Vertex Energy 10Q 2022 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2022

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM _____________ TO _____________

Commission File Number 001-11476

———————

VERTEX ENERGY, INC.

(Exact name of registrant as specified in its charter)

———————


Nevada			94-3439569
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1331 Gemini Street, Suite 250, Houston, Texas 77058

(Address of principal executive offices) (Zip Code)

866-660-8156

Registrant's telephone number, including area code

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, $0.001 Par Value Per Share	VTNR	The NASDAQ Stock Market LLC
		(Nasdaq Capital Market)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☑ Yes ¨ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☑ Yes ¨ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.


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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act.

¨ Yes ☑ No

As of November 7, 2022, there were 75,668,826 shares of common stock are issued and outstanding.

TABLE OF CONTENTS


		Page
Glossary of Terms		4
	PART I
Item 1.	Financial Statements

	Consolidated Balance Sheets (unaudited)	7

	Consolidated Statements of Operations (unaudited)	9

	Consolidated Statements of Equity (unaudited)	11

	Consolidated Statements of Cash Flows (unaudited)	13

	Notes to Consolidated Financial Statements (unaudited)	16

Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	48

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	69

Item 4.	Controls and Procedures	70


	PART II
Item 1.	Legal Proceedings	71

Item 1A.	Risk Factors	72

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	91

Item 3.	Defaults Upon Senior Securities	91

Item 4.	Mine Safety Disclosures	91

Item 5.	Other Information	91

Item 6.	Exhibits	92

GLOSSARY OF TERMS

Please see the “Glossary” beginning on page 4 in our Annual Report on Form 10-K for the year ended December 31, 2021, filed with the Securities and Exchange Commission on March 14, 2022 (the "Annual Report"), for a list of abbreviations and definitions used throughout this Report. In addition, unless the context otherwise requires and for the purposes of this report only:

•“BBL” (also “bbl” or “Bbl”) is the abbreviated form for one barrel, 42 U.S. gallons of liquid volume.

•“BPD” (also “bpd”) is the abbreviated form for barrels per day. This can refer to designed or actual capacity/throughput.

•“BCD” (also “bcd”, “b/cd”) is the abbreviated form of barrels per calendar day; meaning the total number of barrels of actual throughput processed within 24 hours under typical operating conditions.

•“Base oil” is a lubricant grade oil initially produced from refining crude oil or through chemical synthesis used in manufacturing lubricant products such as lubricating greases, motor oil, and metal processing fluids.

•“Black Oil” is a term used to describe used lubricating oils, which may be visually characterized as dark in color due to carbon and other residual elements and compounds which accumulate through use. This term can also refer to the business segment within the Company, which manages used motor oil related operations and processes such as purchase, sales, aggregation, processing, and re-refining.

•“Catalytic Reforming” is a process that uses heat, pressure, and a catalyst to convert low-octane naphthas into high-octane gasoline blending components.

•“Cracking” refers to the process of breaking down larger, heavier, and more complex hydrocarbon molecules into simpler and lighter molecules through the use of heat, pressure, and sometimes a catalyst.

•“Crude oil distillation” means the process of distilling vapor from liquid crudes, usually by heating and condensing the vapor slightly above atmospheric pressure turning it back to liquid in order to purify, fractionate or form the desired products.

•“Cutterstock” also known as “cutter stock”, refers to any stream that is blended to adjust various properties of the resulting blend.

•“Distillates” are finished fuel products such as diesel fuels, jet fuel and kerosene.

•“Generator” means any person, by site, whose act or process produces used oil or whose act first causes used oil to become subject to regulation. Generators can be service stations, governments or other businesses that produce or receive used oil.

•“IMO 2020” refers to the International Maritime Organization’s rule, effective January 1, 2020, which limited sulfur content in fuels used on board ships operating outside designated emission control areas to 0.50% mass by mass.

•“Industrial fuel” is a distillate fuel oil, typically a blend of lower-quality fuel oils. It can include diesel fuels and fuel oils such as No. 1, No. 2, and No. 4 diesel fuels that are historically used for space heating and power generation. Industrial fuel is typically a fuel with low viscosity, as well as low sulfur, ash, and heavy metal content, making it an ideal blending agent.

•“LLS” means Louisiana Light Sweet Crude and is a grade of crude oil classified by its low sulfur content.

•“LPG” means liquefied petroleum gases.

•“Lubricant” or “lube” means a solvent-neutral paraffinic product used in commercial heavy-duty engine oils, passenger car oils, and specialty products for industrial applications such as heat transfer, metalworking, rubber, and other general process oil.

•“MBL” means one thousand barrels.

•“Metals” consist of recoverable ferrous and non-ferrous recyclable metals from manufacturing and consumption. Scrap metal can be recovered from pipes, barges, boats, building supplies, surplus equipment, tanks, and other items consisting of metal composition. These materials are segregated, processed, cut up, and sent back to a steel mill for re-purposing.

•“Oil collection services” include the collection, handling, treatment, and transacting of used motor oil and related products which contain used motor oil (such as oil filters and absorbents) acquired from customers.

•“Olefins” are hydrotreated VGO.

•“Other refinery products” include the sales of asphalt, condensate, recovered products, and other petroleum products.

•“Pygas” or pyrolysis gasoline, is a product that can be blended with gasoline as an octane booster or distilled and separated into its components, including benzene and other hydrocarbons.

•“Re-Refining” refers to the process or industry which uses refining processes and technology with used oil as a feedstock to produce high-quality base stocks and intermediate feedstocks for lubricants, fuels, and other petroleum products.

•“Refining adjusted EBITDA” represents income (loss) from operations plus depreciation and amortization, unrealized gains and losses on hedging activities, gain and loss on intermediation agreement, and certain other unusual or non-recurring charges included in selling, general, and administrative expenses.

•“Refining gross margin” is defined as gross profit (loss) less the cost of fuel intakes and other fuel costs. It excludes operating expenses and depreciation attributable to cost of revenues and other non-operating items included in costs of revenues, including unrealized losses on hedging activities and loss on inventory intermediation agreement.

•“Refining gross margin per barrel of throughput” is calculated as refining gross margin divided by total throughput barrels for the period presented.

•“Reformate” is a gasoline blending stock produced by catalytic reforming.

•“Renewable Diesel” means a diesel fuel derived from vegetable oils or animal fats that is produced through various processes, most commonly through hydrotreating, reacting the feedstock with hydrogen under temperatures and pressure in the presence of a catalyst.

•“RINs” means renewable identification numbers and refers to serial numbers assigned to credits generated from renewable fuel production under the Environmental Protection Agency’s Renewable Fuel Standard (“RFS”) regulations, which require blending renewable fuels into the nation’s fuel supply. In lieu of blending, refiners may purchase these transferable credits to comply with the regulations.

•“Sour Crude Oil” refers to crude oil containing quantities of sulfur greater than 0.4 percent by weight.

•“Sweet Crude Oil” refers to crude oil containing quantities of sulfur equal to or less than 0.4 percent by weight.

•“UMO” is the abbreviation for used motor oil.

•“Vacuum Distillation” is the process of distilling vapor from liquid crudes, usually by heating and condensing the vapor below atmospheric pressure turning it back to a liquid in order to purify, fractionate or form the desired products.

•“Vacuum Gas Oil” or “VGO” is a product produced from a vacuum distillation column which is predominately used as an intermediate feedstock to produce transportation fuels and other by-products such as gasoline, diesel and marine fuels.

•“VTB” refers to vacuum tower bottoms, the leftover bottom product of distillation, which can be processed in cokers and used for upgrading into gasoline, diesel, and gas oil.

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

VERTEX ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(in thousands, except number of shares and par value)

(UNAUDITED)


	September 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	117,464	$	36,130
Restricted cash	4,929		100,497
Accounts receivable, net	51,830		14,880

Inventory	169,772		8,031
Derivative commodity asset	1,219		96
Prepaid expenses and other current assets	33,337		4,567
Assets held for sale, current	11,651		10,070
Total current assets	390,202		174,271


Fixed assets, at cost	198,088		62,196
Less accumulated depreciation	(33,371)		(26,043)
Fixed assets, net	164,717		36,153
Finance lease right-of-use assets	43,649		377
Operating lease right-of use assets	33,960		33,272
Intangible assets, net	12,803		6,652

Other assets	2,246		15,335


TOTAL ASSETS	$	647,577	$	266,060

LIABILITIES, TEMPORARY EQUITY, AND EQUITY
Current liabilities
Accounts payable	$	70,906	$	11,980
Accrued expenses	42,650		4,942

Finance lease liability-current	1,155		342
Operating lease liability-current	6,421		5,849
Current portion of long-term debt, net	16,637		2,413
Obligations under inventory financing agreements, net	134,244		—


Total current liabilities	272,013		25,526

Long-term debt, net	167,665		64,131
Finance lease liability-long-term	44,339		256

Operating lease liability-long-term	27,539		27,423


Derivative warrant liability	14,303		75,211
Other liabilities	1,378		—
Total liabilities	527,237		192,547

COMMITMENTS AND CONTINGENCIES (Note 4)	—		—


	September 30, 2022		December 31, 2021

TEMPORARY EQUITY




Redeemable non-controlling interest	—		43,447
Total temporary equity	—		43,447
EQUITY
50,000,000 of total Preferred shares authorized:
Series A Convertible Preferred Stock, $0.001 par value; zero and 5,000,000 shares designated, zero and 385,601 shares issued and outstanding at September 30, 2022 and December 31, 2021, with a liquidation preference of $0 and $574,545 at September 30, 2022 and December 31, 2021.	—		—



Common stock, $0.001 par value per share; 750,000,000 shares authorized; 75,608,826 and 63,287,965 shares issued and outstanding at September 30, 2022 and December 31, 2021, respectively.	76		63
Additional paid-in capital	278,930		138,620
Accumulated deficit	(160,354)		(110,614)
Total Vertex Energy, Inc. shareholders' equity	118,652		28,069
Non-controlling interest	1,688		1,997
Total equity	120,340		30,066
TOTAL LIABILITIES, TEMPORARY EQUITY, AND EQUITY	$	647,577	$	266,060

See accompanying condensed notes to the consolidated financial statements.

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share amounts)

(UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues	$	810,208	$	50,982	$	1,915,423	$	147,807
Cost of revenues (exclusive of depreciation and amortization shown separately below)	750,463		46,142		1,819,757		127,986
Depreciation and amortization attributable to costs of revenues	4,050		1,028		9,144		3,002
Gross profit	55,695		3,812		86,522		16,819

Operating expenses:
Selling, general and administrative expenses	36,978		8,177		89,934		21,742
Depreciation and amortization attributable to operating expenses	1,120		420		2,656		1,260


Total operating expenses	38,098		8,597		92,590		23,002

Income (loss) from operations	17,597		(4,785)		(6,068)		(6,183)

Other income (expense):


Other income (expenses)	417		(3)		1,060		4,220

Gain (loss) on change in value of derivative warrant liability	12,312		11,907		7,788		(11,380)

Interest expense	(13,131)		(455)		(65,083)		(919)
Total other income (expense)	(402)		11,449		(56,235)		(8,079)
Income (loss) from continuing operations before income tax	17,195		6,664		(62,303)		(14,262)
Income tax benefit (expense)	—		—		—		—
Income (loss) from continuing operations	17,195		6,664		(62,303)		(14,262)
Income from discontinued operations, net of tax (see note 23)	4,975		3,981		19,882		11,915
Net income (loss)	22,170		10,645		(42,421)		(2,347)
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest from continuing operations	(64)		(115)		33		511
Net income attributable to non-controlling interest and redeemable non-controlling interest from discontinued operations	—		2,400		6,829		7,183
Net income (loss) attributable to Vertex Energy, Inc.	22,234		8,360		(49,283)		(10,041)

Accretion of redeemable noncontrolling interest to redemption value from continued operations	—		(415)		(428)		(1,177)
Accretion of discount on Series B and B1 Preferred Stock	—		—		—		(507)


Net income (loss) attributable to common shareholders from continuing operations	17,259		6,364		(62,764)		(16,457)
Net income attributable to common shareholders from discontinued operations, net of tax	4,975		1,581		13,053		4,732
Net income (loss) attributable to common shareholders	$	22,234	$	7,945	$	(49,711)	$	(11,725)


Basic income (loss) per common share
Continuing operations	$	0.23	$	0.10	$	(0.91)	$	(0.31)
Discontinued operations, net of tax	0.07		0.03		0.19		0.09
Basic income (loss) per common share	$	0.30	$	0.13	$	(0.72)	$	(0.22)

Diluted income (loss) per common share
Continuing operations	$	0.22	$	0.10	$	(0.91)	$	(0.31)
Discontinued operations, net of tax	0.06		0.02		0.19		0.09
Diluted income (loss) per common share	$	0.28	$	0.12	$	(0.72)	$	(0.22)

Shares used in computing earnings per share
Basic	75,591		61,349		69,007		53,964
Diluted	79,638		64,605		69,007		53,964

See accompanying condensed notes to the consolidated financial statements.

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(in thousands, except par value)

(UNAUDITED)


Nine Months Ended September 30, 2022
	Common Stock			Series A Preferred
	Shares	$0.001 Par		Shares	$0.001 Par		Additional Paid-In Capital		Retained Earnings		Non-controlling Interest		Total Equity
Balance on January 1, 2022	63,288	$	63	386	$	—	$	138,620	$	(110,614)	$	1,997	$	30,066
Exercise of options	60	—		—	—		76		—		—		76
Exercise of warrants	1,113	1		—	—		(1)		—		—		—
Share based compensation expense	—	—		—	—		250		—		—		250
Conversion of Series A Preferred stock to common	5	—		(5)	—		—		—		—		—
Reclassification of derivative liabilities	—	—		—	—		78,789		—		—		78,789
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		(422)		—		(422)
Net income (loss)	—	—		—	—		—		(4,547)		3,739		(808)
Less: amount attributable to redeemable non-controlling interest	—	—		—	—		—		—		(3,769)		(3,769)
Balance on March 31, 2022	64,466	64		381	—		217,734		(115,583)		1,967		104,182
Exercise of options to common	498	1		—	—		553		—		—		554
Exercise of options to common- unissued	—	—		—	—		3		—		—		3
Distribution to noncontrolling shareholder	—	—		—	—		—		—		(380)		(380)
Adjustment of redeemable non controlling interest	—	—		—	—		29		(29)		—		—
Conversion of Convertible Senior Notes to common	10,165	10		—	—		59,812		—		—		59,822
Share based compensation expense	—	—		—	—		324		—		—		324
Conversion of Series A Preferred stock to common	381	1		(381)	—		—		—		—		1
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		(6)		—		(6)
Net income (loss)	—	—		—	—		—		(66,970)		3,188		(63,782)
Less: amount attributable to redeemable non-controlling interest	—	—		—	—		—		—		(3,023)		(3,023)
Balance on June 30, 2022	75,510	76		—	—		278,455		(182,588)		1,752		97,695
Exercise of options to common	4	—		—	—		—		—		—		—
Exercise of options to common- unissued	—	—		—	—		97		—		—		97
Exercise of warrants	96	—		—	—		—		—		—		—




Share based compensation expense	—	—		—	—		378		—		—		378






Net income (loss)	—	—		—	—				22,234		(64)		22,170

Balance on September 30, 2022	75,610	$	76	—	$	—	$	278,930	$	(160,354)	$	1,688	$	120,340

See accompanying condensed notes to the consolidated financial statements.


Nine Months Ended September 30, 2021
	Common Stock			Series A Preferred
	Shares	$0.001 Par		Shares	$0.001 Par		Additional Paid-In Capital		Retained Earnings		Non-controlling Interest		Total Equity
Balance on January 1, 2021	45,555	$	46	420	$	—	$	94,570	$	(90,009)	$	1,318	$	5,925
Exercise of options	23	—		—	—		—		—		—		—
Exercise of B1 warrants	1,080	1		—	—		2,757		—		—		2,758
Exchanges of Series B Preferred stock to common	2,359	2		—	—		4,114		630		—		4,746
Share based compensation expense	—	—		—	—		150		—		—		150

Conversion of Series B Preferred stock to common	638	1		—	—		1,978		—		—		1,979
Conversion of Series B1 Preferred stock to common	2,087	2		—	—		3,254		—		—		3,256
Dividends on Series B and B1	—	—		—	—		—		(372)		—		(372)
Accretion of discount on Series B and B1	—	—		—	—		—		(224)		—		(224)
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		(373)		—		(373)
Net income	—	—		—	—		—		974		1,991		2,965
Less: amount attributable to redeemable non-controlling interest	—	—		—	—		—		—		(1,542)		(1,542)
Balance on March 31, 2021	51,742	52		420	—		106,823		(89,374)		1,767		19,268
Exercise of options to common	505	—		—	—		229		—		—		229
Exercise of options to common- unissued	—	—		—	—		475		—		—		475
Leverage Lubricants contribution	—	—		—	—		—		—		(13)		(13)
Exercise of B1 warrants	157	—		—	—		1,634		—		—		1,634
Exercise of B1 warrants-unissued	—	—		—	—		1,186		—		—		1,186
Share based compensation expense	—	—		—	—		205		—		—		205
Conversion of Series A Preferred stock to common	28	—		(28)	—		—		—		—		—
Conversion of Series B Preferred stock to common	1,842	2		—	—		5,707		—		—		5,709
Conversion of Series B Preferred stock to common-unissued	—	—		—	—		760		—		—		760
Conversion of Series B1 Preferred stock to common	5,635	6		—	—		8,785		—		—		8,791

Accretion of discount on Series B and B1	—	—		—	—		—		(284)		—		(284)

Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		(387)		—		(387)
Net income (loss)	—	—		—	—		—		(19,375)		3,418		(15,957)
Less: amount attributable to redeemable non-controlling interest	—	—		—	—		—		—		(3,113)		(3,113)
Balance on June 30, 2021	59,909	60		392	—		125,804		(109,420)		2,059		18,503
Exercise of options to common	1,267	1		—	—		1,481		—		—		1,482
Exercise of options to common- unissued	—	—		—	—		3		—		—		3
Exercise of B1 warrants	1,576	2		—	—		9,361		—		—		9,363
Conversion of Series B Preferred stock to common	245	—		—	—		—		—		—		—
Conversion of Series A Preferred stock to common	6	—		(6)	—		—		—		—		—
Leverage Lubricants contribution	—	—		—	—		—		—		2		2
Distribution from VRM LA	—	—		—	—		—		—		(169)		(169)
Share based compensation expense	—	—		—	—		257		—		—		257



Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		(415)		—		(415)


Net income	—	—		—	—		—		8,360		2,285		10,645
Less: amount attributable to redeemable non-controlling interest	—	—		—	—		—		—		(2,329)		(2,329)
Balance on September 30, 2021	63,003	$	63	386	$	—	$	136,906	$	(101,475)	$	1,848	$	37,342

See accompanying condensed notes to the consolidated financial statements.

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(UNAUDITED)


	Nine Months Ended September 30,
	2022		2021
Cash flows from operating activities
Net loss	$	(42,421)	$	(2,347)
Income from discontinued operations, net of tax	19,882		11,915
Loss from continuing operations	(62,303)		(14,262)
Adjustments to reconcile net loss from continuing operations to cash provided by (used in) operating activities, net of acquisitions
Stock based compensation expense	952		613
Depreciation and amortization	11,800		4,263

Gain on forgiveness of debt	—		(4,222)
(Gain) loss on sale of assets	(112)		2
Provision for environment clean up	1,428		—

Increase in allowance for bad debt	157		717
Increase in fair value of derivative warrant liability	(7,788)		11,380
Loss on commodity derivative contracts	87,218		2,205
Net cash settlements on commodity derivatives	(100,253)		(1,999)
Amortization of debt discount and deferred costs	44,537		38
Changes in operating assets and liabilities, net of acquisition
Accounts receivable and other receivables	(37,157)		(6,123)

Inventory	(31,521)		(3,716)
Prepaid expenses and other current assets	(16,433)		(2,366)
Accounts payable	58,925		1,945
Accrued expenses	37,658		2,450
Other assets	54		(648)
Net cash used in operating activities from continuing operations	(12,838)		(9,723)
Cash flows from investing activities
Acquisition of business, net of cash	(227,525)		2

Software purchase	(106)		—


Purchase of fixed assets	(34,744)		(2,313)

Investment in Mobile Refinery assets	—		(10,241)

Proceeds from sale of fixed assets	188		75
Net cash used in investing activities from continuing operations	(262,187)		(12,477)
Cash flows from financing activities
Payments on finance leases	(201)		(409)
Proceeds from exercise of options and warrants to common stock	729		6,493
Distributions to noncontrolling interest	(380)		(169)


Net borrowings on inventory financing agreements	133,744		—
Net change in line of credit	—		(166)
Redemption of noncontrolling interest	(50,666)		—
Proceeds from note payable	173,315		10,078
Payments on note payable	(14,101)		(3,779)
Net cash provided by financing activities from continuing operations	242,440		12,050


Discontinued operations:
Net cash provided by operating activities	20,199		13,043
Net cash used in investing activities	(1,848)		(1,675)

Net cash provided by discontinued operations	18,351		11,368

Net change in cash, cash equivalents and restricted cash	(14,234)		1,218
Cash, cash equivalents, and restricted cash at beginning of the period	136,627		10,995
Cash, cash equivalents, and restricted cash at end of period	$	122,393	$	12,213

See accompanying condensed notes to the consolidated financial statements.

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(UNAUDITED)

(Continued)

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported within the consolidated balance sheets to the same such amounts shown in the consolidated statements of cash flows (in thousands).


	Nine Months Ended
	September 30, 2022		September 30, 2021
Cash and cash equivalents	$	117,464	$	12,113
Restricted cash	4,929		$	100
Cash and cash equivalents and restricted cash as shown in the consolidated statements of cash flows	$	122,393	$	12,213



SUPPLEMENTAL INFORMATION
Cash paid for interest	$	20,191	$	844
Cash paid for taxes	$	—	$	—
NON-CASH INVESTING AND FINANCING TRANSACTIONS
Equity component of the convertible note issuance	$	78,789	$	—

Conversion of Series B Preferred Stock into common stock	$	—	$	8,447
Conversion of Series B1 Preferred Stock into common stock	$	—	$	12,046
Exchanges of Series B Preferred Stock into common stock	$	—	$	4,747
Accretion of discount on Series B and B1 Preferred Stock	$	—	$	507
Dividends-in-kind accrued on Series B and B1 Preferred Stock	$	—	$	(258)

Conversion of Convertible Senior Notes to common stock	$	59,822	$	—
Equipment acquired (disposed) under leases	$	45,096	$	174
Accretion of redeemable noncontrolling interest to redemption value	$	428	$	1,177

See accompanying notes to the consolidated financial statements.

VERTEX ENERGY, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

SEPTEMBER 30, 2022

(UNAUDITED)

NOTE 1. BASIS OF PRESENTATION AND NATURE OF OPERATIONS

Vertex Energy, Inc. (the "Company" or "Vertex Energy") is an energy transition company focused on the production and distribution of conventional and alternative fuels. We operate used motor oil processing plants in Houston, Texas, Port Arthur, Texas, Marrero, Louisiana, and Columbus, Ohio.

As of April 1, 2022, we own a refinery in Mobile, Alabama (the “Mobile Refinery”) with an operable refining capacity of 75,000 barrels per day (“bpd”) and more than 3.2 million barrels of storage capacity. The total purchase consideration was $75.0 million in cash plus $16.3 million in previously agreed upon capital expenditures and miscellaneous prepaid and reimbursable items. At the time of the acquisition, the Company also purchased $130.0 million in hydrocarbon inventories of which $124.0 were financed under an inventory financing agreement. See Note 3 “Mobile Refinery Acquisition” and Note 10 “Inventory Financing Agreement” for additional information.

The accompanying unaudited interim consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America and the rules of the Securities and Exchange Commission ("SEC") and should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2021, contained in the Company's annual report, as filed with the SEC on Form 10-K on March 14, 2022 (the "Form 10-K").

The December 31, 2021 balance sheet was retroactively restated from the audited financial statements of our 2021 Form 10-K to account for the change for our discontinued business, see Note 23 "Discontinued Operations". In the opinion of management all adjustments, consisting of normal recurring adjustments necessary for a fair presentation of financial position and the results of operations for the interim periods presented, have been reflected herein. All significant intercompany transactions have been eliminated in consolidation. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. Notes to the consolidated financial statements which would substantially duplicate the disclosures contained in the audited consolidated financial statements for the most recent fiscal year 2021 as reported in Form 10-K have been omitted.

Used Motor Oils Business ("UMO Business")

Our UMO Business consists of our used oil refinery in Marrero, Louisiana, our Heartland used oil refinery in Ohio, our H&H and Heartland used motor oil (UMO) collections business; our oil filters and absorbent materials recycling facility in East Texas; and the rights to a lease at the Cedar Marine terminal in Baytown, Texas. The UMO Business is presented as part of our Black Oil segment in our consolidated financial statements. On June 29, 2021, the Company, through certain of its subsidiaries, entered into an Asset Purchase Agreement (the “UMO Sale Agreement”) with Safety-Kleen Systems, Inc. (“Safety-Kleen”) by which Safety-Kleen agreed to acquire the Company’s UMO Business. Assets which form a part of our Black Oil Segment which will not be sold as part of the sale of the UMO Business consent of (1) our re-refining complex located in Belle Chasse, Louisiana, which we refer to as our Myrtle Grove Facility; (2) our Marine division established in 2022, which consists of blending and distribution of fuels to the marine market; and (3) our finished lubricants and metal operations, including the distribution and blending of lubricants as well as a metal recovery operation.

During the third quarter of 2021, the Company classified the UMO Business as held for sale based on management’s intention and the Company’s shareholders’ approval to sell the UMO Business. The Company’s historical financial statements have been revised to present the operating results of the UMO Business as discontinued operations. The results of operations of this business are presented as “Income (loss) from discontinued operations” in the statement of operations and the related cash flows of this business have been reclassified to discontinued operations for all periods presented. The assets and liabilities of the UMO Business have been reclassified to “Assets held for sale” and “Liabilities held for sale”, respectively, in the consolidated balance sheet for all periods presented.

On January 24, 2022, the Company and its subsidiaries that were party to the UMO Sale Agreement and Safety-Kleen, entered into an Asset Purchase Termination Agreement (the “UMO Termination Agreement”) pursuant to which the UMO Sale Agreement was terminated. Under the terms of the UMO Termination Agreement, the Company paid a termination fee to Safety-Kleen of $3.0 million. Immediately upon receipt of such termination fee, which the Company paid simultaneously with the execution of the UMO Termination Agreement, the UMO Sale Agreement was terminated and is of no further force or

effect, and with no further liability to any party thereunder, other than certain confidentiality obligations of the parties and ongoing liability for any willful or intentional breach of, or non-compliance with, the UMO Sale Agreement.

The Company is still exploring opportunities to sell the UMO Business and believes it will sell such assets within a year. As of the day of this filing, the Company is in ongoing discussions with a third party regarding a potential sale of the Company's Heartland refinery in Ohio, and as such has determined to present only the Company's Heartland refinery options as discontinued operations ("Heartland Business").

Use of Estimates

The preparation of GAAP financial statements requires management to make estimates and assumptions that affect reported amounts of assets and liabilities, disclosure of contingent assets and liabilities, and reported amounts of revenue and expenses. Actual results could differ from these estimates. Any effects on the business, financial position or results of operations from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.

The majority of the numbers presented below are rounded numbers and should be considered as approximate.

Reclassification of Prior Year Presentation

Certain prior period amounts have been reclassified to conform to current period presentation. These reclassifications had no effect on the reported results of operations.

The Company included the Heartland Business as discontinued operation, and reclassified the other UMO Business operations out of the assets held for sale, and all liabilities of the UMO Business out of liabilities held for sale, other than in connection with the Heartland Business.

NOTE 2. SUMMARY OF CRITICAL ACCOUNTING POLICIES AND ESTIMATES

With the exception of the accounting policies below, there have been no new or material changes to the significant accounting policies discussed in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

Cash, Cash Equivalents and Restricted Cash

The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.

Restricted cash as of September 30, 2022, consisted of a $4.8 million deposit in a bank for financing of a short-term equipment lease, and a $0.1 million deposit in a money market account to serve as collateral for payment of a credit card. As of December 31, 2021, a total of $100.4 million was held in an escrow account in connection with the issuance of certain convertible notes (see Note 15. "Long-Term Debt". The funds were released on April 1, 2022 and used in the purchase of the Mobile Refinery. See Note 3 “Mobile Refinery Acquisition ”.

Accounts Receivable

Accounts receivable represents amounts due from customers. Accounts receivable are recorded at invoiced amounts, net of reserves and allowances, do not bear interest and are not collateralized. The Company uses its best estimate to determine the required allowance for doubtful accounts based on a variety of factors, including the length of time receivables are past due, economic trends and conditions affecting its customer base, significant one-time events, and historical write-off experience. Specific provisions are recorded for individual receivables when we become aware of a customer’s inability to meet its financial obligations. The Company reviews the adequacy of its reserves and allowances quarterly.

Receivable balances greater than 90 days past due are individually reviewed for collectability and if deemed uncollectible, are charged off against the allowance accounts after all means of collection have been exhausted and the potential for recovery is considered remote. The allowance was $1.5 million and $1.4 million at September 30, 2022 and December 31, 2021, respectively.

Inventory and Obligations Under Inventory Financing Agreements

Mobile Refinery. Inventories at the recently acquired Mobile Refinery consist of crude oil and refined petroleum products. Simultaneously with the acquisition of the Mobile Refinery, the Company entered into an inventory financing agreement with Macquarie Energy North America Trading Inc. (“Macquarie”) under which Macquarie agreed to finance all the crude oil utilized at the Mobile Refinery under procurement contracts. In addition, the Company became a party to a Supply and Offtake Agreement with Macquarie. Under this arrangement, the Company purchases crude oil supplied from third-party suppliers and Macquarie provides credit support for certain of these purchases. Macquarie holds title to all crude oil and refined products inventories at all times, except for liquefied petroleum gases and sulfur, which the Company has pledged, together with all receivables arising from the sales of such inventories.

The crude oil remains in the legal title of Macquarie and is stored in our storage tanks governed by a storage agreement. Legal title to the crude oil passes to us at the tank outlet. After processing, Macquarie takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by Macquarie on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we have an obligation to repurchase it. The valuation of our repurchase obligation requires that we make estimates of the prices and differentials assuming settlement occurs at the end of the reporting period.

Hydrocarbon inventories at the Mobile Refinery are stated at the lower of cost or net realizable value using the weighted average inventory accounting method. Estimating the net realizable value of our inventory requires management to make assumptions about the timing of sales and the expected proceeds that will be realized for these sales. See Note 9 “Inventory” and Note 10 “Inventory Financing Agreement” for more information.

Other locations. Inventories from our legacy business consist of feedstocks and refined petroleum products and recovered ferrous and non-ferrous metals. These commodity inventories are stated at the lower of cost or net realizable value using the first-in, first-out (“FIFO”) accounting method.

Revenue Recognition

Our revenues are generated through the sale of refined petroleum products and terminalling and storage services. We recognize revenue from product sales at prevailing market rates at the point in time in which the customer obtains control of the product. Terminalling and storage revenues are recognized as services are rendered, and our performance obligations have been satisfied once the product has been transferred back to the customer. These services are short-term in nature, and the service fees charged to our customers are at prevailing market rates. The timing of our revenue recognition may differ from the timing of payment from our customers. A receivable is recorded when revenue is recognized prior to payment and we have an unconditional right to payment.

Environmental Reserves

We accrue for losses associated with environmental remediation obligations when such losses are probable and reasonably estimable. The liability represents the expected costs of remediating contaminated soil and groundwater at the site. Costs of future expenditures for environmental remediation obligations are discounted to their present value.

Impairment of long-lived assets

The Company evaluates the carrying value and recoverability of its long-lived assets when circumstances warrant such evaluation. Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable through the estimated undiscounted cash flows expected to result from the use and eventual disposition of the assets. Whenever any such impairment exists, an impairment loss will be recognized for the amount by which the carrying value exceeds the fair value. The Company determined that no long-lived asset impairment existed during the nine months ended September 30, 2022 and 2021.

Redeemable Noncontrolling Interests

As more fully described in “Note 22. Non-Controlling Interests”, the Company was party to put/call option agreements with the holder of Vertex Refining Myrtle Grove LLC (“MG SPV”) and HPRM LLC, a Delaware limited liability company (“Heartland SPV”), which entities were formed as special purpose vehicles in connection with the transactions described in greater detail in non-controlling interests. The put options permited MG SPV's and Heartland SPV's non-controlling interest holders, at any time

on or after the earlier of (a) the fifth anniversary of the applicable closing date of such issuances and (ii) the occurrence of certain triggering events (an “MG Redemption” and “Heartland Redemption”, as applicable) to require MG SPV and Heartland SPV to redeem the non-controlling interest from the holder of such interest. Applicable accounting guidance requires an equity instrument that is redeemable for cash or other assets to be classified outside of permanent equity if it is redeemable (a) at a fixed or determinable price on a fixed or determinable date, (b) at the option of the holder, or (c) upon the occurrence of an event that is not solely within the control of the issuer. Based on this guidance, the Company classified the MG SPV and Heartland SPV non-controlling interests between the liabilities and equity sections of the accompanying consolidated balance sheets. If an equity instrument subject to the guidance is currently redeemable, the instrument is adjusted to its maximum redemption amount at the balance sheet date. If the equity instrument subject to the guidance is not currently redeemable but it is probable that the equity instrument will become redeemable (for example, when the redemption depends solely on the passage of time), the guidance permits either of the following measurement methods: (a) accrete changes in the redemption value over the period from the date of issuance (or from the date that it becomes probable that the instrument will become redeemable, if later) to the earliest redemption date of the instrument using an appropriate methodology, or (b) recognize changes in the redemption value immediately as they occur and adjust the carrying amount of the instrument to equal the redemption value at the end of each reporting period. The amount presented in temporary equity should be no less than the initial amount reported in temporary equity for the instrument. Because the MG SPV and Heartland SPV equity instruments were to become redeemable solely based on the passage of time, the Company determined that it is probable that the MG SPV and Heartland SPV equity instruments would become redeemable. The Company elected to apply the second of the two measurement options described above. An adjustment to the carrying amount of a non-controlling interest from the application of the above guidance does not impact net loss in the consolidated financial statements. Rather, such adjustments are treated as equity transactions and adjustment to net loss in determining net loss available to common stockholders for the purpose of calculating earnings per share. On April 1, 2022, the Company redeemed the non-controlling interest holder's interest of MG SPV, and on May 26, 2022, the Company redeemed the non-controlling interest holder's interest of Heartland SPV.

Variable Interest Entities

The Company determines whether each business entity in which it has equity interests, debt, or other investments constitutes a variable interest entity (“VIE”) based on consideration of the following criteria: (i) the entity lacks sufficient equity at-risk to finance its activities without additional subordinated financial support, or (ii) equity holders, as a group, lack the characteristics of a controlling financial instrument.

If an entity is determined to be a VIE, the Company then determines whether to consolidate the entity as the primary beneficiary. The primary beneficiary has both (i) the power to direct the activities that most significantly impact the VIE’s economic performance, and (ii) the obligation to absorb losses of the VIE or the right to receive benefits from the VIE that could potentially be significant to the entity.

Assets and Liabilities Held for Sale

The Company classifies disposal groups as held for sale in the period in which all of the following criteria are met: (1) management, having the authority to approve the action, commits to a plan to sell the disposal group; (2) the disposal group is available for immediate sale in its present condition subject only to terms that are usual and customary for sales of such disposal groups; (3) an active program to locate a buyer or buyers and other actions required to complete the plan to sell the disposal group have been initiated; (4) the sale of the disposal group is probable, and transfer of the disposal group is expected to qualify for recognition as a completed sale, within one year, except if events or circumstances beyond the Company’s control extend the period of time required to sell the disposal group beyond one year; (5) the disposal group is being actively marketed for sale at a price that is reasonable in relation to its current fair value; and (6) actions required to complete the plan indicate that it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn.

A disposal group that is classified as held for sale is initially measured at the lower of its carrying amount or fair value less any costs to sell. Any loss resulting from this measurement is recognized in the period in which the held for sale criteria are met. No loss was recognized during the periods presented.

Subsequent changes in the fair value of a disposal group less any costs to sell are reported as an adjustment to the carrying amount of the disposal group, as long as the new carrying amount does not exceed the carrying amount of the asset at the time it was initially classified as held for sale. Upon determining that a disposal group meets the criteria to be classified as held for sale, the Company reports the assets and liabilities of the disposal group for all periods presented in the line items assets held for sale and liabilities held for sale, respectively, in the consolidated balance sheets.

Discontinued Operations

The results of operations of a component of the Company that can be clearly distinguished, operationally and for financial reporting purposes, that either has been disposed of or is classified as held for sale is reported in discontinued operations, if the disposal represents a strategic shift that has, or will have, a major effect on the Company’s operations and financial results.

New Accounting Pronouncements

Accounting pronouncements adopted by the Company in 2022.

In August 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity to simplify the accounting for convertible debt and other equity-linked instruments. The new guidance simplifies the accounting for convertible instruments by eliminating the cash conversion and beneficial conversion feature models used to separately account for embedded conversion features as a component of equity. Instead, the entity will account for the convertible debt or convertible preferred stock securities as a single unit of account, unless the conversion feature requires bifurcation and recognition as derivatives. Additionally, the guidance requires entities to use the if-converted method for all convertible instruments in the diluted earnings per share calculation and include the effect of potential share settlement for instruments that may be settled in cash or shares. The Company adopted this new guidance as of January 1, 2022, under the modified retrospective method. On January 20, 2022, our shareholders approved the issuance of shares of our common stock issuable upon the conversion of our $155 million aggregate principal amount at maturity 6.25% Convertible Senior Notes due 2027 (the "Convertible Senior Notes"), the $79 million derivative liabilities were recorded as additional paid-in capital.

Accounting pronouncements not yet adopted.

The Company has not identified any recent accounting pronouncements that are expected to have a material impact on our financial condition, results of operations or cash flows upon adoption.

NOTE 3. MOBILE REFINERY ACQUISITION

On April 1, 2022 (the “Effective Date”), Vertex Energy Operating, LLC (“Vertex Operating”), the Company’s wholly-owned subsidiary assigned its rights to that certain May 26, 2021 Sale and Purchase Agreement between Vertex Operating and Equilon Enterprises LLC d/b/a Shell Oil Products US, Shell Oil Company and Shell Chemical LP, subsidiaries of Shell plc (“Shell”) (the “Refinery Purchase Agreement”), to Vertex Refining Alabama LLC, a Delaware limited liability company (“Vertex Refining”) which is indirectly wholly-owned by the Company, and on the same date, Vertex Refining completed the acquisition of a Mobile, Alabama refinery (the “Mobile Refinery”) from Shell (the “Mobile Acquisition”). On the Effective Date, a total of $75 million (less $10 million previously paid) was paid by Vertex Refining in consideration for the acquisition of the Mobile Refinery, which amount was subject to customary purchase price adjustments and reimbursement for certain capital expenditures in the amount of approximately $0.4 million, $15.9 million was paid to Shell for previously agreed upon capital expenditures and miscellaneous prepaid and reimbursable items, and $130 million was paid to Shell by Vertex Refining in connection with the purchase of certain crude oil inventory and finished products owned by Shell and located at the Mobile Refinery on April 1, 2022 (approximately $124 million of which was funded by Macquarie as a result of the simultaneous sale of such inventory to Macquarie pursuant to an Inventory Sales Agreement between Vertex Refining and Macquarie). The Company also paid $8.7 million at closing pursuant to the terms of a Swapkit Purchase Agreement entered into with Shell on May 26, 2021 (the “Swapkit Agreement”), pursuant to which the Company agreed to fund a technology solution comprising the ecosystem required for the Company to run the Mobile Refinery after closing (the “Swapkit”).

The purchase price allocation is preliminary and subject to change based upon the finalization of our valuation report. The following table summarizes the preliminary determination and recognition of assets acquired (in thousands):


	Financing agreement		Vertex acquisition		Total
Inventory	$	124,311	$	5,909	$	130,220
Prepaid assets	—		147		147
Fixed assets	—		97,158		97,158
Total purchase price	$	124,311	$	103,214	$	227,525

The following table presents summarized results of operations of the Mobile Refinery for the period from April 1, 2022 to September 30, 2022, which are included in the accompanying consolidated statement of operations for the period ended September 30, 2022 (in thousands):


	For Three Months Ended September 30, 2022		For Six Months Ended September 30, 2022
Revenue	$	733,521	$	1,655,717
Net Income (loss)	$	18,370	$	(5,592)

The following table presents unaudited pro forma results of operations reflecting the acquisition of the Mobile Refinery as if the acquisition had occurred as of January 1, 2021. This information has been compiled from current and historical financial statements and is not necessarily indicative of the results that actually would have been achieved had the transaction occurred at the beginning of the periods presented or that may be achieved in the future (in thousands):


	For Nine Months Ended September 30,
	2022		2021
Revenue	$	2,406,617	$	1,473,700
Net income (loss)	$	49,509	$	(37,500)

NOTE 4. COMMITMENTS AND CONTINGENCIES

Litigation

The Company, in its normal course of business, is involved in various other claims and legal action. In the opinion of management, the outcome of these claims and actions will not have a material adverse impact upon the financial position of the Company. We are currently party to the following material litigation proceedings:

Vertex Refining LA, LLC (“Vertex Refining LA”), the wholly-owned subsidiary of Vertex Operating was named as a defendant, along with numerous other parties, in five lawsuits filed on or about February 12, 2016, in the Second Parish Court for the Parish of Jefferson, State of Louisiana, Case No. 121749, by Russell Doucet et. al., Case No. 121750, by Kendra Cannon et. al., Case No. 121751, by Lashawn Jones et. al., Case No. 121752, by Joan Strauss et. al. and Case No. 121753, by Donna Allen et. al. The suits relate to alleged noxious and harmful emissions from our facility located in Marrero, Louisiana. The suits seek damages for physical and emotional injuries, pain and suffering, medical expenses and deprivation of the use and enjoyment of plaintiffs’ homes. We intend to vigorously defend ourselves and oppose the relief sought in the complaints, provided that at this stage of the litigation, the Company has no basis for determining whether there is any likelihood of material loss associated with the claims and/or the potential and/or the outcome of the litigation.

On November 17, 2020, Vertex filed a lawsuit against Penthol LLC (“Penthol”) in the 61st Judicial District Court of Harris County, Texas, Cause No. 2020-65269, for breach of contract and simultaneously sought a Temporary Restraining Order and Temporary Injunction enjoining Penthol from, among other things, circumventing Vertex in violation of the terms of that certain June 5, 2016 Sales Representative and Marketing Agreement entered into between Vertex Operating and Penthol (the “Penthol Agreement”). Vertex seeks damages, attorney’s fees, costs of court, and all other relief to which it may be entitled.

On February 8, 2021, Penthol filed a complaint against Vertex Operating in the United States District Court for the Southern District of Texas; Civil Action No. 4:21-CV-416 (the “Complaint”). Penthol’s Complaint sought damages from Vertex Operating for alleged violations of the Sherman Act, breach of contract, business disparagement, and misappropriation of trade secrets under the Defend Trade Secrets Act and Texas Uniform Trade Secrets Act. On August 12, 2021, United States District Judge Andrew S. Hanen dismissed Penthol’s Sherman Act claim. Penthol’s remaining claims are pending. Penthol is seeking a declaration that Vertex has materially breached the agreement; an injunction that prohibits Vertex from using Penthol’s alleged trade secrets and requires Vertex to return any of Penthol’s alleged trade secrets; awards of actual, consequential and exemplary damages, attorneys’ fees and costs of court; and other relief to which it may be entitled. Vertex denies Penthol’s allegations in the Complaint. Vertex contends Penthol’s claims are completely without merit, and that Penthol’s termination of the Penthol Agreement was wrongful and resulted in damages to Vertex that it is seeking to recover in the Harris County lawsuit. Further, Vertex contends that Penthol’s termination of the Penthol Agreement constitutes a breach by Penthol under the express terms of the Penthol Agreement, and that Vertex remains entitled to payment of the amounts due Vertex under the Penthol Agreement

for unpaid commissions and unpaid performance incentives. Vertex disputes Penthol’s allegations of wrongdoing and intends to vigorously defend itself in this matter. On February 26, 2021, Penthol filed its second amended answer and counterclaims, alleging that Vertex improperly terminated the Penthol Agreement and that Vertex tortiously interfered with Penthol’s prospective and existing business relationships. Vertex denies these allegations and is vigorously defending them.

Recently, the parties agreed to move the pending claims and defenses in the Texas state court lawsuit into the federal court lawsuit. Both parties also sought to amend their pleadings to add additional claims. By order dated October 18, 2022, the Judge in the lawsuit, Judge Hanen largely granted these requests. As a result, Vertex was granted leave to add Penthol C.V. as a defendant. Penthol was granted leave to add claims for fraud and breach of contract relating to an assignment agreement, and add claims for misappropriation of trade secrets. All pending claims between the parties are now in the federal court action.

The parties recently conducted numerous depositions and substantial document discovery. Vertex has filed a motion for summary judgment, and Penthol has filed a motion for partial summary judgment, both of which are pending.

This case is pending, but is currently set for trial in January 2023.

We cannot predict the impact (if any) that any of the matters described above may have on our business, results of operations, financial position, or cash flows. Because of the inherent uncertainties of such matters, including the early stage and lack of specific damage claims in the Penthol matter, we cannot estimate the range of possible losses from them (except as otherwise indicated).

Environmental Matters

Like other petroleum refiners, we are subject to federal, state, and local environmental laws and regulations. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal. These governmental entities may also propose or assess fines or require corrective actions for these asserted violations. Except as disclosed below, we do not anticipate that any such matters currently known to management will have a material impact on our financial condition, results of operations, or cash flows. On April 1, 2022, we acquired the Mobile Refinery and during the nine months ended on September 30, 2022, we reserved $1.4 million for environment clean up.

NOTE 5. REVENUES

Our revenues are primarily generated from contracts with customers through the sale of refined petroleum products and terminalling and storage services. We recognize revenue from product sales at prevailing market rates at the point in time in which the customer obtains control of the product. Terminalling and storage revenues are recognized as services are rendered, and our performance obligations have been satisfied once the product has been transferred back to the customer. These services are short-term in nature, and the service fees charged to our customers are at prevailing market rates.

The following tables present our revenues disaggregated by geographical market and revenue source (in thousands):


	Three Months Ended September 30, 2022
	Black Oil* & Recovery		Refining & Marketing		Consolidated
Primary Geographical Markets


Southern United States	$	43,439	$	766,769	$	810,208
Sources of Revenue
Refined products:
Gasolines	$	—	$	171,023	$	171,023
Jet Fuels	—		138,962		138,962
Diesel	—		276,355		276,355
Other refinery products (1)	37,607		108,337		145,944
Re-refined products:
Pygas	—		15,285		15,285
Metals (2)	4,060		—		4,060
Other re-refined products (3)	1,490		54,663		56,153
Services:
Terminalling	—		2,144		2,144
Oil collection services	282		—		282
Total revenues	$	43,439	$	766,769	$	810,208


	Three Months Ended September 30, 2021
	Black Oil* & Recovery		Refining & Marketing		Consolidated
Primary Geographical Markets


Southern United States	$	26,410	$	24,572	$	50,982
Sources of Revenue
Refined products:
Gasolines	$	—	$	6,674	$	6,674
Jet Fuels	—		—		—
Diesel	—		13,745		13,745
Other refinery products (1)	20,339		—		20,339
Re-refined products:
Pygas	—		3,736		3,736
Metals (2)	4,328		—		4,328
Other re-refined products (3)	909		417		1,326
Services:					—

Oil collection services	834		—		834
Total revenues	$	26,410	$	24,572	$	50,982


	Nine Months Ended September 30, 2022
	Black Oil* & Recovery		Refining & Marketing		Consolidated
Primary Geographical Markets


Southern United States	$	147,545	$	1,767,878	$	1,915,423
Sources of Revenue
Refined products:
Gasolines	$	—	$	432,173	$	432,173
Jet Fuels	—		282,650		282,650
Diesel	—		620,580		620,580
Other refinery products (1)	129,078		259,667		388,745
Re-refined products:
Pygas	—		40,661		40,661
Metals (2)	13,080		—		13,080
Other re-refined products (3)	4,111		127,695		131,806
Services:					—
Terminalling	—		4,452		4,452
Oil collection services	1,276		—		1,276
Total revenues	$	147,545	$	1,767,878	$	1,915,423


	Nine Months Ended September 30, 2021
	Black Oil* & Recovery		Refining & Marketing		Consolidated
Primary Geographical Markets


Southern United States	$	80,124	$	67,683	$	147,807
Sources of Revenue
Refined products:
Gasolines	—		17,168		17,168
Jet Fuels	—		—		—
Diesel	—		38,806		38,806
Other refinery products (1)	58,039		—		58,039
Re-refined products:
Pygas	—		10,571		10,571
Metals (2)	17,455		—		17,455
Other re-refined products (3)	1,763		1,138		2,901
Services:					—

Oil collection services	2,867		—		2,867
Total revenues	$	80,124	$	67,683	$	147,807

* The Company has determined to combine the Black Oil and Recovery segments in the presentation above due to the revenue from such segment being less than 10% of the Company's total revenue after the Mobile Refinery acquisition. The Black Oil segment includes the Heartland Business, which is presented herein as discontinued operations.

(1) Other refinery products include the sales of base oil, VGO, cutterstock and Hydrotreated VGO and other petroleum products.

(2) Metals consist of recoverable ferrous and non-ferrous recyclable metals from manufacturing and consumption. Scrap metal can be recovered from pipes, barges, boats, building supplies, surplus equipment, tanks, and other items consisting of metal composition. These materials are segregated, processed, cut-up and sent back to a steel mill for re-purposing.

(3) Other re-refinery products include the sales of asphalt, condensate, recovered products, and other petroleum products.

NOTE 6. SEGMENT REPORTING

After the acquisition of the Mobile Refinery on April 1, 2022, the revenues of our Black Oil and Recovery segments are less than 10% of consolidated revenue. The Company decided to present our Black Oil and Recovery segment together during this reporting period.

The Refining and Marketing segment consists primarily of the sale of gasoline, diesel and jet fuel produced at the Mobile Refinery as well as pygas and industrial fuels, which are produced at a third-party facility.

The Black Oil and Recovery segment consists primarily of the sale of (a) petroleum products which include base oil and industrial fuels—which consist of used motor oils, cutterstock and fuel oil generated by our facilities; (b) oil collection services—which consist of used oil sales, burner fuel sales, antifreeze sales and service charges; (c) the sale of other re-refinery products including asphalt, condensate, recovered products, and used motor oil; (d) transportation revenues; (e) the sale of VGO (vacuum gas oil)/marine fuel; (f) the sale of ferrous and non-ferrous recyclable Metal(s) products that are recovered from manufacturing and consumption; and (g) revenues generated from trading/marketing of Group III Base Oils. The Black Oil segment includes the Heartland Business, which is presented herein as discontinued operations.

We also disaggregate our revenue by product category for each of our segments, as we believe such disaggregation helps depict how our revenue and cash flows are affected by economic factors.

Segment information for the three and nine months ended September 30, 2022 and 2021 is as follows (in thousands):


THREE MONTHS ENDED SEPTEMBER 30, 2022
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Revenues:
Refined products	$	37,607	$	694,677	$	—	$	732,284
Re-refined products	5,550		69,948		—		75,498
Services	282		2,144		—		2,426
Total revenues	43,439		766,769		—		810,208
Cost of revenues (exclusive of depreciation and amortization shown separately below)	35,299		715,164		—		750,463
Depreciation and amortization attributable to costs of revenues	939		3,111		—		4,050
Gross profit	7,201		48,494		—		55,695
Selling, general and administrative expenses	4,919		27,988		4,071		36,978
Depreciation and amortization attributable to operating expenses	39		850		231		1,120
Income (loss) from operations	$	2,243	$	19,656	$	(4,302)	$	17,597

Capital expenditures	$	412	$	26,333	$	—	$	26,745


THREE MONTHS ENDED SEPTEMBER 30, 2021
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Revenues:
Refined products	$	20,339	$	20,419	$	—	$	40,758
Re-refined products	5,237		4,153		—		9,390
Services	834		—		—		834
Total revenues	26,410		24,572		—		50,982
Cost of revenues (exclusive of depreciation and amortization shown separately below)	22,205		23,937		—		46,142
Depreciation and amortization attributable to costs of revenues	901		127		—		1,028
Gross profit	3,304		508		—		3,812
Selling, general and administrative expenses	3,618		1,034		3,525		8,177
Depreciation and amortization attributable to operating expenses	59		108		253		420
Loss from operations	$	(373)	$	(634)	$	(3,778)	$	(4,785)

Capital expenditures	$	228	$	—	$	—	$	228


NINE MONTHS ENDED SEPTEMBER 30, 2022
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Revenues:
Refined products	$	129,078	$	1,595,070	$	—	$	1,724,148
Re-refined products	17,191		168,356		—		185,547
Services	1,276		4,452		—		5,728
Total revenues	147,545		1,767,878		—		1,915,423
Cost of revenues (exclusive of depreciation and amortization shown separately below)	111,740		1,708,017		—		1,819,757
Depreciation and amortization attributable to costs of revenues	2,805		6,339		—		9,144
Gross profit	33,000		53,522		—		86,522
Selling, general and administrative expenses	13,383		52,709		23,842		89,934
Depreciation and amortization attributable to operating expenses	142		1,785		729		2,656
Income (loss) from operations	$	19,475	$	(972)	$	(24,571)	$	(6,068)

Capital expenditures	$	2,830	$	142,927	$	—	$	145,757


NINE MONTHS ENDED SEPTEMBER 30, 2021
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Revenues:
Refined products	$	58,039	$	55,974	$	—	$	114,013
Re-refined products	19,218		11,709		—		30,927
Services	2,867		—		—		2,867
Total revenues	80,124		67,683		—		147,807
Cost of revenues (exclusive of depreciation and amortization shown separately below)	63,431		64,555		—		127,986
Depreciation and amortization attributable to costs of revenues	2,623		379		—		3,002
Gross profit	14,070		2,749		—		16,819
Selling, general and administrative expenses	10,841		2,482		8,419		21,742
Depreciation and amortization attributable to operating expenses	176		325		759		1,260
Income (loss) from operations	$	3,053	$	(58)	$	(9,178)	$	(6,183)

Capital expenditures	$	2,313	$	—	$	—	$	2,313

Total assets by segment were as follows (in thousands):


AS OF SEPTEMBER 30, 2022
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Total assets	$	123,808	$	395,692	$	128,077	$	647,577

AS OF SEPTEMBER 30, 2021
	Black Oil & Recovery		Refining & Marketing		Corporate and Eliminations		Consolidated
Total assets	$	101,461	$	4,775	$	38,414	$	144,650

Segment assets for the Refining and Marketing and Black Oil and Recovery segments consist of property, plant, and equipment, right-of-use assets, intangible assets, accounts receivable, inventories and other assets. Assets for the corporate unallocated amounts consist of property, plant, and equipment used at the corporate headquarters, intangible assets, derivative commodity assets, assets held for sale as well as cash.

NOTE 7. ACCOUNTS RECEIVABLE

Accounts receivable, net, consists of the following at September 30, 2022 and December 31, 2021(in thousands):


	September 30, 2022		December 31, 2021
Accounts receivable trade	$	52,338	$	16,302
Allowance for doubtful accounts	(1,509)		(1,422)
Accounts receivable trade, net	50,829		14,880
Accounts receivable other	1,001		—
Accounts receivable, net	$	51,830	$	14,880

Accounts receivable trade represents amounts due from customers. Accounts receivable trade are recorded at invoiced amounts, net of reserves and allowances and do not bear interest.

NOTE 8. CONCENTRATIONS OF RISK AND SIGNIFICANT CUSTOMERS

At September 30, 2022 and 2021 and for each of the nine months then ended, the Company’s revenues and receivables were comprised of the following customer concentrations:


	As of and for the Nine Months Ended
	September 30, 2022		September 30, 2021
	% of Revenues	% of Receivables	% of Revenues	% of Receivables
Customer 1	40%	2%	34%	11%
Customer 2	22%	45%	12%	6%
Customer 3	10%	7%	9%	5%

For each of the nine months ended September 30, 2022 and 2021, the Company’s segment revenues were comprised of the following customer concentrations:


	% of Revenue by Segment		% Revenue by Segment
	Nine Months Ended September 30, 2022		Nine Months Ended September 30, 2021
	Black Oil and Recovery	Refining		Black Oil and Recovery	Refining
Customer 1	—%	43%		—%	27%
Customer 2	—%	24%		—%	20%
Customer 3	83%	4%		64%	—%

The Company had one vendor that represented 57% of total purchases and 49% of total payables for the nine months ended September 30, 2022, and one vendor that represented 38% of total purchases and 26% of total payables at September 30, 2021.

NOTE 9. INVENTORY

The following table describes the Company's inventory balances by category (in thousands):



	As of September 30, 2022		As of December 31, 2021
Crude oil	$	60,504	$	926
Refined products	97,568		4,729
Re-refined products	6,590		2,376
Total hydrocarbon inventories	164,662		8,031
Other inventories	5,110		—
Total inventories	$	169,772	$	8,031

NOTE 10. INVENTORY FINANCING AGREEMENT

On April 1, 2022, pursuant to an Inventory Sales Agreement entered into between Vertex Refining and Macquarie, Macquarie purchased all the Mobile Refinery Inventory from Vertex Refining for $130 million (which funds, together with cash on hand, were used by Vertex Refining to purchase the Mobile Refinery Inventory from Shell), which Mobile Refinery Inventory then became subject to the terms of the Supply and Offtake Agreement, discussed in detail below. The following table summarizes our outstanding obligations under our inventory financing agreements as of September 30, 2022 (in thousands):


	September 30, 2022
Obligations under inventory financing agreement	$	135,744
Unamortized financing cost	(1,500)
Obligations under inventory financing agreement, net	$	134,244

The valuation of our obligations at the end of each reporting period requires that we make estimates of the prices and differentials for our then monthly forward purchase obligations.

Supply and Offtake Agreement

On April 1, 2022 (the “Commencement Date”), Vertex Refining entered into a Supply and Offtake Agreement (the “Supply and Offtake Agreement”) with Macquarie, pertaining to crude oil supply and offtake of finished products located at the Mobile Refinery acquired on April 1, 2022. On the Commencement Date, pursuant to an Inventory Sales Agreement and in connection with the Supply and Offtake Agreement, Macquarie purchased from Vertex Refining all crude oil and finished products within the categories covered by the Supply and Offtake Agreement and the Inventory Sales Agreement, which were held at the Mobile Refinery and a certain specified third party storage terminal, which were previously purchased by Vertex Refining as part of the acquisition of the Mobile Refinery as discussed in greater detail above in Note 3. "Mobile Refinery Acquisition".

Pursuant to the Supply and Offtake Agreement, beginning on the Commencement Date and subject to certain exceptions, substantially all of the crude oil located at the Mobile Refinery and at a specified third party storage terminal from time to time will be owned by Macquarie prior to its sale to Vertex Refining for consumption within the Mobile Refinery processing units. Also pursuant to the Supply and Offtake Agreement, and subject to the terms and conditions and certain exceptions set forth therein, Macquarie will purchase from Vertex Refining substantially all of the Mobile Refinery’s output of certain refined products and will own such refined products while they are located within certain specified locations at the Mobile Refinery. Macquarie takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by Macquarie on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we have an obligation to repurchase it.

Pursuant to the Supply and Offtake Agreement and subject to the terms and conditions therein, Macquarie may during the term of the Supply and Offtake Agreement procure crude oil and refined products from certain third parties which may be sold to Vertex Refining or third parties pursuant to the Supply and Offtake Agreement and may sell Refined Products to Vertex Refining or third parties (including customers of Vertex Refining).

The obligations of Vertex Refining and any of its subsidiaries under the Supply and Offtake Agreement and related transaction documents are guaranteed by the Company. The obligations of Vertex Refining and any of its subsidiaries under the Supply and Offtake Agreement and related transaction documents are also secured by a Pledge and Security Agreement in favor of Macquarie, discussed below, executed by Vertex Refining. In addition, the Supply and Offtake Agreement also requires that Vertex Refining post and maintain cash collateral (in the form of an independent amount) as security for Vertex Refining’s obligations under the Supply and Offtake Agreement and the related transaction documents. The amount of cash collateral is subject to adjustments during the term.

Pursuant to the Supply and Offtake Agreement, Vertex Refining and Macquarie are in discussions to cooperate to develop and document, by no later than 180 days after the Commencement Date, procedures relating to the unwinding and termination of the agreement and related agreements, in the event of the expiration or early termination of the Supply and Offtake Agreement. The parties also agreed to use commercially reasonable efforts to negotiate mutually agreeable terms for Macquarie’s intermediating of renewable feedstocks and renewable diesel that will be utilized and/or produced by Vertex Refining in connection with and following a planned renewable diesel conversion project at the Mobile Refinery (including providing Macquarie a right of first refusal in connection therewith), for 90 days after the Commencement Date (the “RD Period”), which discussions are ongoing. If, by the end of the RD Period, Macquarie and Vertex Refining, each acting in good faith and in a commercially reasonable manner, have not been able to reach commercial agreement regarding the entry into a renewable diesel intermediation, Vertex Refining may elect to terminate the Supply and Offtake Agreement by providing notice of any such election to Macquarie; provided that no such election may be effective earlier than the date falling 90 calendar days following the date on which such notice is delivered. The agreement is also subject to termination upon the occurrence of certain events, including the termination of certain agreements relating to the delivery of crude oil to and the offtake of products from the Mobile Refinery. Upon an early termination of the Supply and Offtake Agreement, Vertex Refining is required to pay amounts relating to such termination to Macquarie including, among other things, outstanding unpaid amounts, amounts owing

with respect to terminating transactions under the Supply and Offtake Agreement and related transaction documents, unpaid ancillary costs, and breakage costs, losses and out-of-pocket costs with respect to the termination, liquidation, maintenance or reestablishment, or redeployment of certain hedges put in place by Macquarie in connection with the transactions contemplated by the agreement, and Vertex Refining is required to pay other termination fees and amounts to Macquarie in the event of any termination of the agreement. Additionally, upon the termination of the Supply and Offtake Agreement, the outstanding obligations of Vertex Refining and Macquarie to each other will be calculated and reduced to an estimated net settlement payment which will be subject to true-up when the final settlement payment has been calculated following termination.

The Supply and Offtake Agreement requires Vertex Refining to prepare and deliver certain forecasts, projections and estimates and comply with financial statement delivery obligations and other disclosure obligations. The agreement also requires Vertex Refining to provide Macquarie notice of certain estimated monthly crude oil delivery, crude oil consumption, product production, target inventory levels and product offtake terms, which Macquarie has the right to reject, subject to certain disclosure requirements.

The Supply and Offtake Agreement has a 24 month term following the Commencement Date, subject to the performance of customary covenants, and certain events of default and termination events provided therein (certain of which are discussed in greater detail below), for a facility of this size and type. Additionally, either party may terminate the agreement at any time, for any reason, with no less than 180 days prior notice to the other.

The Supply and Offtake Agreement includes certain customary representations, warranties, indemnification obligations and limitations of liability of the parties for a facility of this size and type, and also requires Vertex Refining to be responsible for certain ancillary costs relating to the Supply and Offtake Agreement and the transactions contemplated thereby. The Supply and Offtake Agreement requires Vertex Refining to comply with various indemnity, insurance and tax obligations, and also includes a prohibition on any amendments to Vertex Refining’s financing agreements which, among other things, adversely affect Macquarie’s rights and remedies under the Supply and Offtake Agreement and related transaction documents without the prior consent of Macquarie; a prohibition on Vertex Refining entering into any financing agreement which would cause Vertex Refining’s specified indebtedness to exceed $10 million without Macquarie’s prior consent, subject to certain exceptions; and a requirement that Vertex Refining not have less than $17.5 million in unrestricted cash for any period of more than three consecutive business days. The Supply and Offtake Agreement includes events of default and termination events, including if the Company ceases to beneficially own, directly or indirectly, 100% of the capital stock of Vertex Refining; the change in ownership of the Company or Vertex Refining resulting in one person or group acquiring 50% or more of the capital stock of the Company or Vertex Refining (as applicable); or a change in a majority of the Board of Directors of the Company or Vertex Refining during any 12 consecutive months, without certain approvals, including the approval of the Board of Directors of the Company or Vertex Refining (as applicable) immediately prior to such change; and a cross default to indebtedness (other than indebtedness under financing agreements) of the Company or Vertex Refining for over $20 million, a cross default to indebtedness under financing agreements of Vertex Refining or the Company, or a final judgment or order being rendered against Vertex Refining or the Company in an amount exceeding $20 million.

The price for crude oil purchased by the Company from Macquarie and for products sold by the Company to Macquarie within each agreed product group, in each case, is equal to a pre-determined benchmark, plus a pre-agreed upon differential, subject to adjustments and monthly true-ups.

Vertex Refining is required to pay Macquarie various monthly fees in connection with the Supply and Offtake Agreement and related arrangements, including, without limitation, (1) an inventory management fee, calculated based on the value of the inventory owned by Macquarie in connection with the Supply and Offtake Agreement, (2) a lien inventory fee based upon the value of certain inventory on which Macquarie has a lien, (3) a per barrel crude handling fee based upon the volume of crude oil Macquarie sells to Vertex Refining, (4) per barrel crude oil and products intermediation fees for each barrel of crude oil which Macquarie buys from a third party and each barrel of products Macquarie sells to a third party, in each case, in connection with the Supply and Offtake Agreement, and (5) a services fee in respect of which Macquarie agrees to make Crude Oil and Products available to the Company in accordance with the weekly nomination procedure as set forth in the Supply and Offtake Agreement. Vertex Refining will also be responsible for certain payments relating to Macquarie’s hedging of the inventory it owns in connection with the Supply and Offtake Agreement, including the costs of rolling hedges forward each month, as well as any costs (or gains) resulting from a mismatch between the Company’s projected target inventory levels (which provide the basis for Macquarie’s hedge position) and actual month end inventory levels.

In connection with the entry into the Supply and Offtake Agreement, Vertex Refining entered into various ancillary agreements which relate to supply, storage, marketing and sales of crude oil and refined products including, but not limited to the following: Inventory Sales Agreement, Master Crude Oil and Products Agreement, Storage and Services Agreement, and a Pledge and Security Agreement (collectively with the Supply and Offtake Agreement, the “Supply Transaction Documents”).

The Company agreed to guarantee the obligations of Vertex Refining and any of its subsidiaries arising under the Supply Transaction Documents pursuant to the entry into a Guaranty in favor of Macquarie.

Tripartite Agreements

Also on the Commencement Date, Vertex Refining, Macquarie and certain parties subject to crude oil supply and products offtake agreements with Vertex Refining, relating to the Mobile Refinery, entered into various tripartite agreements (the “Tripartite Agreements”), whereby Vertex Refining granted Macquarie the right, on a rolling daily or monthly basis, as applicable, to elect to assume Vertex Refining’s rights and obligations under such crude oil supply and products offtake agreements in connection with the performance of the Supply and Offtake Agreement, and the counterparties thereto are deemed to have consented to Macquarie’s assuming such obligations. Such Tripartite Agreements also provided for certain interpretations of the provisions of such supply and offtake agreements between Vertex Refining and such third parties in connection with Macquarie’s right to elect to assume Vertex Refining’s rights and obligations under such agreements. The Tripartite Agreements remain in place until the termination of the agreements to which they relate, or the earlier termination thereof as set forth in the Tripartite Agreements, including in the event of certain events of default by the parties thereto under the modified crude oil supply and products offtake agreements or the Supply and Offtake Agreement and related transaction documents and also in the event of the termination of the Supply and Offtake Agreement. Macquarie, Vertex Refining and a third party offtaker also entered into a tripartite agreement pursuant to which certain storage capacity within the Mobile Refinery which Macquarie had leased pursuant to the Storage and Services Agreement was effectively made available to such third party consistent with the terms agreed by such party and Vertex Refining in its underlying products offtake agreement. Macquarie, Vertex Refining and a third party storage terminal operator also entered into a tripartite agreement relating to the storage of Macquarie-owned crude oil in such terminal in connection with the Supply and Offtake Agreement.

Guaranty

Vertex Refining’s obligations under the Supply and Offtake Agreement and related transaction documents (other than the hedges which are secured and guaranteed on a pari passu basis under the Loan and Security Agreement) were unconditionally guaranteed by the Company pursuant to the terms of a Guaranty entered into on April 1, 2022, by the Company in favor of Macquarie (the “Guaranty”).

NOTE 11. PREPAID EXPENSES AND OTHER CURRENT ASSETS

The following table describes the Company's prepaid expenses and other current assets balances (in thousands):


	As of September 30, 2022		As of December 31, 2021
Prepaid insurance	$	15,168	$	2,638
Commodity derivative advance	12,468		556
Renewable volume obligation (RVO) assets	1,389		—
Other prepaid expenses	4,312		1,373
Total prepaid expenses	$	33,337	$	4,567

NOTE 12. FIXED ASSETS, NET

Fixed assets consist of the following (in thousands):


	Useful Life (in years)	September 30, 2022		December 31, 2021
Equipment	10	$	116,370	$	38,682
Furniture and fixtures	7	106		106
Leasehold improvements	15	2,779		2,473
Office equipment	5	1,433		1,183
Vehicles	5	8,168		6,999
Building	20	2,334		274
Land improvements	20	158		—
Construction in progress		57,730		10,484
Land		9,010		1,995
Total fixed assets		198,088		62,196
Less accumulated depreciation		(33,371)		(26,043)
Net fixed assets		$	164,717	$	36,153

The increase in fixed assets is due to the fixed assets acquired by the acquisition of the Mobile Refinery on April 1, 2022. Depreciation expense was $3.3 million and $1.0 million for the three months ended September 30, 2022 and 2021, respectively, for the continued operations. Depreciation expense was $7.6 million and $2.9 million for the nine months ended September 30, 2022 and 2021, respectively for the continued operations.

Asset Retirement Obligations:

The Company has asset retirement obligations with respect to certain of its refinery assets due to various legal obligations to clean and/or dispose of various component parts of each refinery at the time they are retired. However, these component parts can be used for extended and indeterminate periods of time as long as they are properly maintained and/or upgraded. It is the Company’s practice and current intent to maintain its refinery assets and continue making improvements to those assets based on technological advances. As a result, the Company believes that its refinery assets have indeterminate lives for purposes of estimating asset retirement obligations because dates, or ranges of dates, upon which the Company would retire refinery assets cannot reasonably be estimated. When a date or range of dates can reasonably be estimated for the retirement of any component part of a refinery, the Company estimates the cost of performing the retirement activities and records a liability for the fair value of that cost using established present value techniques.

NOTE 13. INTANGIBLE ASSETS, NET

Components of intangible assets (subject to amortization) consist of the following items:


		September 30, 2022						December 31, 2021
	Useful Life (in years)	Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount		Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount
Customer relations	5	$	978	$	971	$	7	$	978	$	940	$	38
Vendor relations	10	4,778		4,557		221		4,778		4,199		579
Trademark/Trade name	15	887		595		292		887		550		337
TCEP Technology/Patent	15	13,287		8,617		4,670		13,287		7,952		5,335
Non-compete	3	197		196		1		197		192		5
Software	3	9,344		1,732		7,612		538		180		358
		$	29,471	$	16,668	$	12,803	$	20,665	$	14,013	$	6,652

Intangible assets are amortized on a straight-line basis. We continually evaluate the amortization period and carrying basis of intangible assets to determine whether subsequent events and circumstances warrant a revised estimated useful life or reduction in value.

Total amortization expense of intangibles was $1.1 million and $0.4 million for the three months ended September 30, 2022 and 2021, respectively. Total amortization expense of intangibles was $2.7 million and $1.3 million for the nine months ended September 30, 2022 and 2021, respectively.

Estimated future amortization expense is as follows (in thousands):


Year 1	$	4,061
Year 2	4,005
Year 3	2,549
Year 4	950
Year 5	948
Thereafter	290
	$	12,803

NOTE 14. ACCRUED LIABILITIES

Accrued expenses and other current liabilities consisted of the following (in thousands):


	September 30, 2022		December 31, 2021
Accrued purchases	$	18,496	$	1,877
Accrued interest	1		1,594
Accrued compensation and benefits	3,625		1,082
Accrued income, real estate, sales and other taxes	1,454		389
RINS liabilities	19,023		—
Environmental liabilities - current	51		—
	$	42,650	$	4,942

The increase in accrued liabilities from December 31, 2021 is due to the operation of the Mobile Refinery, which was acquired on April 1, 2022.

NOTE 15. LONG-TERM DEBT

The Company's long-term debt consisted of the following as of September 30, 2022 and December 31, 2021 (in thousands):


Creditor	Loan Type	Balance on September 30, 2022		Balance on December 31, 2021
Senior Convertible Note	Convertible note	$	95,178	$	155,000
Term Loan 2025	Loan	165,000		—
John Deere Note	Note	—		94
SBA Loan	SBA Loan	59		59

Various institutions	Insurance premiums financed	10,449		2,375
Principal amount of long-term debt		270,686		157,528
Less: unamortized discount and deferred financing costs		(86,384)		(90,984)
Total debt, net of unamortized discount and deferred financing costs		184,302		66,544
Less: current maturities, net of unamortized discount and deferred financing costs		(16,637)		(2,413)
Long term debt, net of current maturities		$	167,665	$	64,131

Future maturities of long-term debt, excluding financing lease obligations, as of September 30, 2022 are summarized as follows (in thousands):


Period Ended September 30,	Amount Due
2023	$	16,637
2024	8,252
2025	150,563
2026	1
2027	95,180
Thereafter	53
Total	$	270,686

Term Loan

On April 1, 2022 (the “Closing Date”), Vertex Refining; the Company, as a guarantor; substantially all of the Company’s direct and indirect subsidiaries, as guarantors (together with the Company, the “Initial Guarantors”); certain funds and accounts under management by BlackRock Financial Management, Inc. or its affiliates, as lenders (“BlackRock”), certain funds managed or advised by Whitebox Advisors, LLC, as lenders (“Whitebox”), certain funds managed by Highbridge Capital Management, LLC, as lenders (“Highbridge”), Chambers Energy Capital IV, LP, as a lender (“Chambers”), CrowdOut Capital LLC, as a lender (“CrowdOut Capital”), CrowdOut Credit Opportunities Fund LLC, as a lender (collectively with BlackRock, Whitebox, Highbridge, Chambers and CrowdOut Capital, the “Lenders”); and Cantor Fitzgerald Securities, in its capacity as administrative agent and collateral agent for the Lenders (the “Agent”), entered into a Loan and Security Agreement (the “Loan and Security Agreement”).

Pursuant to the Loan and Security Agreement, the Lenders agreed to provide a $125 million term loan to Vertex Refining (the “Initial Term Loan”), the proceeds of which, less agreed upon fees and discounts, were held in escrow prior to the Closing Date, pursuant to an Escrow Agreement. On the Closing Date, net proceeds from the term loans, less the agreed upon fees and discounts, as well as certain transaction expenses, were released from escrow to Vertex Refining in an aggregate amount of $94 million.

On May 26, 2022, each of the Initial Guarantors (including the Company), Vertex Refining OH, LLC, which is indirectly wholly-owned by the Company ("Vertex OH"), Heartland SPV, and Tensile-Heartland Acquisition Corporation, a Delaware corporation (“Tensile-Heartland”, and together with Vertex Ohio and Heartland SPV, the “Additional Guarantors”, and the Additional Guarantors, together with the Initial Guarantors, the “Guarantors”, and the Guarantors, together with Vertex Refining, the “Loan Parties”), entered into an Amendment Number One to Loan and Security Agreement (“Amendment No. One to Loan Agreement”), with certain of the Lenders and CrowdOut Warehouse LLC, as a lender (the “Additional Lenders” and together with the Initial Lenders, the “Lenders”) and the Agent, pursuant to which, the amount of the Term Loan (as defined below) was increased from $125 million to $165 million, with the Additional Lenders providing an additional term loan in the amount of $40 million (the “Additional Term Loan”, and together with the Initial Term Loan, the “Term Loan”).

Pursuant to the Loan and Security Agreement, on the last day of March, June, September and December of each year (or if such day is not a business day, the next succeeding business day), beginning on March 31, 2023 and ending on December 31, 2024, Vertex Refining is required to repay $2 million of the principal amount owed under the Loan and Security Agreement (i.e., 1.25% of the original principal amount per quarter), subject to reductions in the event of any prepayment of the Loan and Security Agreement.

The Company used a portion of the proceeds from the Term Loan borrowing to pay a portion of the purchase price associated with the acquisition of the Mobile Refinery (defined above) acquired by Vertex Refining on April 1, 2022, as discussed in greater detail above, and to pay certain fees and expenses associated with the closing of the Loan and Security Agreement and is required to use the remainder of the funds for (i) the planned renewable diesel conversion of the Mobile Refinery, and (ii) working capital and liquidity needs.

On September 30, 2022, Vertex Refining; the Company, as a guarantor; substantially all of the Company’s direct and indirect subsidiaries, as guarantors; Vertex Marine Fuel Services LLC (“Vertex Marine”) and Vertex Refining Texas LLC (“Vertex Texas,” and together with Vertex Marine, the “New Subsidiary Guarantors”), which are indirectly wholly-owned by the Company; the lenders thereto; and the Agent, entered into a second amendment (“Amendment No. Two”) to the Loan and Security Agreement.

Amendment No. Two (a) extends the date that the Company is required to begin initial commercial production of renewable diesel at the Mobile Refinery, from February 28, 2023 to April 28, 2023, and provides other corresponding extensions of the milestones required to complete the Company’s capital project designed to modify the Mobile Refinery’s existing hydrocracking unit to produce renewable diesel fuel on a standalone basis, which as previously described, is currently anticipated for mechanical completion during the first quarter of 2023; and (b) waives and extends certain deadlines and time periods for the Company to take other actions in connection with the Loan and Security Agreement.

In addition, each of the New Subsidiary Guarantors also entered into a Guarantor Joinder, agreeing to be bound by the terms of the Loan and Security Agreement, and to guaranty the amounts owed thereunder.

Warrant Agreement and Derivative Liabilities

In connection with the Loan and Security Agreement, and as additional consideration for the Lenders agreeing to loan funds to the Company thereunder, the Company granted warrants to purchase 2.75 million shares of common stock of the Company to the Lenders (and/or their affiliates) on the Closing Date (the “Initial Warrants”). The terms of the warrants are set forth in a Warrant Agreement (the “April 2022 Warrant Agreement”) entered into on April 1, 2022, between the Company and Continental Stock Transfer & Trust Company as warrant agent.

In connection with the entry into the Amendment No. One to Loan Agreement, and as a required term and condition thereof, on May 26, 2022, the Company granted warrants (the “Additional Warrants” and together with the Initial Warrants, the “Warrants”) to purchase 250 thousand shares of the Company’s common stock to the Additional Lenders and their affiliates. The terms of the Additional Warrants are set forth in a Warrant Agreement (the “May 2022 Warrant Agreement” and together with the April 2022 Warrant Agreement, the “Warrant Agreements”) entered into on May 26, 2022, between the Company and Continental Stock Transfer & Trust Company as warrant agent.

Each Warrant holder has a put right to require the Company to repurchase any portion of the warrants held by such holder concurrently with the consummation of such fundamental transaction. The fundamental transaction clause requires the warrants to be classified as liabilities.

Indenture and Convertible Senior Notes

On November 1, 2021, we issued $155 million aggregate principal amount at maturity of our 6.25% Convertible Senior Notes due 2027 (the “Convertible Senior Notes”) pursuant to an Indenture (the “Indenture”), dated November 1, 2021, between the Company and U.S. Bank National Association, as trustee (the “Trustee”), in a private offering (the “Note Offering”) to persons reasonably believed to be “qualified institutional buyers” and/or to “accredited investors” in reliance on the exemption from registration provided by Section 4(a)(2) of the Securities Act of 1933, as amended (the "Securities Act"), pursuant to Securities Purchase Agreements. The issue price was 90% of the face amount of each note. Interest payments on the Notes are paid semiannually on April 1 and October 1 of each year, beginning on April 1, 2022. As of October 1, 2022, a total of $7 million of interest was paid on our outstanding Convertible Senior Notes.

A total of seventy-five percent (75%) of the net proceeds from the offering were placed into an escrow account to be released to the Company, upon the satisfaction of certain conditions, including the satisfaction or waiver of all of the conditions precedent to the Company’s obligation to consummate the Mobile Acquisition (collectively, the “Escrow Release Conditions”). The Mobile Acquisition was consummated on April 1, 2022, and the proceeds from the sale of the Convertible Senior Notes which were held in escrow were released on April 1, 2022.

Prior to July 1, 2027, the Convertible Senior Notes are convertible at the option of the holders of the Convertible Senior Notes only upon the satisfaction of certain conditions and during certain periods, and thereafter, at any time until the close of business on the second scheduled trading day immediately preceding the maturity date.

Upon conversion, the Company will pay or deliver, as the case may be, cash, shares of its common stock or a combination of cash and shares of its common stock, at its election, provided that until such time as the Company’s stockholders had approved

the issuance of more than 19.99% of our common stock issuable upon conversion of the Convertible Senior Notes in accordance with the rules of The Nasdaq Capital Market, such Convertible Senior Notes were not convertible.

Initially, a maximum of 36 million shares of common stock can be issued upon conversion of the Convertible Senior Notes, based on the initial maximum conversion rate of 233.6449 shares of the Company’s common stock per $1,000 principal amount of Convertible Senior Notes, which is subject to customary and other adjustments described in the Indenture.

On January 20, 2022, our shareholders approved the issuance of shares of our common stock issuable upon conversion of the Convertible Senior Notes, in accordance with Nasdaq Listing Rules 5635 (a) and (d). Accordingly, $79 million of derivative Convertible Senior Note liabilities were reclassified to additional paid in capital.

On May 26, 2022, May 27, 2022, May 31, 2022, and June 1, 2022, holders of an aggregate of $60 million of the Convertible Senior Notes due 2027, converted such notes into 10.2 million shares of common stock of the Company pursuant to the terms of the Indenture. Upon the conversion, the Company recognized $33.9 million unamortized deferred loan cost and discount as interest expense.

The components of the Convertible Senior Notes are presented as follows (in thousands):


	September 30, 2022
Principal Amounts	$	155,000
Conversion of principal into common stock	(59,822)
Outstanding principal amount	95,178
Unamortized discount and issuance costs	(52,362)
Net Carrying Amount	$	42,816

Our Convertible Senior Notes will mature on October 1, 2027, unless earlier repurchased, redeemed or converted. Interest is payable semiannually in arrears on April 1 and October 1 of each year, beginning on April 1, 2022.

NOTE 16. LEASES

Finance Leases

The Company's finance leases liabilities consisted of the following as of September 30, 2022 and December 31, 2021 (in thousands):


Creditor	Loan Type	Balance on September 30, 2022		Balance on December 31, 2021
AVT Equipment Lease-HH	Finance Lease	$	—	$	302
AVT Equipment Lease-Ohio	Finance Lease	—		296
VRA Finance Lease	Finance Lease	45,494		—
		$	45,494	$	598

Future maturities of finance lease obligations, as of September 30, 2022 are summarized as follows (in thousands):


Period Ended September 30,	Amount Due
2023	$	1,155
2024	1,301
2025	1,466
2026	1,652
2027	1,862
Thereafter	38,058
Total	$	45,494

On April 1, 2022, the Company entered into one finance lease. Base payments are $0.4 million per month for the first six months, increasing to $0.5 million per month for the next 180 months. The amount of the right of use assets is $43.6 million at September 30, 2022, and the finance lease obligation is $45.5 million at September 30, 2022. The associated amortization expenses for the three months ended September 30, 2022 and 2021 were $0.7 million and $28.7 thousand, respectively, and are included in depreciation and amortization on the unaudited consolidated statements of operations. The associated interest expense for the three months ended September 30, 2022 and 2021 were $1.4 million and $19.4 thousand, respectively, and are included in interest expense on the unaudited consolidated statements of operations. The associated amortization expenses for the nine months ended September 30, 2022 and 2021 were $0.7 million and $86.0 thousand, respectively, and are included in depreciation and amortization on the unaudited consolidated statements of operations. The associated interest expense for the nine months ended September 30, 2022 and 2021 were $2.7 million and $37 thousand, respectively, and are included in interest expense on the unaudited consolidated statements of operations.

Operating Leases

Operating leases are included in operating lease right-of-use lease assets, and operating current and long-term lease liabilities on the consolidated balance sheets. Lease expense for operating leases is recognized on a straight-line basis over the lease term. Variable lease expense is recognized in the period in which the obligation for those payments is incurred. Lease expense for equipment is included in cost of revenues and other rents are included in selling, general and administrative expense on the unaudited consolidated statements of operations and are reported net of lease income. Lease income is not material to the results of operations for the three and nine months ended September 30, 2022 and 2021. Total operating lease costs for both the three months ended September 30, 2022 and 2021 were $1.5 million and $1.4 million, respectively. Total operating lease costs for both the nine months ended September 30, 2022 and 2021 were $4.4 million and $4.2 million, respectively.

Cash Flows

Cash paid for amounts included in operating lease liabilities was $4.4 million and $4.2 million during the nine months ended September 30, 2022 and 2021, respectively, and is included in operating cash flows. Cash paid for amounts included in finance lease was $201 thousand and $409 thousand during the nine months ended September 30, 2022 and 2021, respectively, and is included in financing cash flows.

Maturities of our lease liabilities for all operating leases are as follows as of September 30, 2022 (in thousands):


September 30, 2022
	Facilities		Equipment		Plant		Railcar		Total
Year 1	$	715	$	262	$	4,111	$	1,333	$	6,421
Year 2	495		262		4,111		1,437		6,305
Year 3	394		259		4,111		489		5,253
Year 4	306		259		4,111		305		4,981
Year 5	300		234		4,111		181		4,826
Thereafter	1,550		—		22,482		—		24,032
Total lease payments	3,760		1,276		43,037		3,745		51,818
Less: interest	(1,139)		(218)		(15,728)		(773)		(17,858)
Present value of operating lease liabilities	$	2,621	$	1,058	$	27,309	$	2,972	$	33,960

The weighted average remaining lease terms and discount rates for all of our operating leases were as follows as of September 30, 2022:


Remaining lease term and discount rate:	September 30, 2022
Weighted average remaining lease terms (years)
Lease facilities	4.79
Lease equipment	10.69
Lease plant	10.47
Lease railcar	3.22
Weighted average discount rate
Lease facilities	9.13	%
Lease equipment	7.97	%
Lease plant	9.37	%
Lease railcar	8.00	%

The plant lease has multiple 5-year extension options for a total of 20 years. The extension option has been included in the lease right-of-use asset and lease obligation.

The Company will reassess the lease terms and purchase options when there is a significant change in circumstances or when the Company elects to exercise an option that had previously been determined that it was not reasonably certain to do so.

NOTE 17. EQUITY

During the nine months ended September 30, 2022, the Company issued 385,593 shares of common stock in connection with the conversion of Series A Convertible Preferred Stock, pursuant to the terms of such securities, issued 1,112,728 shares of the Company's common stock in exchange for warrants to purchase 1,500,000 shares of the Company's common stock with an exercise price of $2.25 per share, issued 96,074 shares of the Company's common stock in exchange for warrants to purchase 165,100 shares of the Company's common stock with an exercise price of $4.50 per share on a cash and cashless basis, and issued 10,165,149 shares of the Company's common stock in conversion of $59,822,000 in Convertible Senior Notes. In addition, the Company issued 561,317 shares of common stock in connection with the exercise of options.

During the nine months ended September 30, 2021, the Company issued 13,826,010 shares of common stock in connection with the conversion of Series A, Series B & B1 Convertible Preferred Stock (which has since been fully converted and terminated) and exercises of warrants into common stock of the Company, pursuant to the terms of such securities. In addition, the Company issued 528,368 shares of common stock in connection with the exercise of options.

Warrant Exchange Agreement. On March 24, 2022, the Company entered into an Exchange Agreement with Tensile Capital Partners Master Fund LP (the “Holder” and "Tensile"). The Holder agreed to exchange outstanding warrants to purchase 1,500,000 shares of the Company’s common stock with an exercise price of $2.25 per share and an expiration date of July 25, 2029, for 1,112,728 shares of the Company’s common stock, effectively resulting in a net cashless exercise of the warrants (which were cancelled in connection with the transaction), with the value of such surrendered shares based on the five day trailing volume weighted average price of the Company’s common stock.

Warrant Agreement in connection with term loan. On July 11, 2022, the holders of warrants to purchase 165,000 shares of the Company’s common stock exercised warrants to purchase 165,000 shares of the Company's common stock with an exercise price of $4.50 per share and an expiration date of April 1, 2027, on a cashless basis, and were issued 95,974 shares of the Company’s common stock, with the value of such surrendered shares based on the five day trailing volume weighted average price of the Company’s common stock.

On July 22, 2022, the holders of warrants to purchase 100 shares of common stock exercised warrants to purchase 100 shares of the Company's common stock with an exercise price of $4.50 per share and were issued 100 shares of common stock.

Conversion of Convertible Senior Notes. On May 26, 2022, May 27, 2022, May 31, 2022, and June 1, 2022, holders of an aggregate of $59,822,000 of the Company’s 6.25% Convertible Senior Notes due 2027, converted such notes into 10,165,149 shares of common stock of the Company pursuant to the terms of the Indenture.

Conversion of Series A Preferred Stock. Pursuant to the prior designation of the rights and preferences of the Series A Convertible Preferred Stock of the Company, each share of Series A Convertible Preferred Stock was to be automatically converted into shares of common stock of the Company (on a one-for-one basis), automatically and without further action by the Company or any holder, upon the first to occur of certain events, including if the closing price of the Company’s common stock on the Nasdaq Capital Market averaged at least $15.00 per share over a period of 20 consecutive trading days and the daily trading volume over the same 20-day period averaged at least 7,500 shares (the “Automatic Conversion Provision”).

Effective on June 10, 2022, the Automatic Conversion Provision of the Series A Convertible Preferred Stock was triggered, and the 374,337 then outstanding shares of the Company’s Series A Convertible Preferred Stock automatically converted into 374,337 shares of common stock of the Company and on June 10, 2022, all rights of any holder with respect to the shares of the Series A Convertible Preferred Stock so converted, including the rights, if any, to receive distributions of the Company’s assets terminated, except only for the rights of such holders to receive certificates for the number of whole shares of common stock into which such shares of the Series A Convertible Preferred Stock were converted.

Preferred Stock and Detachable Warrants. The total number of authorized shares of the Company’s preferred stock is 50,000,000 shares, $0.001 par value per share. The total number of designated shares of the Company’s Series A Convertible Preferred Stock is 0 and 5,000,000, as of September 30, 2022 and December 31, 2021 (“Series A Preferred”). The total number of designated shares of the Company’s Series B Convertible Preferred Stock is 0 and 10 million, as of September 30, 2022 and December 31, 2021. The total number of designated shares of the Company’s Series B1 Convertible Preferred Stock is 0 and 17,000,000 as of September 30, 2022 and December 31, 2021. The total number of designated shares of Series C Convertible Preferred Stock is 0 and 44,000 as of September 30, 2022 and December 31, 2021. As of September 30, 2022 and December 31, 2021, there were 0 and 385,601 shares, respectively, of Series A Preferred Stock issued and outstanding. As of September 30, 2022 and December 31, 2021, there were no shares of Series B, B1 and C Preferred Stock outstanding. On

August 31, 2022, the Company decided to withdraw and terminate the designations of the Series A, Series B, Series B1 and Series C preferred stock.

Certificates of Withdrawal of Previously Designated Preferred Stock. The Company filed Certificates of Withdrawal relating to each series of Preferred Stock previously designated with the Secretary of State of Nevada and terminated the designation of its Series A Preferred Stock (on August 24, 2022); Series B Preferred Stock (on August 24, 2022); Series B1 Preferred Stock (on August 23, 2022) and Series C Preferred Stock (on August 23, 2022). At the time of the filing of the Certificates of Withdrawal, no shares of any of the previously designated series of Preferred Stock were outstanding. The Certificates of Withdrawal were effective upon filing, and eliminated from our Articles of Incorporation all matters set forth in the previously-filed Certificates of Designation with respect to the previously designated series of Preferred Stock.

NOTE 18. EARNINGS PER SHARE

The following is a reconciliation of the numerator and denominator for basic and diluted income (loss) per share for the three months and nine months ended September 30, 2022 and 2021 (in thousands, except per share amounts):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Basic income (loss) per Share
Numerator:
Net income (loss) attributable to shareholders from continuing operations	$	17,259	$	6,364	$	(62,764)	$	(16,457)
Net income attributable to shareholders from discontinued operations, net of tax	4,975		1,581		13,053		4,732
Net income (loss) attributable to common shareholders	$	22,234	$	7,945	$	(49,711)	$	(11,725)
Denominator:
Weighted-average common shares outstanding	75,591		61,349		69,007		53,964
Basic income (loss) per common shares
Continuing operations	$	0.23	$	0.10	$	(0.91)	$	(0.31)
Discontinued operations, net of tax	0.07		0.03		0.19		0.09
Basic income (loss) per share	$	0.30	$	0.13	$	(0.72)	$	(0.22)

Diluted Income (Loss) per Share
Numerator:
Net income (loss) attributable to shareholders from continuing operations	$	17,259	$	6,364	$	(62,764)	$	(16,457)
Net income available to shareholders from discontinued operations, net of tax	4,975		1,581		13,053		4,732
Net income (loss) available to common shareholders	$	22,234	$	7,945	$	(49,711)	$	(11,725)
Denominator:
Weighted-average shares outstanding	75,591		61,349		69,007		53,964
Effect of dilutive securities
Stock options and warrants	4,047		2,871		—		—
Preferred stock	—		385		—		—
Diluted weighted-average shares outstanding	79,638		64,605		69,007		53,964
Diluted income (loss) per common shares
Continuing operations	$	0.22	$	0.10	$	(0.91)	$	(0.31)
Discontinued operations, net of tax	0.06		0.02		0.19		0.09
Diluted income (loss) per share	$	0.28	$	0.12	$	(0.72)	$	(0.22)

NOTE 19. FAIR VALUE MEASUREMENTS

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2022 and December 31, 2021 (in thousands):


	As of September 30, 2022
	Level 1		Level 2		Level 3		Total
Derivative instruments, assets
Commodity	$	1,219	$	—	$	—	$	1,219
Derivative instruments, assets	1,219		—		—		1,219
Derivative instruments, liabilities
Derivative warrants	—		—		14,303		14,303
Derivative warrants, liabilities	—		—		14,303		14,303
Total	$	1,219	$	—	$	(14,303)	$	(13,084)

	As of December 31, 2021
	Level 1		Level 2		Level 3		Total
Derivative instruments, assets
Commodity	$	96	$	—	$	—	$	96
Derivative instruments, assets	96		—		—		96
Derivative instruments, liabilities
Derivative warrants	—		—		75,211		75,211
Derivative warrants, liabilities	—		—		75,211		75,211
Total	$	96	$	—	$	(75,211)	$	(75,115)

Level 3 instruments include Initial Warrants and Additional Warrants granted in connection with the Loan and Security Agreement, see Note 15 "Long-Term Debt". We revalued the 2,835 thousand warrants granted and outstanding at September 30, 2022 using the Dynamic Black-Scholes model that computes the impact of a possible change in control transaction upon the exercise of the warrant shares. The Dynamic Black-Scholes Merton unobservable inputs used were as follows:


Dynamic Black-Scholes Merton Unobservable Inputs
	Initial Warrants		Additional Warrants
Expected dividend rate	—	%	—	%
Expected volatility	104.52	%	101	%
Risk free interest rate	4.06	%	4.06	%
Expected term	5		5.5

The following is an analysis of changes in the derivative liability classified as level 3 in the fair value hierarchy for the nine months ended September 30, 2022 (in thousands):


Level Three Roll-Forward
	2022
Balance at beginning of period	$	75,211
April 1 warrants granted	22,795
May 26 warrants granted	2,874
Equity component of the convertible senior not	(78,789)
Change in valuation of warrants included in net income	(7,788)
Balance at end of period	$	14,303

See Note 20 "Commodity Deri vative Instru ments ", below for information on the impact on results of operations of our commodity derivative instruments.

NOTE 20. COMMODITY DERIVATIVE INSTRUMENTS

The Company utilizes derivative instruments to manage its exposure to fluctuations in the underlying commodity prices of its inventory. The Company’s management sets and implements hedging policies, including volumes, types of instruments and counterparties, to support oil prices at targeted levels and manage its exposure to fluctuating prices.

The Company’s derivative instruments consist of option and futures arrangements for oil. For option and futures arrangements, the Company receives the difference positive or negative between an agreed-upon strike price and the market price.

The mark-to-market effects of these contracts as of September 30, 2022 and December 31, 2021, are summarized in the following table. The notional amount is equal to the total net volumetric derivative position during the period indicated. The fair value of the crude oil futures agreements is based on the difference between the strike price and the New York Mercantile Exchange and Brent Complex futures price for the applicable trading months.


As of September 30, 2022
Contract Type	Contract Period	Weighted Average Strike Price (Barrels)		Remaining Volume (Barrels)	Fair Value
				(in thousands)	(in thousands)
Swap	Sept. 2022 - Nov. 2022	$	4.51	12	$	54
Swap	Sept. 2022 - Nov. 2022	$	2.39	6	$	14
Option	Sept. 2022 - Nov. 2022	$	10.75	42	$	1,075
Swap	Sept. 2022 - Nov. 2022	$	1.52	50	$	76


As of December 31, 2021
Contract Type	Contract Period	Weighted Average Strike Price (Barrels)		Remaining Volume (Barrels)	Fair Value
				(in thousands)	(in thousands)
Options	Dec. 2021-Mar. 2022	$	3.18	18	$	136
Futures	Dec. 2021-Mar. 2022	$	31.59	20	$	71
Futures	Dec. 2021-Mar. 2022	$	32.48	50	$	(111)

The carrying values of the Company’s derivatives positions and their locations on the consolidated balance sheets as of September 30, 2022 and December 31, 2021 are presented in the table below.


Balance Sheet Classification	Contract Type	2022		2021

	Crude oil options	$	1,075	$	136
	Crude oil swaps	144		—
	Crude oil futures	—		(40)
Derivative commodity assets		$	1,219	$	96

For the three months ended September 30, 2022 and 2021, we recognized $11.0 million and $0.3 million of gain, respectively, on commodity derivative contracts on the consolidated statements of operations as part of our cost of revenues.

For the nine months ended September 30, 2022 and 2021, we recognized $87.2 million and $2.2 million of loss, respectively, on commodity derivative contracts on the consolidated statements of operations as part of our cost of revenues.

NOTE 21. INCOME TAXES

Our effective tax rate of 0% on pretax income differs from the U.S. federal income tax rate of 21% because of the change in our valuation allowance.

The year to date loss at September 30, 2022 puts the Company in an accumulated loss position for the cumulative 12 quarters then ended. For tax reporting purposes, we have net operating losses (“NOLs”) of approximately $106 million as of September 30, 2022 that are available to reduce future taxable income. In determining the carrying value of our net deferred tax asset, the Company considered all negative and positive evidence. The Company has generated pre-tax loss of approximately $29.1 million from January 1, 2022 through September 30, 2022.

The year to date loss at September 30, 2021 puts the Company in an accumulated loss position for the cumulative 12 quarters then ended. For tax reporting purposes, we have NOLs of approximately $38.9 million as of September 30, 2021 that are available to reduce future taxable income. In determining the carrying value of our net deferred tax asset, the Company considered all negative and positive evidence. The Company generated pre-tax loss of approximately $2.3 million from January 1, 2021 through September 30, 2021.

NOTE 22. NON-CONTROLLING INTERESTS

Myrtle Grove Facility

On April 1, 2022, the Company, through Vertex Splitter Corporation (“Vertex Splitter”), a wholly-owned subsidiary of the Company, acquired the 15% noncontrolling interest of Vertex Refining Myrtle Grove LLC (“MG SPV”) held by Tensile-Myrtle Grove Acquisition Corporation (“Tensile-MG”), an affiliate of Tensile Capital Partners Master Fund LP, an investment fund based in San Francisco, California (“Tensile”) from Tensile-Vertex for $7.2 million, which was based on the value of the Class B Unit preference of MG SPV held by Tensile-MG, plus capital invested by Tensile-MG in MG SPV (which had not been returned as of the date of payment), plus cash and cash equivalents held by Tensile-MG as of the closing date. As a result, the Company acquired 100% of MG SPV, which in turn owns the Company’s Belle Chasse, Louisiana, re-refining complex.

Myrtle Grove Redeemable Noncontrolling Interest. In accordance with ASC 480-10-S99-3A, the Company applied a two-step approach to measure noncontrolling interests associated with MG SPV at the balance sheet date. First, the Company applied the measurement guidance in ASC 810-10 by attributing a portion of the subsidiary’s net loss of $38 thousand to the noncontrolling interest. Second, the Company applied the subsequent measurement guidance in ASC 480-10-S99-3A, which indicates that the noncontrolling interest’s carrying amount is the higher of (1) the cumulative amount that would result from applying the measurement guidance in ASC 810-10 in the first step or (2) the redemption value. Pursuant to ASC 480-10-S99-3A, for a security that is probable of becoming redeemable in the future, the Company adjusted the carrying amount of the redeemable noncontrolling interests to what would be the redemption value assuming the security was redeemable at the balance sheet date. This accretion adjustment of $0.4 million increased the carrying amount of redeemable noncontrolling interests to the redemption value as of April 1, 2022 of $7.2 million. Adjustments to the carrying amount of redeemable noncontrolling interests to redemption value are reflected in retained earnings.

The table below presents the reconciliation of changes in redeemable noncontrolling interest relating to MG SPV as of September 30, 2022 and 2021 (in thousands):


	September 30, 2022		September 30, 2021
Beginning balance	$	6,812	$	5,473


Net loss attributable to redeemable non-controlling interest	(38)		(200)

Accretion of non-controlling interest to redemption value	428		1,176
Redemption of non-controlling interest	(7,202)		—
Ending balance	$	—	$	6,449

Heartland Re-refining Complex

On May 26, 2022, the Company, through Vertex Splitter acquired the 65% noncontrolling interest of Heartland SPV held by Tensile-Heartland from Tensile-Vertex Holdings LLC (“Tensile-Vertex”), an affiliate of Tensile for $43.5 million, which was based on the value of the Class B Unit preference of Heartland SPV held by Tensile-Heartland, plus capital invested by Tensile-Heartland in Heartland SPV (which had not been returned as of the date of payment), plus cash and cash equivalents held by

Tensile-Heartland as of the closing date. As a result, the Company acquired 100% of Heartland SPV, which in turn owns the Company’s Columbus, Ohio, re-refining complex.

Heartland Redeemable Noncontrolling Interest. In accordance with ASC 480-10-S99-3A, the Company applied a two-step approach to measure noncontrolling interests associated with Heartland SPV at the balance sheet date. First, the Company applied the measurement guidance in ASC 810-10 by attributing a portion of the subsidiary’s net income of $6.8 million to the noncontrolling interest. Second, the Company applied the subsequent measurement guidance in ASC 480-10-S99-3A, which indicates that the noncontrolling interest’s carrying amount is the higher of (1) the cumulative amount that would result from applying the measurement guidance in ASC 810-10 in the first step or (2) the redemption value. At May 26, 2022, the cumulative amount resulting from the application of the measurement guidance in ASC 810-10 was $43.5 million. On May 26, 2022, the Company acquired a 65% interest in Heartland SPV from Tensile for $43.5 million.

The table below presents the reconciliation of changes in redeemable noncontrolling interest relating to Heartland SPV as of September 30, 2022 and 2021 (in thousands):


	September 30, 2022		September 30, 2021
Beginning balance	$	36,635	$	26,139


Net income attributable to redeemable non-controlling interest	6,829		7,183
Redemption of non-controlling interest	(43,464)		—
Ending balance	$	—	$	33,322

The amount of accretion of redeemable noncontrolling interest to redemption value of $0.4 million and $1.1 million are presented as an adjustment to net income (loss) attributable to Vertex Energy, Inc., to arrive at net income (loss) attributable to common shareholders on the consolidated statements of operations which represent the MG SPV and Heartland SPV accretion of redeemable noncontrolling interest to redemption value combined for the nine months ended September 30, 2022 and 2021, respectively.

NOTE 23. DISCONTINUED OPERATIONS

During the third quarter of 2021, the Company initiated and began executing a strategic plan to sell its UMO Business. An investment banking advisory services firm was engaged and actively marketed this segment. On September 28, 2021, the shareholders approved the proposed sale of its portfolio of used motor oil collection and recycling assets to Safety-Kleen pursuant to the UMO Sale Agreement discussed below.

On January 25, 2022, the Company entered into a mutual agreement with Safety-Kleen to terminate the UMO Sale Agreement. In connection with the termination agreement, the Company paid Safety-Kleen a break-up fee of $3 million.

Vertex is continuing to explore opportunities for the sale of the UMO Business. Subsequent to the April 1, 2022 acquisition of the Mobile Refinery, our UMO Business operations no longer consist of ‘all or substantially all’ of our assets and as such, we have determined that the sale of such operations does not reach a level that would require shareholder approval if sold under Nevada law. As such, the requirement to obtain shareholder approval for any subsequent sale of the UMO Business is no longer necessary.

The Company is still exploring opportunities to sell the UMO Business and believes it will sell such assets within a year. As of the day of this filing, the Company is in ongoing discussions with a third party regarding a potential sale of the Heartland Business and has accordingly presented only this division as discontinued operations while reclassifying the other UMO Business operations out of assets held for sale, and all liabilities of the UMO Business out of liabilities held for sale, other than in connection with the Heartland Business. The following summarized financial information has been reclassified as continued operations for the six months ended June 30, 2022 and 2021 (in thousands):


	June 30, 2022		December 31, 2021
Assets held for sale to assets held and used	$	81,616	$	74,046
Liabilities held for sale to liabilities held and paid	$	(35,507)	$	(37,645)
	Six Months Ended June 30,
	2022		2021
Net income from discontinued operations to continued operation	$	16,736	$	1,284

The following summarized financial information has been segregated from continuing operations and reported as Discontinued Operations for the three months and nine months ended September 30, 2022, and 2021 (in thousands):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues	$	22,153	$	14,507	$	63,534	$	41,039
Cost of revenues (exclusive of depreciation shown separately below)	14,306		8,638		36,077		23,124
Depreciation and amortization attributable to costs of revenues	391		393		1,170		1,160
Gross profit	7,456		5,476		26,287		16,755
Operating expenses:
Selling, general and administrative expenses (exclusive of depreciation shown separately below)	2,418		1,418		6,213		4,606
Depreciation and amortization expense attributable to operating expenses	63		63		188		188
Total operating expenses	2,481		1,481		6,401		4,794
Income from operations	4,975		3,995		19,886		11,961
Other income (expense)


Interest expense	—		(14)		(4)		(46)
Total other expense	—		(14)		(4)		(46)
Income before income tax	4,975		3,981		19,882		11,915
Income tax benefit (expense)	—		—		—		—
Income from discontinued operations, net of tax	$	4,975	$	3,981	$	19,882	$	11,915

The assets and liabilities held for sale on the Consolidated Balance Sheets as of September 30, 2022 and December 31, 2021 are as follows (in thousands):


	September 30, 2022		December 31, 2021
ASSETS

Inventory	$	2,190	$	1,253
Prepaid expenses	317		163
Total current assets	2,507		1,416

Fixed assets, at cost	17,658		15,451
Less accumulated depreciation	(9,140)		(8,047)
Fixed assets, net	8,518		7,404
Finance lease right-of-use assets	—		436

Intangible assets, net	626		814

Assets held for sale	$	11,651	$	10,070

NOTE 24. RELATED PARTY TRANSACTIONS

Related Parties

From time to time, the Company consults Ruddy Gregory, PLLC., a related party law firm of which James Gregory, a member of the Board of Directors, serves as a partner. During the nine months ended September 30, 2022 and 2021, we paid $0.5 million and $0.6 million, respectively, to such law firm for services rendered, which services include the drafting and negotiation of, and due diligence associated with, the Sale Agreement and Refinery Purchase Agreement (defined and discussed above), and related transactions, including the Loan and Security Agreement and Supply and Offtake Agreement, discussed above.

NOTE 25. SUBSEQUENT EVENTS

On October 1, 2022, a total of $3 million of interest was paid on our outstanding Convertible Senior Notes.

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

Introduction

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) is provided in addition to the accompanying unaudited consolidated financial statements and notes thereto on the basis of management’s assessment to assist readers in understanding our results of operations, financial condition, and cash flows. As such, it should be read in conjunction with the interim unaudited financial statements and the notes thereto included in this Quarterly Report on Form 10-Q, and the audited financial statements and notes thereto and “Part II”, “Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in our Annual Report on Form 10-K for the year ended December 31, 2021, filed with the Securities and Exchange Commission on March 14, 2022 (the “Annual Report”). Unless the context requires otherwise, references to the “Company,” “we,” “us,” “our,” “Vertex”, “Vertex Energy” and “Vertex Energy, Inc.” refer specifically to Vertex Energy, Inc. and its consolidated subsidiaries.

Certain capitalized terms used below and otherwise defined below, have the meanings given to such terms in the footnotes to our unaudited consolidated financial statements included above under “Part I – Financial Information” – “Item 1. Financial Statements”.

Our logo and some of our trademarks and tradenames are used in this Report. This Report also includes trademarks, tradenames and service marks that are the property of others. Solely for convenience, trademarks, tradenames and service marks referred to in this Report may appear without the ®, ™ and SM symbols. References to our trademarks, tradenames and service marks are not intended to indicate in any way that we will not assert to the fullest extent under applicable law our rights or the rights of the applicable licensors if any, nor that respective owners to other intellectual property rights will not assert, to the fullest extent under applicable law, their rights thereto. We do not intend the use or display of other companies’ trademarks and trade names to imply a relationship with, or endorsement or sponsorship of us by, any other companies.

In this Quarterly Report on Form 10-Q, we may rely on and refer to information regarding the refining, re-refining, used oil and oil and gas industries in general from market research reports, analyst reports and other publicly available information. Although we believe that this information is reliable, we cannot guarantee the accuracy and completeness of this information, and we have not independently verified any of it.

We file annual, quarterly, and current reports, proxy statements and other information with the Securities and Exchange Commission (“SEC”). Our SEC filings (reports, proxy and information statements, and other information) are available to the public over the Internet at the SEC’s website at www.sec.gov and are available for download, free of charge, soon after such reports are filed with or furnished to the SEC, on the “Investor Relations,” “SEC Filings” page of our website at www.vertexenergy.com. Information on our website is not part of this Report, and we do not desire to incorporate by reference such information herein. Copies of documents filed by us with the SEC are also available from us without charge, upon oral or written request to our Secretary, who can be contacted at the address and telephone number set forth on the cover page of this Report.

The majority of the numbers presented below are rounded numbers and should be considered as approximate.

Unless the context otherwise requires and for the purposes of this report only:

● “Exchange Act” refers to the Securities Exchange Act of 1934, as amended;

● “SEC” or the “Commission” refers to the United States Securities and Exchange Commission; and

● “Securities Act” refers to the Securities Act of 1933, as amended.

Where You Can Find Other Information

written request to our Secretary, who can be contacted at the address and telephone number set forth on the cover page of this Report.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q (this “Report”) contains forward-looking statements within the meaning of the federal securities laws, including the Private Securities Litigation Reform Act of 1995, regarding future events and the future results of the Company that are based on current expectations, estimates, forecasts, and projections about the industry in which the Company operates and the beliefs and assumptions of the management of the Company. In some cases, you can identify forward-looking statements by the following words: “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “ongoing,” “plan,” “potential,” “predict,” “project,” “should,” or the negative of these terms or other comparable terminology, although not all forward-looking statements contain these words. Forward-looking statements are not a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking statements are based on information available at the time the statements are made and involve known and unknown risks, uncertainties and other factors that may cause our results, levels of activity, performance or achievements to be materially different from the information expressed or implied by the forward-looking statements in this Report. Factors that might cause or contribute to such differences include, but are not limited to, those discussed elsewhere in this Report, including under "Risk Factors", and in other reports the Company files with the Securities and Exchange Commission (“SEC” or the “Commission”), including the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, as filed with the SEC on March 14, 2022 (under the heading "Risk Factors" and in other parts of that report), which factors include:

•our need for additional funding and the availability of and terms of such funding;

•risks associated with our outstanding indebtedness, including our outstanding Convertible Senior Notes, including amounts owed, restrictive covenants and security interests in connection therewith, and our ability to repay such debts and amounts due thereon (including interest) when due, and mandatory and special redemption provisions thereof, and conversion rights associated therewith, including dilution caused thereby (in connection with the Convertible Senior Notes);

•security interests, guarantees and pledges associated with our outstanding Loan and Security Agreement and Supply and Offtake Agreement, and risks associated with such agreements in general;

•risks associated with the capital project currently in process at our recently acquired Mobile, Alabama refinery, including costs, timing, delays and unanticipated problems associated therewith;

•health, safety, security and environment risks;

•risks associated with an offtake agreement which will only become effective upon the occurrence of certain events, including the completion of the capital project at the Mobile, Alabama refinery, which may not be completed timely;

•the level of competition in our industry and our ability to compete;

•our ability to respond to changes in our industry;

•the loss of key personnel or failure to attract, integrate and retain additional personnel;

•our ability to protect our intellectual property and not infringe on others’ intellectual property;

•our ability to scale our business;

•our ability to maintain supplier relationships and obtain adequate supplies of feedstocks;

•our ability to obtain and retain customers;

•our ability to produce our products at competitive rates;

•our ability to execute our business strategy in a very competitive environment;

•trends in, and the market for, the price of oil and gas and alternative energy sources;

•our ability to maintain our relationships with Bunker One (USA) Inc, Macquarie Energy North America Trading Inc., and Shell;

•the impact of competitive services and products;

•our ability to complete and integrate future acquisitions;

•our ability to maintain insurance;

•potential future litigation, judgments and settlements;

•rules and regulations making our operations more costly or restrictive;

•changes in environmental and other laws and regulations and risks associated with such laws and regulations;

•economic downturns both in the United States and globally;

•risk of increased regulation of our operations and products;

•negative publicity and public opposition to our operations;

•disruptions in the infrastructure that we and our partners rely on;

•an inability to identify attractive acquisition opportunities and successfully negotiate acquisition terms;

•liabilities associated with acquired companies, assets or businesses;

•interruptions at our facilities;

•losses under derivative and hedging contracts;

•unexpected changes in our anticipated capital expenditures resulting from unforeseen required maintenance, repairs, or upgrades;

•our ability to acquire and construct new facilities;

•prohibitions on borrowing and other covenants of our debt facilities;

•our ability to effectively manage our growth;

•decreases and/or volatility in global demand for, and the price of, oil;

•our ability to acquire sufficient amounts of used oil feedstock through our collection routes, to produce finished products, and in the absence of such internally collected feedstocks, our ability to acquire third-party feedstocks on commercially reasonable terms;

•repayment of and covenants in our current and future debt facilities;

•rising inflation, rising interest rates, governmental responses thereto and possible recessions caused thereby;

•the lack of capital available on acceptable terms to finance our continued growth; and

•other risk factors included under “Risk Factors“ in our latest Annual Report on Form 10-K and set forth below under “Risk Factors“.

In addition, any statements that refer to projections of our future financial performance, our anticipated growth and trends in our businesses, and other characterizations of future events or circumstances are forward-looking statements.

You should read the matters described in, and incorporated by reference in, "Risk Factors" and the other cautionary statements made in this Report, and incorporated by reference herein, as being applicable to all related forward-looking statements wherever they appear in this Report. We cannot assure you that the forward-looking statements in this Report will prove to be accurate and therefore prospective investors are encouraged not to place undue reliance on forward-looking statements. All forward-looking statements included herein speak only as of the date of the filing of this Report. All subsequent written and oral forward-looking statements attributable to the Company, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements above. Other than as required by law, we undertake no obligation to update or revise these forward-looking statements, even though our situation may change in the future.

Overview and Business Activities

Vertex is an energy transition company specializing in refining and marketing high-value conventional and lower-carbon alternative transportation fuels. We are engaged in operations across the petroleum value chain, including refining, collection, aggregation, transportation, storage and sales of aggregated feedstock and refined products to end-users. All of these products are commodities that are subject to various degrees of product quality and performance specifications.

We currently provide our services in 15 states, primarily in the Gulf Coast, Midwest, and Mid-Atlantic regions of the United States. For the rolling twelve-month period ending September 30, 2022, we aggregated approximately 86.5 million gallons of used motor oil and other petroleum by-product feedstocks and managed the re-refining of approximately 80.1 million gallons of used motor oil with our proprietary vacuum gas oil (“VGO”) and Base Oil processes.

Mobile Refinery acquisition. Effective April 1, 2022, we completed the acquisition of a 75,000 bpd crude oil refinery ten miles north of Mobile, in Saraland, Alabama (the “Mobile Refinery”) and related logistics assets, which include a deep-water draft, bulk loading terminal facility with 600,000 Bbls of storage capacity for crude oil and associated refined petroleum products located in Mobile, Alabama (the “Blakeley Island Terminal”). The terminal includes a dock for loading and unloading vessels with a pipeline tie-in, as well as the related logistics infrastructure of a high-capacity truck rack with 3-4 loading heads per truck, each rated at 600 gallons per minute (the “Mobile Truck Rack”). The Mobile Refinery currently processes heavy and sour crude to produce heavy olefin feed, regular gasoline, premium gasoline, jet fuel, and diesel fuel.

The Company paid a total of $75.0 million (less $10 million previously paid) in consideration for the acquisition of the Mobile Refinery. In addition, we paid $16.4 million for previously agreed upon capital expenditures, miscellaneous prepaids and reimbursable items and an $8.7 million technology solution comprising the ecosystem required for the Company to run the Mobile Refinery after the acquisition. The Company also purchased certain crude oil and finished products inventories for $130.2 million owned by Shell at the Mobile Refinery.

As a result of the Mobile Refinery purchase, Vertex Refining and Shell Trading (US) Company (“STUSCO”) entered into a Crude Oil & Hydrocarbon Feedstock Supply Agreement (the “Crude Supply Agreement”) pursuant to which STUSCO agreed to sell to Vertex Refining, and Vertex Refining agreed to buy from STUSCO, all of the crude oil and hydrocarbon feedstock requirements of the Mobile Refinery, subject to certain exceptions set forth therein. The agreement provides that STUSCO is the exclusive supplier for the Mobile Refinery’s requirement for crude oil and hydrocarbon feedstock.

Additionally, as a result of the Mobile Refinery purchase, we entered into several agreements with Macquarie Energy North America Trading Inc (“Macquarie”). Under these agreements (together, the “Inventory Financing Agreement”), Macquarie agrees to finance the Mobile Refinery’s crude supply and inventories, and Vertex agrees to provide storage and terminalling services to Macquarie. At the time of the acquisition, Macquarie agreed to finance $124.3 million of the $130.2 million of opening inventories. See Note 3 “Mobile Refinery Acquisition” of our Condensed Notes to Consolidated Financial Statements.

Myrtle Grove Facility Purchase. On April 1, 2022, the Company, through Vertex Splitter Corporation (“Vertex Splitter”), a wholly-owned subsidiary of the Company acquired the 15% noncontrolling interest of Vertex Refining Myrtle Grove LLC (“MG SPV”) held by Tensile-Myrtle Grove Acquisition Corporation (“Tensile-MG”), an affiliate of Tensile Capital Partners Master Fund LP, an investment fund based in San Francisco, California (“Tensile”) from Tensile-Vertex for $7.2 million, which was based on the value of the Class B Unit preference of MG SPV held by Tensile-MG, plus capital invested by Tensile-MG in MG SPV (which had not been returned as of the date of payment), plus cash and cash equivalents held by Tensile-MG as of the closing date. As a result, the Company acquired 100% of MG SPV, which in turn owns the Company’s Belle Chasse, Louisiana, re-refining complex. See Note 22 “Non-Controlling Interests” of our Condensed Notes to Consolidated Financial Statements.

Heartland Re-refining Complex. On May 26, 2022, the Company, through Vertex Splitter acquired the 65% noncontrolling interest of HPRM LLC, a Delaware limited liability company (“Heartland SPV”) held by Tensile-Heartland Acquisition Corporation, a Delaware corporation (“Tensile-Heartland”) from Tensile-Vertex Holdings LLC (“Tensile-Vertex”), an affiliate of Tensile for $43.5 million, which was based on the value of the Class B Unit preference of Heartland SPV held by Tensile-Heartland, plus capital invested by Tensile-Heartland in Heartland SPV (which had not been returned as of the date of payment), plus cash and cash equivalents held by Tensile-Heartland as of the closing date. As a result, the Company acquired 100% of Heartland SPV, which in turn owns the Company’s Columbus, Ohio, re-refining complex. See Note 22 “Non-Controlling Interests” of our Condensed Notes to Consolidated Financial Statements.

We operate two business segments: the Refining and Marketing segment and the Black Oil and Recovery segment. For further description of the business and products of our segments, see “Results of Operations”, below.

Strategy and Plan of Operations

The principal elements of our strategy include:

Completion of Renewable Diesel Conversion Project. The renewable diesel conversion project is designed to modify the Mobile Refinery's hydrocracking unit to produce renewable diesel fuel on a standalone basis. To date, we have technology, engineering and construction partners and construction of foundations and fabrication of piping has commenced. Initial renewable production volumes are expected to come on-stream in the second quarter of 2023. The Company expects the total project cost to be in the range of $90 to $100 million, funded entirely through existing cash on-hand and cash flow from operations. As of September 30, 2022, the Company had incurred $38.8 million in capital expenditures for this project.

Expand Feedstock Supply Volume. We intend to expand our feedstock supply volume by growing our collection and aggregation operations. We plan to increase the volume of feedstock we collect directly by developing new relationships with generators and working to displace incumbent collectors; increasing the number of collection personnel, vehicles, equipment, and geographical areas we serve; and acquiring collectors in new or existing territories. We intend to increase the volume of feedstock we aggregate from third-party collectors by expanding our existing relationships and developing new vendor relationships. We believe that our ability to acquire large feedstock volumes will help to cultivate new vendor relationships because collectors often prefer to work with a single, reliable customer rather than manage multiple relationships and the uncertainty of excess inventory.

Broaden Existing Customer Relationships and Secure New Large Accounts. We intend to broaden our existing customer relationships by increasing sales of used motor oil and re-refined products to these accounts. In some cases, we may also seek to serve as our customers’ primary or exclusive supplier. We also believe that as we increase our supply of feedstock and re-refined products that we will secure larger customer accounts that require a partner who can consistently deliver high volumes.

Re-Refine Higher Value End Products. We intend to develop, lease, or acquire technologies to re-refine our feedstock supply into higher-value end products. We believe that the expansion of our facilities and our technology, and investments in additional technologies, will enable us to upgrade feedstock into end products, such as lubricating base oil, that command higher market prices than the current re-refined products we produce.

Pursue Selective Strategic Relationships or Acquisitions. We plan to grow market share by consolidating feedstock supply through partnering with or acquiring collection and aggregation assets. Such acquisitions and/or partnerships could increase our revenue and provide better control over the quality and quantity of feedstock available for resale and/or upgrading as well as providing additional locations. In addition, we intend to pursue further vertical integration opportunities by acquiring complementary processing technologies where we can realize synergies by leveraging our customer and vendor relationships, infrastructure, and personnel, and by eliminating duplicative overhead costs.

Results of Operations

We are engaged in operations across the petroleum value chain, including crude oil refining, collection, aggregation, transportation, storage, and sales of refined and re-refined products and aggregated feedstock. Our margins are a function of the difference between what we are able to pay for raw materials and the market prices for the range of products produced. The various petroleum products produced are typically a function of crude oil indices and are quoted on multiple exchanges such as the New York Mercantile Exchange (“NYMEX”). These prices are determined by a global market and can be influenced by many factors, including but not limited to supply/demand, weather, politics, and global/regional inventory levels. As such, we cannot provide any assurances regarding results of operations for any future periods, as numerous factors outside of our control affect the prices paid for raw materials and the prices (for the most part keyed to the NYMEX) that can be charged for such products. These factors include the supply of, and demand for, crude oil, and refined products, which in turn depend on changes in domestic and foreign economies; weather conditions; domestic and foreign political affairs; production levels; the marketing of competitive fuels; and government regulation. Additionally, for the near term, results of operations will be subject to further uncertainty, as the global markets and exchanges, including the NYMEX, continue to experience volatility.

Refining margins have experienced significant increases during the first nine months of 2022 in each of the benchmark commodities we track compared to the same period in 2021. The ongoing conflict between Russia and Ukraine, which began in the first quarter of 2022, and the economic sanctions imposed on Russia have decreased the global supply of crude oil affecting global prices. This conflict coupled with disruptions in supply chain that began with the COVID-19 pandemic in 2020, have resulted in increased inflation and higher market prices in crude oil and refined products. During the twelve months ended September 30, 2022, the Consumer Price Energy Index in the United States increased 19.7% impacting our gross margins. The Consumer Price All Items Index increased 8.2% for the same period impacting our operating expenses and slowing economic growth.

The following table sets forth the high and low spot prices during the nine months ended September 30, 2022, for our key benchmarks.


2022
Benchmark	High		Date	Low		Date
Crackspread 2-1-1 (dollars per barrel) (1)	$	56.47	June 22	$	25.50	August 8
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon)	$	4.36	March 8	$	2.15	January 3
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon)	$	4.35	June 3	$	2.26	January 3
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel)	$	112.93	March 8	$	54.30	September 30
NYMEX Crude oil (dollars per barrel)	$	123.70	March 8	$	76.08	January 3
Reported in Platt’s US Marketscan (Gulf Coast)
(1) Period reported from April 1 through September 30. The Gulf Coast 2-1-1 crack spread is calculated using two barrels of LLS (Louisiana Light Sweet crude oil) producing one barrel of USGC CBOB gasoline and one barrel of USGC ultra-low sulfur diesel.

The following table sets forth the high and low spot prices during the nine months ended September 30, 2021, for our key benchmarks.


2021
Benchmark	High		Date	Low		Date
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon)	$	2.15	September 30	$	1.32	January 4
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon)	$	2.30	July 30	$	1.36	January 4
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel)	$	69.64	September 30	$	45.08	January 4
NYMEX Crude oil (dollars per barrel)	$	75.29	September 28	$	47.62	January 4
Reported in Platt’s US Marketscan (Gulf Coast)

Our production and sales of lower value products such as LPGs, VGO and sulfur also impact our results of operations, especially when crude prices are high. Our results of operations are also significantly affected by our direct operating expenses, especially our labor costs. Safety, reliability and the environmental performance of our refineries’ operations are critical to our financial performance.

As our competitors bring new technologies to the marketplace, which will likely enable them to obtain higher values for the finished products created through their technologies from purchased black oil feedstock, we anticipate that they will be willing to pay more for feedstock due to the additional value received from their finished product (i.e., as their margins increase, they are able to increase the prices they are willing to pay for feedstock). If we are not able to continue to refine and improve our technologies and gain efficiencies in our technologies, we could be negatively impacted by the ability of our competitors to bring new processes to market which compete with our processes, as well as their ability to outbid us for feedstock supplies. Additionally, if we are forced to pay more for feedstock, our cash flows will be negatively impacted and our margins will decrease.

Our results of operations for the three and nine months ended September 30, 2022, were significantly impacted by the acquisition of the Mobile Refinery on April 1, 2022. There are no comparable amounts presented for the same periods in 2021. See the summary of the Mobile Refinery operating results under Results of Operations – Refining and Marketing, below.

We operate two business segments: the Refining and Marketing segment and the Black Oil and Recovery segment. The table below shows our product categories by segment. For further description of individual products, please refer to the Glossary of terms at the beginning of this document.


	Black Oil(1) and Recovery (2)	Refining and Marketing(3)
Gasolines		X
Jet Fuels		X
Diesel		X
Base oil	X
VGO/Marine fuel sales	X	X
Other refinery products (4)	X	X
Pygas		X
Metals (5)	X
Other re-refined products (6)	X	X
Terminalling		X
Oil collection services	X

(1) The Black Oil segment continued operations consist primary of the sale of (a) other re-refinery products, recovered products, and used motor oil; (b) specialty blending and packaging of lubricants, (c) transportation revenues; and (d) the sale of VGO (vacuum gas oil)/marine fuel; (e) petroleum products which include base oil and industrial fuels—which consist of used motor oils, cutterstock and fuel oil generated by our facilities; (f) oil collection services—which consist of used oil sales, burner fuel sales, antifreeze sales and service charges; (g) the sale of other re-refinery products including asphalt, condensate, recovered products, and used motor oil. As of the date of this filing, the Company is in ongoing discussions with a third party regarding a potential sale of the Company’s Heartland refinery in Ohio (which forms a part of the Black Oil segment), and as such, has determined to present only the Company’s Heartland refinery options as discontinued operations (“Heartland Business”).

(2) As discussed in greater detail below under “Black Oil and Recovery Segment”, the Recovery segment consists primarily of revenues generated from the sale of ferrous and non-ferrous recyclable Metal(s) products that are recovered from manufacturing and consumption. It also includes revenues generated from trading/marketing of Group III Base Oils.

(3) As discussed in greater detail below under “Refining and Marketing Segment”, the Refining and Marketing segment consists primarily of the sale of pygas; industrial fuels, which are produced at a third-party facility (Monument Chemical); and distillates.

(4) Other refinery products include the sales of base oil, cutterstock and hydrotreated VGO, LPGs, sulfur and vacuum tower bottoms (VTB).

(5) Metals consist of recoverable ferrous and non-ferrous recyclable metals from manufacturing and consumption. Scrap metal can be recovered from pipes, barges, boats, building supplies, surplus equipment, tanks, and other items consisting of metal composition. These materials are segregated, processed, cut-up and sent back to a steel mill for re-purposing.

(6) Other re-refinery products include the sales of asphalt, condensate, recovered products, and other petroleum products.

Results of Operations

The following discussion includes comments and analysis relating to our results of operations. This discussion should be read in conjunction with Item 1. Financial Statements and is intended to provide investors with a reasonable basis for assessing our historical operations, however, it should not serve as the only criteria for predicting our future performance.

Consolidated Results of Operations

Set forth below are our results of operations for the three and nine months ended September 30, 2022 as compared to the same periods in 2021 (in thousands):


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022		2021		Variance*		2022		2021		Variance*
Revenues	$	810,208	$	50,982	$	759,226	$	1,915,423	$	147,807	$	1,767,616
Cost of revenues (exclusive of depreciation and amortization shown separately below)	750,463		46,142		(704,321)		1,819,757		127,986		(1,691,771)
Depreciation and amortization attributable to costs of revenues	4,050		1,028		(3,022)		9,144		3,002		(6,142)
Gross profit	55,695		3,812		51,883		86,522		16,819		69,703



Operating expenses:
Selling, general and administrative expenses	36,978		8,177		(28,801)		89,934		21,742		(68,192)
Depreciation and amortization attributable to operating expenses	1,120		420		(700)		2,656		1,260		(1,396)

Total operating expenses	38,098		8,597		(29,501)		92,590		23,002		(69,588)


Income (loss) from operations	17,597		(4,785)		22,382		(6,068)		(6,183)		115

Other income (expense):



Other income	417		(3)		420		1,060		4,220		(3,160)

Income (loss) on change in value of derivative warrant liability	12,312		11,907		405		7,788		(11,380)		19,168

Interest expense	(13,131)		(455)		(12,676)		(65,083)		(919)		(64,164)
Total other income (expense)	(402)		11,449		(11,851)		(56,235)		(8,079)		(48,156)

Income (loss) from continuing operation before income tax	17,195		6,664		10,531		(62,303)		(14,262)		(48,041)

Income tax benefit (expense)	—		—		—		—		—		—

Income (loss) from continuing operations	17,195		6,664		10,531		(62,303)		(14,262)		(48,041)
Income from discontinued operations, net of tax	4,975		3,981		994		19,882		11,915		7,967
Net income (loss)	22,170		10,645		11,525		(42,421)		(2,347)		(40,074)
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest from continuing operations	(64)		(115)		51		33		511		(478)
Net income attributable to non-controlling interest and redeemable non-controlling from discontinued operations	—		2,400		(2,400)		6,829		7,183		(354)
Net income (loss) attributable to Vertex Energy, Inc.	$	22,234	$	8,360	$	13,874	$	(49,283)	$	(10,041)	$	(39,242)

* Favorable variances are represented by positive numbers and unfavorable variances are represented by negative numbers.

Our revenues and cost of revenues are significantly impacted by the recently acquired Mobile Refinery on April 1, 2022, and fluctuations in commodity prices. Increases in commodity prices typically result in increases in revenue and cost of revenues (i.e., feedstock costs). Additionally, we have used hedging instruments to manage our exposure to underlying commodity prices.

Third Quarter 2022 Compared to Third Quarter 2021 Discussion

During the three months ended September 30, 2022, compared to the same period in 2021, we saw a 204% increase in the volume of products we manage through our facilities (mainly as a result of the Mobile Refinery acquisition and increased volumes processed through such facility). In addition, we saw an increase in operating costs (inclusive of depreciation and amortization) on a per barrel basis for the third quarter of 2022 as compared to the same period in 2021 due to the increased price of direct material and indirect costs. Management of operating costs is critical to our ability to remain competitive in the marketplace, we continue to experience inflationary pressures across numerous cost categories. The key areas of impact are around transportation, labor, as well as fuel and energy related expenses.

During the three months ended September 30, 2022, total revenues increased approximately $759.2 million compared to the same period in 2021, of which $733.5 million was from the Mobile Refinery. The remaining variance of $25.7 million was from our legacy business. This increase from our legacy business was due primarily to higher commodity prices and increased volumes at our facilities. Volumes improved as a result of additional feedstock availability in the overall marketplace.

During the three months ended September 30, 2022, total cost of revenues (exclusive of depreciation and amortization) increased approximately $704.3 million, of which $681.7 million was from the Mobile Refinery and $22.7 million was from other business compared to same period ended September 30, 2021. The main reason for the $22.7 million increase from other business was the result of the increase in commodity prices during 2022 compared to 2021, which impacted our feedstock pricing and certain operational expenses. Our cost of revenues is a function of the ultimate price we are required to pay to acquire feedstocks, principally crude oil, inventory financing costs, and other maintenance costs at our facilities.

The total operating expenses (excluding depreciation and amortization) increased approximately $28.8 million for the three months ended September 30, 2022, compared to the same prior year’s period, of which $26.2 million was associated with the Mobile Refinery.

For the three months ended September 30, 2022, total depreciation and amortization expense attributable to cost of revenues was $4.1 million, compared to $1.0 million for the three months ended September 30, 2021, an increase of $3.0 million, mainly due to Mobile Refinery assets acquired and additional investments in rolling stock and facility assets during the fourth quarter of 2021, which increased depreciation and amortization in 2022.

Additionally, our per barrel margin increased 496% for the three months ended September 30, 2022, relative to the three months ended September 30, 2021. Our per barrel margin is calculated by dividing the total volume of product sold (in bbls) by total gross profit for the applicable period ($55.7 million for the 2022 period versus $3.8 million for the 2021 period). This increase was a result of the increase in our product spreads related to increases in feedstock prices and increases in operating maintenance costs at our facilities, during the three months ended September 30, 2022, compared to the same period during 2021.

The Gulf Coast 2-1-1 crack spreads increased during the three months ended September 30, 2022 compared to the three months ended June 30, 2022. The crack spread averaged $34.82 per barrel during the three months ended September 30, 2022 compared to $45.06 during the three months ended June 30, 2022. We use crack spreads as a performance benchmark for our Mobile refining gross margin and as a comparison with other industry participants. The Gulf Coast 2-1-1 crack spread is calculated using two barrels of LLS (Louisiana Light Sweet crude oil) producing one barrel of USGC CBOB gasoline and one barrel of USGC ultra-low sulfur diesel.

Overall, commodity prices were up for the three months ended September 30, 2022, compared to the same period in 2021. For example, the average posting (U.S. Gulfcoast Residual Fuel No. 6 3%) for the three months ended September 30, 2022, increased 22% per barrel from a three-month average of $62.46 for the three months ended September 30, 2021 to $76.25 per barrel for the three months ended September 30, 2022. The average posting (U.S. Gulfcoast Unleaded 87 Waterborne) for the three months ended September 30, 2022 increased $20.05 per barrel from a three-month average of $92.69 for the three months ended September 30, 2021 to $120.74 per barrel for the three months ended September 30, 2022.

We had interest expense of $13.1 million for the three months ended September 30, 2022, compared to interest expense of $0.5 million for the three months ended September 30, 2021, an increase of $12.6 million. This increase was due to the accretion of deferred loan costs and interest expenses associated with the issuance of $155 million in Convertible Senior Notes on November 1, 2021, and draws under our Term Loan of $125 million on April 1, 2022 and $40 million on May 26, 2022.

We had an approximately $12.3 million gain on change in value of derivative liability for the three months ended September 30, 2022, in connection with the warrants granted in connection with the Term Loan issued on April 1, 2022 (warrants to purchase 2.75 million shares) and May 26, 2022 (warrants to purchase 0.25 million shares), compared to a gain on change in the value of our derivative liability of $11.9 million in the prior year’s period, which was in connection with certain warrants granted in May 2016, which have either been exercised or expired to date. This change was mainly due to the fluctuation in the market price of our common stock (and more specifically the decrease in the market price of our common stock during the current period, compared to the prior period), warrant exercises, and non-cash accounting adjustments in connection therewith.

We had net income from continuing operations of approximately $17.2 million for the three months ended September 30, 2022, compared to net income from continuing operations of $6.7 million for the three months ended September 30, 2021, an increase in net income from continuing operations of $10.5 million. The main reason for the increase in net income from continuing operations for the three months ended September 30, 2022, compared to the three months ended September 30, 2021, was attributable to the profit on inventory hedging activities, and increased commodity prices which helped improve margins for the three months ended September 30, 2022, each as described in greater detail above.

Year to Date 2022 Compared to Year to Date 2021 Discussion

Total revenues increased $1,767.6 million for the nine months ended September 30, 2022 compared to the same period in 2021, due primarily to the Mobile Refinery acquisition, which Mobile Refinery generated $1,655.7 million in revenue and higher commodity prices and increased volumes across our facilities, during the nine months ended September 30, 2022, compared to the prior year’s period.

For the nine months ended September 30, 2022, total cost of revenues (exclusive of depreciation and amortization) was $1.8 billion, compared to $128.0 million for the nine months ended September 30, 2021, an increase of $1.7 billion from the prior period. The main reason for the increase was the addition of the Mobile Refinery business which was acquired on April 1, 2022, in addition to higher commodity prices, which impacted our feedstock pricing, and increases in volumes throughout the business.

For the nine months ended September 30, 2022, total depreciation and amortization expense attributable to cost of revenues was approximately $9.1 million, compared to $3.0 million for the nine months ended September 30, 2021, an increase of $6.1 million, mainly due to assets acquired with the Mobile Refinery purchase.

We had gross profit as a percentage of revenue of 4.5% for the nine months ended September 30, 2022, compared to gross profit as a percentage of revenues of 11.4% for the nine months ended September 30, 2021. The decrease was mainly due to our change in business strategy after we acquired the Mobile Refinery on April 1, 2022.

We had operating expenses (excluding depreciation and amortization) of approximately $89.9 million for the nine months ended September 30, 2022, compared to $21.7 million for the prior year’s period, an increase of $68.2 million. This increase is primarily due to $48.2 million of operating expenses relating to the Mobile Refinery and $13.6 million of Mobile Refinery acquisition costs and business development expenses related to the transactions contemplated by the UMO Sale Agreement (which was terminated as of January 25, 2022) and the Refinery Purchase Agreement and related transactions.

We had gross loss from operations of approximately $6.1 million for the nine months ended September 30, 2022, compared to a loss from operations of $6.2 million for the nine months ended September 30, 2021, an increase of $0.1 million in gross loss from operations from the prior year’s nine-month period. The increase in gross loss from operations was mostly due to the loss from commodity derivatives and the cost of the Mobile Refinery acquisition.

We had interest expense of approximately $65.1 million for the nine months ended September 30, 2022, compared to interest expense of $0.9 million for the same period in 2021, an increase in interest expense of $64.2 million due to a higher amount of term debt outstanding during the nine months ended September 30, 2022, compared to the prior period, the unamortized deferred loan costs related to the conversion of Convertible Senior Notes to common stock during the period and the interest associated with the Convertible Senior Notes, which were issued on November 1, 2021, and the Term Loan, which was issued on April 1, 2022 ($125 million) and May 26, 2022 ($40 million).

We had an approximately $7.8 million gain on change in value of derivative liability for the nine months ended September 30, 2022 in connection with certain warrants granted in April and May 2022, compared to a loss on change in the value of our derivative liability of $11.4 million in the prior year’s period, which related to warrants granted in June 2015 and May 2016 which expired during 2021. This change was mainly due to the fluctuation in the market price of our common stock (and more specifically the significant decrease in the market price of our common stock during the current period), warrant exercises, and non-cash

accounting adjustments in connection therewith. This resulted in a significant change in non-cash expense for the period, compared to the prior year’s period.

We had a net loss from continuing operations of approximately $62.3 million for the nine months ended September 30, 2022, compared to a net loss from continuing operations of $14.3 million for the nine months ended September 30, 2021, an increase in net loss from continuing operations of $48.0 million from the prior period due to the reasons described above. The majority of our net loss for the nine months ended September 30, 2022, was attributable to the loss on inventory hedging activities created by market conditions, and amortized deferred loan cost and discount, which was reported as interest expenses, related to the conversion of Convertible Senior Notes, which is a non-cash expense.

Refining and Marketing Segment

Effective on April 1, 2022, the Refining and Marketing segment generates most of its revenues from the sales of petroleum refined products processed at the Mobile Refinery. The Mobile Refinery processes crude oils into refined finished products which include gasolines, distillates including jet fuel, LPGs, and other residual fuels such as VTBs, VGO, olefins, reformate and sulfur. We market these finished products across the southeastern United States through a high-capacity truck rack, together with deep and shallow water distribution points capable of supplying waterborne vessels. Most of the Mobile Refinery production is sold to Macquarie under the Inventory Financing Agreement. The Refining and Marketing segment also includes revenues from gathering hydrocarbon streams in the form of petroleum distillates, transmix and other chemical products that have become off-specification during the transportation or refining process. These feedstock streams are purchased from pipeline operators, refineries, chemical processing facilities and third-party providers, and then processed at a third-party facility under our direction. The end products are typically three distillate petroleum streams (gasoline blendstock, pygas and fuel oil cutterstock), which are sold to major oil companies or to large petroleum trading and blending companies. The end products are delivered by barge and truck to customers. Additionally, this segment includes the wholesale distribution of gasoline, blended gasoline, and diesel for use as engine fuel to operate automobiles, trucks, locomotives, and construction equipment.

Results from operations from the Mobile Refinery have substantially changed our overall revenue, cost of revenue, net income, and earnings before interest, taxes, depreciation, and amortization. During the three and nine months ended September 30, 2022, the Mobile Refinery generated 91% and 86%, respectively, of our total consolidated revenue. Set forth below are our results of operations and certain key performance indicators disaggregated to show the Mobile Refinery on a stand-alone basis to facilitate comparability between periods (in thousands, except key performance indicators):


	Three Months Ended September 30,
	2022						2021
Refining and Marketing Segment (in thousands)	Mobile Refinery		Legacy Refining and Marketing		Total Refining and Marketing		Legacy Refining and Marketing
Revenues	$	733,521	$	33,248	$	766,769	$	24,572
Cost of revenues (exclusive of depreciation and amortization shown separately below)	681,682		33,482		715,164		23,937
Depreciation and amortization attributable to costs of revenues	2,957		154		3,111		127
Gross profit (loss)	48,882		(388)		48,494		508
Operating expenses
Selling general and administrative expense	26,240		1,748		27,988		1,034
Depreciation and amortization attributable to operating expenses	736		114		850		108
Total operating expenses	26,976		1,862		28,838		1,142
Income (loss) from operations	21,906		(2,250)		19,656		(634)
Other income (expenses)					—		—


Interest expense	(3,536)		—		(3,536)		—
Net income (loss)	$	18,370	$	(2,250)	$	16,120	$	(634)
Refining adjusted EBITDA *	(517)		(2,757)		(3,274)		(399)
Key performance indicators:
Refining gross margin	$	48,343	n/a		n/a		n/a
Refining gross margin per bbl of throughput (1)*	7.73		n/a		n/a		n/a
USGC 2-1-1 Crack Spread Per Barrel (2)	34.82		n/a		n/a		n/a
Operating expenses per bbl of throughput (3)	$	4.20	n/a		n/a		n/a


	Nine Months Ended September 30,
	2022						2021
Refining and Marketing Segment (in thousands)	Mobile Refinery		Legacy Refining and Marketing		Total Refining and Marketing		Legacy Refining and Marketing
Revenues	$	1,655,717	$	112,161	$	1,767,878	$	67,683
Cost of revenues (exclusive of depreciation and amortization shown separately below)	1,598,924		109,093		1,708,017		64,555
Depreciation and amortization attributable to costs of revenues	5,944		395		6,339		379
Gross profit	50,849		2,673		53,522		2,749
Operating expenses
Selling general and administrative expense	48,201		4,508		52,709		2,482
Depreciation and amortization attributable to operating expenses	1,472		313		1,785		325
Total operating expenses	49,673		4,821		54,494		2,807
Income (loss) from operations	1,176		(2,148)		(972)		(58)
Other income (expenses)					—		—

Interest expense	(6,786)		—		(6,786)		—
Interest income	18		—		18		—
Net income (loss)	$	(5,592)	$	(2,148)	$	(7,740)	$	(58)
Refining adjusted EBITDA*	63,063		(1,509)		61,554		646
Key performance indicators:
Refining gross margin	$	140,952	n/a		n/a		n/a
Refining gross margin per bbl of throughput(1)*	11.00		n/a		n/a		n/a
USGC 2-1-1 Crack Spread Per Barrel(2)	39.95		n/a		n/a		n/a
Operating expenses per bbl of throughput (3)	$	3.76	n/a		n/a		n/a

* See “Non-GAAP Financial Measures” below.

(1) Refining gross margin per throughput barrel is calculated as refining gross margin divided by total throughput barrels for the period presented.

(2) Crack Spread USGC 2-1-1. The crack spread is a measure of the difference between market prices for refined products and crude oil, commonly used by the refining industry. We use crack spreads as a performance benchmark for our refining gross margin and as a comparison with other industry participants. Crack spreads can fluctuate significantly, particularly when prices of refined products do not move in the same direction as the cost of crude oil. To calculate the crack spread we believe most closely relates to the crude intakes and products at the Mobile Refinery, we use two barrels of Louisiana Light Sweet crude oil, producing one barrel of USGC CBOB gasoline and one barrel of USGC ULSD.

(3) Operating expenses per throughput barrel are calculated as operating expenses minus depreciation and amortization divided by total throughput barrels for the period presented.

The following table shows average throughput and product yield at the Mobile Refinery since we acquired it on April 1, 2022. During the third quarter of 2022, the Mobile Refinery underwent a turnaround at the crude unit and change of catalyst at the diesel hydrotreater and reformer units, impacting our throughput volumes for the quarter.


	Three Months Ended September 30, 2022	Six Months Ended September 30, 2022
Refinery Feedstocks (bpd)
Crude oil	67,954	70,032
Total feedstocks	67,954	70,032

Refinery Yields (bpd)
Gasolines	15,310	16,646
Distillates	20,342	19,884
Jet fuel	11,026	10,860
Other (1)	21,147	22,390
Total average barrel yields per day	67,825	69,780

(1) Other includes intermediates and LPGs.

Third Quarter 2022 Compared to Third Quarter 2021 Discussion

Our Refining segment includes the business operations of our Refining and Marketing operations, which includes our Mobile Refinery. Revenues of $766.8 million in the Refining segment were up 3,020% during the three months ended September 30, 2022, as compared to the same period in 2021 mostly as a result of the operations of the Mobile Refinery, which had $733.5 of revenue, and the increased commodity prices and volume during the three months ended September 30, 2022. Overall volume for the Refining and Marketing segment increased during the three months ended September 30, 2022, as compared to the same period in 2021.

Gross profit for the segment was $48.5 million, of which $48.9 million was related to the Mobile Refinery. Our Legacy Refining and Marketing business experienced an increase in revenues of $8.7 million from the third quarter 2021 compared to the third quarter 2022. The decreased gross profit of $0.9 million from the legacy Refining and Marketing business was primarily due to higher commodity prices.

The Mobile Refinery had $26.2 million in operational expenses for the period, representing 93.8% of the total segment. The increase of $0.7 million quarter over quarter from the legacy Refining and Marketing business was primarily due to the higher inflation in 2022, compared to the same period in 2021.

Interest expense of $3.5 million for the third quarter 2022 included $2.1 million related to our inventory financing agreement and $1.4 million related to a capitalized equipment lease. There was no comparable activity for the same period in 2021.

Year to Date 2022 Compared to Year to Date 2021 Discussion

Our Refining segment includes the business operations of our Refining and Marketing operations, as well as the Mobile Refinery acquired on April 1, 2022. During the nine months ended September 30, 2022, our Refining and Marketing revenues were approximately $1,767.9 million, of which $1,655.7 million were from the Mobile Refinery operations. Cost of revenues (exclusive of depreciation and amortization) for the same period were $1,708.0 million, of which $1,598.9 million related to the processing costs of the Mobile Refinery, and depreciation and amortization attributable to cost of revenues was $6.3 million. During the nine months ended September 30, 2021, our Refining and Marketing revenues for the same period were $67.7 million, cost of revenues (exclusive of depreciation and amortization) were $65 million, and depreciation and amortization attributable to cost of revenues were $379 thousand.

Gross profit for the segment was $54.5 million, of which $49.7 million was related to the Mobile Refinery. Our legacy Refining and Marketing business experienced an increase in revenues of $49.5 million year to date 2021 compared to year to date 2022. The increase in gross profit from our legacy Refining and Marketing business of $2.0 million was primarily due to higher commodity prices.

The Mobile Refinery had $48.2 million in operation expenses for the period, representing 91.4% of the total segment. The increase of $2.0 million year to date 2021, over the same period in 2022 from the legacy Refining and Marketing business was primarily due to higher inflation during 2022, compared to the same period in 2021.

Interest expense of $6.8 million for the nine months ended September 30, 2022, included $3.8 million related to our inventory financing agreement, $2.7 million related to a capitalized equipment lease, and $0.2 for insurance financing. There was no comparable activity for the same period in 2021.

Non-GAAP Financial Measures

In addition to our results calculated under generally accepted accounting principles in the United States (“GAAP”), in this Report we also present Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA, each as discussed in greater detail below. Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA are “non-GAAP financial measures” presented as supplemental measures of the Company’s performance. They are not presented in accordance with GAAP. We use Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA as supplements to GAAP measures of performance to evaluate the effectiveness of our business strategies, to make budgeting decisions, to allocate resources and to compare our performance relative to our peers. Additionally, these measures, when used in conjunction with related GAAP financial measures, provide investors with an additional financial analytical framework which management uses, in addition to historical operating results, as the basis for financial, operational and planning decisions and present measurements that third parties have indicated are useful in assessing the Company and its results of operations. Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA are presented because we believe they provide additional useful information to investors due to the various noncash items during the period. Non-GAAP financial information similar to Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA are also frequently used by analysts, investors and other interested parties to evaluate companies in our industry.

Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA are unaudited, and have limitations as analytical tools, and you should not consider them in isolation, or as a substitute for analysis of our operating results as reported under GAAP. Some of these limitations are: Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA do not reflect cash expenditures, or future requirements for capital expenditures, or contractual commitments; Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA do not reflect changes in, or cash requirements for, working capital needs; Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA do not reflect the significant interest expense, or the cash requirements necessary to service interest or principal payments, on debt or cash income tax payments; although depreciation and amortization are noncash charges, the assets being depreciated and amortized will often have to be replaced in the future, Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA do not reflect any cash requirements for such replacements; Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA, represent only a portion of our total operating results; and other companies in this industry may calculate Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA differently than we do, limiting their usefulness as a comparative measure.

You should not consider Refining Gross Margin, Refining Gross Margin Per Barrel of Throughput and Refining Adjusted EBITDA in isolation, or as substitutes for analysis of the Company’s results as reported under GAAP. The Company’s presentation of these measures should not be construed as an inference that future results will be unaffected by unusual or nonrecurring items. We compensate for these limitations by providing a reconciliation of each of these non-GAAP measures to the most comparable GAAP measure below. We encourage investors and others to review our business, results of operations, and financial information in their entirety, not to rely on any single financial measure, and to view these non-GAAP measures in conjunction with the most directly comparable GAAP financial measure.

Refining gross margin.

Refining gross margin is defined as gross profit (loss) plus operating expenses and depreciation attributable to cost of revenues and other non-operating items included in costs of revenues, including unrealized losses on hedging activities and loss on inventory intermediation agreement.

Refining gross margin per barrel of throughput.

Refining gross margin per throughput barrel is calculated as refining gross margin divided by total throughput barrels for the period presented.

Refining Adjusted EBITDA.

Refining Adjusted EBITDA represents net income (loss) from operations plus depreciation and amortization, unrealized gains and losses on hedging activities, gain and loss on intermediation agreement, and certain other unusual or non-recurring charges included in selling, general, and administrative expenses.

The following tables reconcile GAAP gross profit to refining gross margin and net loss to refining Adjusted EBITDA for the periods presented (in thousands):


	Three Months Ended September 30,
	2022						2021
	Mobile Refinery		Legacy Refining and Marketing		Total Refining and Marketing		Legacy Refining and Marketing
Gross profit (loss)	$	48,882	$	(388)	$	48,494	$	508
Operating expenses included in cost of revenues	25,508		—		25,508		—
Depreciation and amortization attributable to costs of revenues	2,957		154		3,111		127
Unrealized gain on hedging activities	(46,977)		(775)		(47,752)		—
Loss on inventory intermediation agreement	17,972		—		17,972		—
Refining gross margin	$	48,342	$	(1,009)	$	47,333	$	635

Net income (loss)	$	18,370	$	(2,250)	$	16,120	$	(634)
Depreciation and amortization	3,693		268		3,961		235
Interest expenses	3,536		—		3,536		—
Unrealized gain on hedging activities	(46,977)		(775)		(47,752)		—
Loss on intermediation agreement	17,972		—		17,972		—
Acquisition costs	2,889		—		2,889		—

Refining adjusted EBITDA	$	(517)	$	(2,757)	$	(3,274)	$	(399)


	Nine Months Ended September 30,
	2022						2021
	Mobile Refinery		Legacy Refining and Marketing		Total Refining and Marketing		Legacy Refining and Marketing
Gross profit	$	50,849	$	2,673	$	53,522	$	2,749
Operating expenses included in cost of revenues	43,083		—		43,083		—
Depreciation and amortization attributable to costs of revenues	5,944		395		6,339		379
Unrealized gain on hedging activities	(76)		(68)		(144)		—
Loss on inventory intermediation agreement	41,152		—		41,152		—
Refining gross margin	$	140,952	$	3,000	$	143,952	$	3,128

Net income (loss)	$	(5,592)	$	(2,148)	$	(7,740)	$	(58)
Depreciation and amortization	7,416		707		8,123		704
Interest expenses	6,768		—		6,768		—
Unrealized gain on hedging activities	(76)		(68)		(144)		—
Loss on intermediation agreement	41,152		—		41,152		—
Acquisition costs	11,967		—		11,967		—
Environmental reserve	1,428		—		1,428		—
Refining adjusted EBITDA	$	63,063	$	(1,509)	$	61,554	$	646

Black Oil and Recovery Segment

After the acquisition of the Mobile Refinery on April 1, 2022, the revenue of our Black Oil and Recovery segments are less than 10% of consolidated revenue. As a result, we have decided, beginning with the current quarter, to combine our Black Oil and Recovery segment into one segment which is engaged in operations across the entire used motor oil recycling value chain, including refinement, collection, aggregation, transportation, storage, recovery, and sales of aggregated feedstock and re-refined products to end-users. We collect and purchase used oil directly from generators such as oil change service stations, automotive repair shops, manufacturing facilities, petroleum refineries, petrochemical manufacturing operations, and a diverse network of suppliers who operate similar collection businesses to ours. We own a fleet of collection vehicles, which routinely visit generators to collect and purchase used motor oil.

We operate a refining facility in Baytown, Texas that uses our proprietary Thermal Chemical Extraction Process (“TCEP”), and we also utilize third-party processing facilities. We use TCEP to pre-treat used oil feedstock; prior to shipping to our facility in Marrero, Louisiana, where we re-refine used motor oil and produce VGO, which is then sold via barge to crude refineries to be utilized as an intermediate feedstock in the refining process, as well as to the marine fuels market. We also operate a re-refining complex located in Belle Chasse, Louisiana (“the Myrtle Grove facility”). This facility includes ground storage tanks with over 8.6 million gallons of storage capacity. These assets are used by both the Black Oil and Refining and Marketing segments. In addition, we also utilize third parties for the transportation and storage of used oil feedstocks. In many cases, we have contractual purchase and sale agreements with our suppliers and customers, respectively. We believe these contracts are beneficial to all parties involved because it ensures that a minimum volume is purchased from collectors and generators, a minimum volume is sold to our customers, and we are able to minimize our inventory risk by a spread between the costs to acquire used oil and the revenues received from the sale and delivery of used oil.

We also operate a generator solutions company for the proper recovery and management of hydrocarbon streams and other petroleum-based products, together with the recovery , processing and sale of ferrous and non-ferrous recyclable metal(s) products that are recovered from manufacturing and consumption.

The Black Oil and Recovery Segment includes our used motor oil business (the "UMO Business"), which includes the Company's Heartland refinery options ("Heartland Business"), which is presented as discontinued operations. Refer to Note 23, "Discontinued Operations" in Notes to Financial Statements for additional information.

The table below represents the operating results of Black Oil and Recovery Segment for the three and nine months ended September 30, 2022 and 2021 (in thousands):


	Three Months Ended September 30,						Nine Months Ended September 30,
	2022		2021		Variance*		2022		2021		Variance*
Revenues	$	43,439	$	26,410	$	17,029	$	147,545	$	80,124	$	67,421
Cost of revenues (exclusive of depreciation and amortization shown separately below)	35,299		22,205		13,094		111,740		63,431		48,309
Depreciation and amortization attributable to costs of revenues	939		901		38		2,805		2,623		182
Gross profit	7,201		3,304		3,897		33,000		14,070		18,930
Operating expenses
Selling general and administrative expense	4,919		3,618		1,301		13,383		10,841		2,542
Depreciation and amortization attributable to operating expenses	39		59		(20)		142		176		(34)
Total operating expenses	4,958		3,677		1,281		13,525		11,017		2,508
Income (loss) from operations	$	2,243	$	(373)	$	2,616	$	19,475	$	3,053	$	16,422

* Favorable variances are represented by positive numbers and unfavorable variances are represented by negative numbers.

Third Quarter 2022 to Third Quarter 2021 Highlights:

Revenue from operations for our Black Oil and Recovery Segment increased $17.0 million for the three months ended September 30, 2022, compared to 2021, as a result of increases in commodity prices, improved margins and a new Marine Division which provided positive revenue and a profit for the period, which was created at the end of 2021 for blending bunker fuels into the Gulf Coast Market.

The total income from the Black Oil and Recovery Segment was $2.2 million for the three months ended September 30, 2022, which increased $2.6 million compared to the same period ended September 30, 2021, due to the increased commodity prices.

Year to Date 2022 to Year to Date 2021 Highlights:

Revenue from operations for our Black Oil and Recovery segment increased $67.4 million for the nine months ended September 30, 2022, compared to 2021, and the percentage of gross profit increased to 22% for the nine months ended September 30, 2022 from 18% for the same period in 2021, as a result of higher commodity prices during the nine months ended September 30, 2022.

The total income from operations for our Recovery segment was $19.5 million for the nine months ended September 30, 2022, which increased $16.4 million compared to the same period ended September 30, 2021, due to the increased commodity prices.

Liquidity and Capital Resources

Our primary sources of liquidity have historically included cash flow from operations, proceeds from notes offerings, bank borrowings, term loans, public equity offerings and other financial arrangements. Uses of cash have included capital expenditures, acquisitions and general working capital needs.

The success of our business operations has been dependent on our ability to manage our margins which are a function of the difference between what we are able to pay or charge for raw materials and the market prices for the range of products produced. We also must maintain relationships with feedstock suppliers and end-product customers (including Shell, Macquarie and others), and operate with efficient management of overhead costs. Through these relationships, we have historically been able to achieve volume discounts in the procurement of our feedstock, thereby increasing the margins of our segments’ operations. The resulting operating cash flow is crucial to the viability and growth of our existing business lines.

We had total assets of approximately $647.6 million as of September 30, 2022, compared to $266.1 million at December 31, 2021. The increase was mainly due to the acquisition of the Mobile Refinery, increases in accounts receivable and inventory levels, due to the increases in commodity prices and volumes during the nine months ended September 30, 2022, and an increase in cash generated from our operations.

We had total current liabilities of approximately $272.0 million as of September 30, 2022, compared to $25.5 million at December 31, 2021. We had total liabilities of $527.2 million as of September 30, 2022, compared to total liabilities of $192.5 million as of December 31, 2021. The increase in current liabilities was mainly due to our inventory financing liabilities, increases in accounts payable and accrued liabilities as a result of rises in commodity prices and volumes along with the term loan balance, during the nine months ended September 30, 2022.

We had working capital of approximately $118.2 million as of September 30, 2022, compared to working capital of $148.7 million as of December 31, 2021. The decrease in working capital from December 31, 2021 to September 30, 2022 is mainly due to the increase in inventory, accounts payable and accrued liabilities, obligations under our inventory financing agreement (discussed above), for which inventory was purchased in September 2022 to be used for products and sales in early October 2022, and $6 million of term loan debt required to be repaid within the next 12 months. We also incurred a $3 million break fee paid for the termination of the Sales Agreement with Safety-Kleen, and $16.6 million of acquisition costs paid in connection with the Mobile Refinery purchase on April 1, 2022, during the nine months ended September 30, 2022.

The ongoing conflict between Russia and Ukraine, which began in the first quarter of 2022, and the economic sanctions imposed on Russia have decreased the global supply of crude oil affecting global prices. This conflict coupled with disruptions in supply chain that began with the COVID-19 pandemic in 2020, have resulted in increased inflation and higher market prices in crude oil and refined products. During the twelve months ended September 30, 2022, the Consumer Price Energy Index in the United States increased 19.7% impacting our gross margins. The Consumer Price All Items Index increased 8.2% for the same period impacting our operating expenses and slowing economic growth. While market conditions have improved through the end of 2021 and into 2022, we are still seeing extreme volatility in commodity pricing. Generally, however, the increase in refined product pricing has had a positive impact on our business and overall liquidity.

Our future operating cash flows will vary based on a number of factors, many of which are beyond our control, including the effects of inflation, increasing interest rates, commodity prices, the cost of recovered oil, and the ability to turn our inventory. Other factors that have affected and are expected to continue to affect earnings and cash flow are transportation, processing, and storage costs. Over the long term, our operating cash flows will also be impacted by our ability to effectively manage our

administrative and operating costs. Additionally, we may incur more capital expenditures related to the Mobile Refinery in the future.

Cash Flows from Operating, Investing and Financing Activities

We believe that we have sufficient liquid assets, cash flow from operations, borrowing capacity and adequate access to capital markets to meet our financial commitments, debt service obligations and anticipated capital expenditures for at least the next 12 months. We expect that our short-term liquidity needs which include debt service, working capital, and capital expenditures related to currently planned growth projects (including the ongoing renewable diesel conversion project designed to modify the Mobile Refinery's hydrocracking unit to produce renewable diesel fuel on a standalone basis) will be met through projected cash flow from operations, borrowings under our various facilities (if necessary) and asset sales.

Our current near term plans include continuing to transition the majority of our assets and operations away from used motor oil and towards several important objectives, the combination of which we believe will advance our strategy of becoming a leading pure-play energy transition company of scale in connection with the recent acquisition of the Mobile Refinery. The refinery, which has a long track record of safe, reliable operations and consistent financial performance, has, effective on April 1, 2022, upon the closing of the acquisition, become our flagship refining asset, which we believe positions us to become a pure-play producer of renewable and conventional products. The addition of renewable fuels production associated with the refinery upon completion of the ongoing capital project at the refinery is anticipated to accelerate Vertex’s strategic focus on "clean" refining.

As previously disclosed, we are currently working on completing a $90 - $100 million capital project designed to modify the Mobile Refinery’s existing hydrocracking unit to produce renewable diesel fuel on a standalone basis. Upon completion of the conversion project, the refinery is expected to commence production of approximately 8,000 - 10,000 barrels per day (bpd) of renewable diesel, with production volumes anticipated to subsequently ramp up to approximately 14,000 bpd by the first quarter of 2024. This project seeks to capitalize on the rapidly growing demand for advanced sustainable fuels, while further expanding upon our commitment to supply lower carbon fuels solutions.

Currently, mechanical completion of the Mobile Refinery’s renewable diesel conversion project is expected to be complete during the first quarter of 2023 with production anticipated to begin in the second quarter of 2023. Upon completion of the planned renewable diesel project, Vertex expects to become one of the leading independent producers of renewable fuels in the southeastern United States.

Additionally, we or our affiliates may, at any time and from time to time, retire or repurchase our outstanding Convertible Senior Notes in open-market purchases, privately negotiated transactions, refinancing or otherwise, through cash purchases and/or exchanges for equity or debt. Such repurchases, refinancings or exchanges, if any, will be upon such terms and at such prices as we may determine, and will depend on prevailing market conditions, our liquidity requirements, contractual restrictions, and other factors. Repurchases, if any, will be funded through available cash from operations. The amounts involved may be material.

We anticipate that the market for our common stock will be subject to wide fluctuations in response to several factors moving forward, including, but not limited to:

(1)actual or anticipated variations in our results of operations;

(2)the market for, and volatility in, the market for oil and gas;

(3)our ability or inability to generate new revenues;

(4)the status of planned acquisitions and divestitures and ongoing capital projects at our facilities; and

(5)the number of shares in our public float.

Furthermore, because our common stock is traded on The NASDAQ Capital Market, our stock price may be impacted by factors that are unrelated or disproportionate to our operating performance. These market fluctuations, as well as general economic, political and market conditions, such as recessions, interest rates or international currency fluctuations may adversely affect the market price of our common stock. Additionally, there could be extreme fluctuations in the price of our common stock.

Shareholders and potential investors in our common stock should exercise caution before making an investment in our common stock, and should not rely on the publicly quoted or traded stock prices in determining our common stock value, but should instead determine the value of our common stock based on the information contained in our public reports and industry information.

Cash flows for the nine months ended September 30, 2022 and 2021, were as follows (in thousands):


	Nine Months Ended September 30,
	2022		2021
Beginning cash, cash equivalents and restricted cash	$	136,627	$	10,995
Net cash provided by (used in):
Operating activities	7,361		3,320
Investing activities	(264,035)		(14,152)
Financing activities	242,440		12,050
Net increase (decrease) in cash, cash equivalents and restricted cash	(14,234)		1,218
Ending cash, cash equivalents and restricted cash	$	122,393	$	12,213

The analysis of cash flow activities below and the table above, is combined for both continued and discontinued operations, whereas the consolidated statement of cash flows included in this report includes only cash flow information for our continued operations.

Our current primary sources of liquidity are cash generated from operations, cash flows from the November 2021 sale of the Convertible Senior Notes and amounts borrowed under the Term Loan on April 1, 2022 (approximately $124 million) and May 26, 2022 ($40 million).

Net cash provided by operating activities was approximately $7.4 million for the nine months ended September 30, 2022, as compared to net cash provided by operating activities of $3.3 million during the corresponding period in 2021. The primary reason for the decrease in cash provided by operating activities for the nine month period ended September 30, 2022, compared to the same period in 2021, was the operation of the Mobile Refinery, cash settlement of commodity derivative, and the net change of current asset and liabilities associated therewith, which had a net benefit on cash of around $11.5 million for the nine months ended on September 30, 2022, compared to the net cash used of $8.5 million during the same period end in 2021.

Investing activities used cash of approximately $264.0 million for the nine months ended September 30, 2022, as compared to $14.2 million of cash used during the corresponding period in 2021, due mainly to the acquisition of the Mobile Refinery and fixed assets purchased during the current period.

Financing activities provided cash of approximately $242.4 million for the nine months ended September 30, 2022, as compared to providing cash of $12.1 million during the corresponding period in 2021. Financing activities for the nine months ended September 30, 2022 were comprised of proceeds from the Term Loan $165.0 million and insurance premium finance of $173.3 million, from inventory financing of $135.7 million and from the exercise of options and warrants of $0.7 million offset by the payment on redemption of non-controlling interest of $50.7 million, distribution to noncontrolling interest of $0.4 million and payment on notes payable and capital leases of $14.1 million. Financing activities for the nine months ended September 30, 2021 were mainly comprised of proceeds from the exercise of options and warrants of $6.5 million and from proceeds of long term note and insurance premium finance of $10.1 million offset by the payment on notes payable and capital leases of $3.8 million.

More information regarding our loan agreements, leases, and Convertible Senior Notes, can be found under “Note 15. "Long-T erm Debt" to the unaudited financial statements included herein.

Critical Accounting Policies and Use of Estimates

Our financial statements are prepared in accordance with U.S. GAAP. The preparation of these financial statements requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. Management regularly evaluates its estimates and judgments, including those related to revenue recognition, intangible assets, long-lived assets valuation, variable interest entities, and legal matters. Actual results may differ from these estimates which may be material. Note 2, “Summary of Critical Accounting Policies and Estimates” in Part I, Item 1 of this Quarterly Report on Form 10-Q and in the Notes to Consolidated Financial Statements in Part II, Item 8 of our Annual Report on Form 10-K for the year ended December 31, 2021 (the “2021 Form 10-K”), and “Critical Accounting Policies and Estimates” in Part II, Item 7 of the 2021 Form 10-K describe the significant accounting policies and methods used in the preparation of the Company’s financial statements. There have been no material changes to the Company’s critical accounting policies and estimates since the 2021 Form 10-K.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

Market Risk

Our revenues and cost of revenues are affected by fluctuations in the value of energy related products. We attempt to mitigate much of the risk associated with the volatility of relevant commodity prices by using our knowledge of the market to obtain feedstock at attractive costs, by efficiently managing the logistics associated with our products, by turning our inventory over quickly and by selling our products into markets where we believe we can achieve the greatest value.

Interest Rate Risk

We are exposed to interest rate risks primarily through borrowings under various bank facilities. Interest on these facilities is based upon variable interest rates using Prime as the base rate.

Commodity Price Risk

We are exposed to market risks related to the volatility of crude oil and refined oil products. Our financial results can be significantly affected by changes in these prices which are driven by global economic and market conditions. We attempt to mitigate much of the risk associated with the volatility of relevant commodity prices by using our knowledge of the market to obtain feedstock at attractive costs, by efficiently managing the logistics associated with our products, by turning our inventory over quickly, and by selling our products into markets where we believe we can achieve the greatest value.

Inflation Risk

Inflationary factors such as increases in the cost of our products and overhead costs may adversely affect our results of operations. We believe that inflation has had an impact on our financial position and results of operations to date. We continue to monitor the impact of inflation in order to minimize its effects through price increases and cost reductions. A high rate of inflation in the future may have an adverse effect on our ability to maintain current levels of gross margin and selling, general, and administrative expenses as a percentage of net revenue if the selling prices of our products do not increase in proportion with these increased costs.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

We have established and maintain a system of disclosure controls and procedures that are designed to provide reasonable assurance that information required to be disclosed in our reports filed with the SEC pursuant to the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Commission and that such information is accumulated and communicated to our management, including our Chief Executive Officer (CEO)(principal executive officer) and Chief Financial Officer (CFO) (principal accounting/financial officer), as appropriate, to allow timely decisions regarding required disclosures.

Management, with the participation of our CEO and CFO, evaluated the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act) as of the end of the period covered by this report. As of September 30, 2022, based on the evaluation of these disclosure controls and procedures, and in light of the material weakness we found in our internal controls over financial reporting as of December 31, 2021 (as described in greater detail in our annual report on Form 10-K for the year ended December 31, 2021), our CEO and CFO have concluded that our disclosure controls and procedures were not effective to provide reasonable assurance that information required to be disclosed in our reports filed with the Securities and Exchange Commission pursuant to the Exchange Act, is recorded properly, processed, summarized and reported within the time periods specified in the rules and forms of the Commission and that such information is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosures.

Remediation Efforts to Address Material Weaknesses

We believe the remedial measures described in Part II, “Item 9A, Controls and Procedures” in our Annual Report on Form 10-K for the year ended December 31, 2021, and others that may be implemented, will remediate these material weaknesses. However, these material weaknesses will not be considered formally remediated until controls have operated effectively for a sufficient period of time and management has concluded, through testing, that the controls are operating effectively.

Inherent Limitations over Internal Controls

Management, including the Company’s Chief Executive Officer and Chief Financial Officer, does not expect that the Company’s internal controls will prevent or detect all errors and all fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of internal controls can provide absolute assurance that all control issues and instances of fraud, if any, have been detected. Also, any evaluation of the effectiveness of controls in future periods are subject to the risk that those internal controls may become inadequate because of changes in business conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Changes in Internal Control Over Financial Reporting

We regularly review our system of internal control over financial reporting to ensure we maintain an effective internal control environment. With the exception of our Mobile acquisition, which we are in the process of evaluating, there were no changes in our internal control over financial reporting that occurred during the three months ended September 30, 2022, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

From time to time, we may become party to litigation or other legal proceedings that we consider to be a part of the ordinary course of our business.

Such current litigation or other legal proceedings are described in, and incorporated by reference in, this “Item 1. Legal Proceedings” of this Form 10-Q from, “Part I” -“Item 1. Financial Statements” in the Notes to Consolidated Financial Statements in “Note 4. "Commitments and Contingencies"”, under the heading “Litigation”. The Company believes that the resolution of currently pending matters will not individually or in the aggregate have a material adverse effect on our financial condition or results of operations. However, assessment of the current litigation or other legal claims could change in light of the discovery of facts not presently known to the Company or by judges, juries or other finders of fact, which are not in accord with management’s evaluation of the possible liability or outcome of such litigation or claims.

Additionally, the outcome of litigation is inherently uncertain. If one or more legal matters were resolved against the Company in a reporting period for amounts in excess of management’s expectations, the Company’s financial condition and operating results for that reporting period could be materially adversely affected.

Item 1A. Risk Factors

Summary Risk Factors

We face risks and uncertainties related to our business, many of which are beyond our control. In particular, risks associated with our business include:

• our need for additional funding, the availability of, and terms of, such funding;

• our ability to pay amounts due on outstanding indebtedness, covenants of such indebtedness and security interests in connection therewith;

• the terms of our agreements with Macquarie, including termination rights associated therewith, and our ability to find a replacement partner, in the event such agreements were terminated;

• risks associated with unanticipated problems at, or downtime effecting, our facilities and those operated by third parties on which we rely;

• risks associated with our hedging activities, or our failure to hedge production;

• risks associated with our outstanding Convertible Notes, including amounts owed, conversion rights associated therewith, dilution caused thereby, redemption obligations associated therewith and our ability to repay such facilities and amounts due thereon when due;

• risks associated with an offtake agreement which will only become effective upon the occurrence of certain events, including the planned completion of a capital project at the Mobile Refinery;

• risks associated with the ongoing capital project associated with the Mobile refinery, including the timing thereof, costs associated therewith and our ability to generate revenues while such project is pending;

• the level of competition in our industry and our ability to compete;

• the supply and demand for oil and used oil, as well as used oil feed stocks and the price of oil and the feedstocks we use in our operations, process and sell;

• the availability of used oil feedstocks;

• our economics of using TCEP for its intended purpose;

• the outcome of natural disasters, hurricanes, floods, war, terrorist attacks, fires and other events negatively impacting our facilities and operations;

• our ability to respond to changes in our industry;

• the loss of key personnel or failure to attract, integrate and retain additional personnel;

• our ability to protect our intellectual property and not infringe on others’ intellectual property;

• our ability to scale our business;

• our ability to maintain supplier relationships and obtain adequate supplies of feedstocks;

• our ability to obtain and retain customers;

• our ability to produce our products at competitive rates;

• our ability to execute our business strategy in a very competitive environment;

• trends in, and the market for, the price of oil and gas and alternative energy sources;

• our ability to maintain our relationship with Bunker One (USA) Inc., Shell and Macquarie;

• the impact of competitive services and products;

• our ability to integrate acquisitions;

• our ability to complete future acquisitions;

• our ability to maintain insurance;

• potential future litigation, judgments and settlements;

• risk of increased regulation of our operations and products and rules and regulations making our operations more costly or restrictive;

• changes in environmental and other laws and regulations and risks associated with such laws and regulations;

• economic downturns both in the United States and globally;

• negative publicity and public opposition to our operations;

• disruptions in the infrastructure that we and our partners rely on;

• an inability to identify attractive acquisition opportunities and successfully negotiate acquisition terms;

• our ability to effectively integrate acquired assets, companies, employees or businesses;

• liabilities associated with acquired companies, assets or businesses;

• unexpected changes in our anticipated capital expenditures resulting from unforeseen required maintenance, repairs, or upgrades;

• prohibitions on borrowing and other covenants of our debt facilities;

• our ability to effectively manage our growth;

• the costs of required insurance, our lack of insurance, or claims not covered by our insurance;

• the redemptive rights of our agreements with partners;

• our lack of effective disclosure controls and procedures and internal control over financial reporting;

• loss of our ability to use net operating loss carry-forwards;

• improvements in alternative energy sources and technologies;

• decreases in global demand for, and the price of, oil, due to COVID-19, state, federal and foreign responses thereto;

• our ability to acquire sufficient amounts of used oil feedstock through our collection routes, to produce finished products, and in the absence of such internally collected feedstocks, our ability to acquire third-party feedstocks on commercially reasonable terms;

• risks of downturns in the U.S. and global economies due to COVID-19, increase in inflation or interest rates, and/or the ongoing conflict in Ukraine;

• the volatile nature of the market for our common stock;

• our ability to meet earnings guidance;

• anti-take-over rights in our governing documents;

• our ability to maintain the listing of our common stock on The Nasdaq Capital Market; and

• dilution caused by new equity offerings, the exercise of warrants and/or the conversion of outstanding convertible notes.

Risk Factors

There have been no material changes from the risk factors previously disclosed in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, filed with the Commission on March 14, 2022 (the “Form 10-K”), under the heading “Risk Factors”, except as set forth below, and investors should review the risks provided in the Form 10-K (as modified as discussed below) and below, prior to making an investment in the Company. The business, financial condition and operating results of the Company can be affected by a number of factors, whether currently known or unknown, including but not limited to those described below and in the Form 10-K for the year ended December 31, 2021, under “Risk Factors”, any one or more of which could, directly or indirectly, cause the Company’s actual financial condition and operating results to vary materially from past, or from anticipated future, financial condition and operating results. Any of these factors, in whole or in part, could materially and adversely affect the Company’s business, financial condition, operating results and stock price. Risk Factors designated by an asterisk (*) below represent Risk Factors which originally appeared in the December 31, 2021 Annual Report, which have been updated and supplemented below. Risk Factors not designated by an asterisk are new Risk Factors not included in the December 31, 2021 Annual Report.

Additionally, the following risk factors disclosed in the Annual Report are no longer relevant to the Company “The Heartland Company Agreement includes redemption rights.”; “The MG Company Agreement includes redemption rights.”; and all of the risk factors set forth under the subheading “Risks Related to the Planned Acquisition of the Mobile Refinery and Planned Acquisition of 100% of Heartland SPV and MG SPV”, except the risk factor titled “The Offtake Agreement with Idemitsu remains subject to various conditions, the obligations of Idemitsu thereunder may not become effective, may be terminated prior to the end of the initial term thereof, and we may face termination fees in connection therewith.”, which remains a risk applicable to the Company.

Risks Relating to Our Need for Future Funding and Current Indebtedness

We will need to raise additional capital in the future and our ability to obtain the necessary funding is uncertain.*

We will need to raise additional funding to meet the requirements of the terms and conditions of our outstanding Convertible Senior Notes, including to pay interest and principal thereon and to repay the Term Loan, and we may need to raise additional funding in the future to support our operations, complete acquisitions and grow our operations. If we raise additional funds in the future, by issuing equity securities, dilution to existing stockholders will result, and such securities may have rights, preferences and privileges senior to those of our common stock. If funding is insufficient at any time in the future and we are unable to generate sufficient revenue from new business arrangements, to repay our outstanding debts, complete planned acquisitions or operations, our results of operations and the value of our securities could be adversely affected. Future funding may not be available on favorable terms, if at all.

We have substantial indebtedness and plan to acquire additional indebtedness in the future, which could adversely affect our financial flexibility and our competitive position. Our future failure to comply with financial covenants in our debt agreements could result in such debt agreements again being declared in default.*

We have a significant amount of outstanding indebtedness. As of September 30, 2022, we owed approximately $114 million in accounts payable and accrued expenses, $121 million in connection with our inventory financing agreements obligations and $184 million, net of original issue discount "OID", under our senior notes payable and term loan (each described above under "Part I. - Item 1. Financial Statements and Supplementary Data" -"Note 10 . "In ventory Financing Agre e ment " and Note 15. "Long-Term Debt".

Our substantial indebtedness could have important consequences and significant effects on our business. For example, it could:

•increase our vulnerability to adverse changes in general economic, industry and competitive conditions;

•require us to dedicate a substantial portion of our cash flow from operations to make payments on our indebtedness, thereby reducing the availability of our cash flow to fund working capital, capital expenditures and other general corporate purposes;

•restrict us from taking advantage of business opportunities;

•make it more difficult to satisfy our financial obligations;

•place us at a competitive disadvantage compared to our competitors that have less debt obligations; and

•limit our ability to borrow additional funds for working capital, capital expenditures, acquisitions, debt service requirements, execution of our business strategy or other general corporate purposes on satisfactory terms or at all.

We may need to raise additional funding in the future to repay or refinance the Convertible Senior Notes, the Term Loan, planned future borrowings and our accounts payable, and as such may need to seek additional debt or equity financing. Such additional financing may not be available on favorable terms, if at all. If debt financing is available and obtained, our interest expense may increase and we may be subject to the risk of default, depending on the terms of such financing. If equity financing is available and obtained it may result in our stockholders experiencing significant dilution. If such financing is unavailable, we may be forced to curtail our operations, which may cause the value of our securities to decline in value and/or become worthless.

The requirements, restrictions and covenants in our Loan and Security Agreement may restrict our ability to operate our business and might lead to a default under such agreement.

The Loan and Security Agreement includes customary representations and warranties, and affirmative and negative covenants of the Loan Parties for a facility of that size and type, including prohibiting the Loan Parties from creating any indebtedness without the consent of the Lenders, subject to certain exceptions, and requiring the Loan Parties to have no less than $17.5 million of unrestricted cash for more than three consecutive business days.

The Loan and Security Agreement includes customary events of default for transactions of that type, including failures to pay amounts due, bankruptcy proceedings, covenant defaults, attachment or seizure of a material portion of the collateral securing the Loan and Security Agreement, cross defaults, if there is a default in any agreement governing indebtedness in excess of $3,000,000, resulting in the right to accelerate such indebtedness, certain judgments against a Loan Party, misrepresentations by the Loan Parties in the transaction documents, insolvency, cross default of the Offtake and Supply Agreement, a Change of Control (discussed below), termination of certain intercreditor agreements, and the loss or termination of certain material contacts. Upon the occurrence of an event of default, the Agent may declare the entire amount of obligations owed under the Loan and Security Agreement immediately due and payable and take certain other actions provided for under the Loan and Security Agreement, including enforcing security interests and guarantees.

Additionally, in the event of any payment, repayment or prepayment (other than with respect to a sale of the Company’s used motor oil assets or a change of control, and other than in connection with prepayments required to be made with funds received from insurance settlements and recoveries which are not subject to a prepayment premium), including in the event of acceleration of the Term Loan, certain asset sales (other than the used motor oil assets), certain equity issuances, and voluntary prepayments (a) during the first 18 months after the Closing Date, Vertex Refining agreed to pay an additional amount to the Lenders equal to 150% of the applicable interest rate, multiplied by the amount of such prepayment amount; (b) during the 19th through 24th months after the Closing Date, Vertex Refining agreed to pay an additional amount to the Lenders equal to 50% of the applicable interest rate, multiplied by the amount of such prepayment amount; and (c) at any time during the 25th month after the Closing Date, but prior to the date that is 90 days before the maturity date of amounts owed pursuant to the Loan and Security Agreement, Vertex Refining agreed to pay an additional amount to the Lenders equal to 25% of the applicable interest rate, multiplied by the amount of such prepayment amount. Upon the sale of the Company’s used motor oil assets (as discussed below), or the required repayment upon a change of control (also discussed below), Vertex Refining agreed to pay an additional amount to the Lenders equal to 1% of the aggregate principal amount of the amount prepaid (as applicable, the “Prepayment Premium”). The Prepayment Premium is also due upon a change of control, which includes the direct or indirect transfer of all or substantially all of the assets of the Loan Parties; the adoption of a plan of liquidation or dissolution relating to the Company; the acquisition in one or a series of transactions of 33% or more of the equity interests of the Company by a person or entity; the Company’s failure to own 100% of Vertex Refining and the other Loan Parties, unless permitted by the Lenders; during any period of twelve consecutive months commencing on or after the Closing Date, the occurrence of a change in the composition of the Board of Directors of the Company such that a majority of the members of

such Board of Directors are no longer directors; or a “change of control” or any comparable term under, and as defined in, any other indebtedness exceeding $2 million of the Loan Parties, shall have occurred (each a “Change of Control”).

As a result of these requirements, covenants and limitations, we may not be able to respond to changes in business and economic conditions and to obtain additional financing, if needed, and we may be prevented from engaging in transactions that might otherwise be beneficial to us. The breach of any of these requirements or covenants could result in a default under the Loan and Security Agreement or future credit facilities. Upon the occurrence of an event of default, the lenders could elect to declare all amounts outstanding under such Loan and Security Agreement or future debt facilities, including accrued interest or other obligations, to be immediately due and payable. If amounts outstanding under such Loan and Security Agreement or future debt facilities were to be accelerated, our assets might not be sufficient to repay in full that indebtedness and our other indebtedness.

Our Loan and Security Agreement and Supply and Offtake Agreement also contain cross-default and cross-acceleration provisions as may our future debt facilities. Under these provisions, a default or acceleration under one instrument governing our debt will in the case of the Loan and Security Agreement and Supply and Offtake Agreement and may in the case of future indebtedness, constitute a default under our other debt instruments that contain cross-default and cross-acceleration provisions, which could result in the related debt and the debt issued under such other instruments becoming immediately due and payable. In such event, we would need to raise funds from alternative sources, which funds might not be available to us on favorable terms, on a timely basis or at all. Alternatively, such a default could require us to sell assets and otherwise curtail operations to pay our creditors. The proceeds of such a sale of assets, or curtailment of operations, might not enable us to pay all of our liabilities.

A prolonged period of weak, or a significant decrease in, industry activity and overall markets, due to COVID-19 or otherwise, may make it difficult to comply with our covenants and the other restrictions in the agreements governing our debt and current global and market conditions have increased the potential for that difficulty.

Our ability to service our indebtedness will depend on our ability to generate cash in the future.

Our ability to make payments on our current (including our Convertible Senior Notes and Term Loan) and future indebtedness will depend on our ability to generate cash in the future. Our ability to generate cash is subject to general economic and market conditions and financial, competitive, legislative, regulatory and other factors that are beyond our control. Our business may not generate sufficient cash to fund our working capital requirements, capital expenditures, debt service and other liquidity needs, which could result in our inability to comply with financial and other covenants contained in our debt agreements, our being unable to repay or pay interest on our indebtedness, and our inability to fund our other liquidity needs. If we are unable to service our debt obligations, fund our other liquidity needs and maintain compliance with our financial and other covenants, we could be forced to curtail our operations, our creditors could accelerate our indebtedness and exercise other remedies and we could be required to pursue one or more alternative strategies, such as selling assets or refinancing or restructuring our indebtedness. However, such alternatives may not be feasible or adequate.

Our obligations under the Loan and Security Agreement and Supply and Offtake Agreement are secured by a first priority security interest in substantially all of our assets and various Company guarantees.

The amounts borrowed pursuant to the terms of the Loan and Security Agreement are secured by substantially all of the present and after-acquired assets of the Company and its subsidiaries. Additionally, Vertex Refining’s obligations under the Loan and Security Agreement are jointly and severally guaranteed by substantially all of the Company’s subsidiaries and the Company. The amounts owed under the Loan and Security Agreement are also secured by various deeds of trusts and mortgages for the real property(s) described therein, over the Mobile Refinery and substantially all other material owned and leased real property of the Guarantors including properties in Texas and Louisiana. In connection with the entry into the Loan and Security Agreement, Vertex Operating, entered into an Intellectual Property Security Agreement in favor of the Agent, pursuant to which it granted a security interest in substantially all of its intellectual property (including patents and trademarks) in favor of the Lenders to secure the obligations of the Loan Parties under the Loan and Security Agreement. In connection with the entry into the Loan and Security Agreement, the Company, Vertex Refining and each of the Guarantors, entered into a Collateral Pledge Agreement in favor of the Agent, pursuant to which they granted the Agent a security interest in all now owned or hereafter acquired promissory notes and instruments evidencing indebtedness to any Guarantor and all now owned or hereafter acquired equity interests owned by such Guarantor.

of Macquarie, executed by Vertex Refining. In addition, the Supply and Offtake Agreement also requires that Vertex Refining post and maintain cash collateral (in the form of an independent amount) as security for Vertex Refining’s obligations under the Supply and Offtake Agreement and the related transaction documents. The amount of cash collateral is subject to adjustments during the term.

As a result of the above, our creditors and Macquarie, in the event of the occurrence of a default under the Loan and Security Agreement or Supply and Offtake Agreement, respectively, may enforce their security interests over our assets and/or our subsidiaries which secure such obligations, take control of our assets and operations, force us to seek bankruptcy protection, or force us to curtail or abandon our current business plans and operations. If that were to happen, any investment in the Company (including, but not limited to any investment in our common stock) could become worthless.

Our arrangement with Macquarie exposes us to Macquarie-related credit and performance risk as well as potential refinancing risks.

In April 2022, we entered into several agreements with Macquarie to support the operations of the Mobile Refinery, including a Supply and Offtake Agreement. Pursuant to the Supply and Offtake Agreement, Macquarie has agreed to intermediate crude oil supplies and refined product inventories at the Mobile Refinery. Macquarie will own all of the crude oil in our tanks and substantially all of our refined product inventories prior to our sale of the inventories.

Should Macquarie terminate the Supply and Offtake Agreement with 180 days written notice, we would need to seek alternative sources of financing, including the requirement upon termination to repurchase the inventory at then current market prices. In addition, the cost of repurchasing the inventory may be at higher prices than we sold the inventory. If the price of crude oil is well above the price at which we sold the inventory, we would have to pay more for the inventory than the price we sold the inventory for. If this is the case at the time of termination, we could suffer significant reductions in liquidity when Macquarie terminates the Supply and Offtake Agreement and we have to repurchase the inventories. We may also be unable to enter into a similar relationship with a third party which may impair our ability to operate the Mobile Refinery and purchase inventory therefore, which could have a material adverse effect on our operations and cash flows.

If we are unable to obtain crude oil supplies for our Mobile Refinery without the benefit of certain intermediation agreements, the capital required to finance our crude oil supply could negatively impact our liquidity.

All of the crude oil delivered at our Mobile Refinery is subject to our Supply and Offtake Agreements with Macquarie. If we are unable to obtain our crude oil supply for our refinery under these agreements, our exposure to crude oil pricing risks may increase as the number of days between when we pay for the crude oil and when the crude oil is delivered to us increases. Such increased exposure could negatively impact our liquidity position due to the increase in working capital used to acquire crude oil inventory for our refineries.

The Intermediation Agreements expose us to counterparty credit and performance risk.

We have Supply and Offtake Agreements with Macquarie, pursuant to which Macquarie will intermediate crude oil supplies and refined product inventories at our Mobile Refinery. Macquarie will own all of the crude oil in our tanks and substantially all of our refined product inventories prior to our sale of the inventories. Upon termination of the Supply and Offtake Agreements, unless extended by mutual agreement for an additional one year term, we are obligated to repurchase all crude oil and refined product inventories then owned by Macquarie and located at the specified storage facilities at then current market prices. This repurchase obligation could have a material adverse effect on our business, results of operations, or financial condition. An adverse change in the business, results of operations, liquidity, or financial condition of our intermediation counterparties could adversely affect the ability of such counterparties to perform their obligations, which could consequently have a material adverse effect on our business, results of operations, or liquidity and, as a result, our business and operating results.

Continued increases in interest rates will cause our debt service obligations to increase.

The amounts borrowed under the Loan and Security Agreement bear interest at a rate per annum equal to the sum of (i) the greater of (x) the per annum rate publicly quoted from time to time by The Wall Street Journal as the “Prime Rate” in the United States minus 1.50% as in effect on such day and (y) the Federal Funds rate for such day plus 0.50%, subject in the case of this clause (i), to a floor of 1.0%, plus (ii) 9.25%, which rate is currently 14%. Interest rates have recently been increasing and any continued increase in the interest rates associated with our floating-rate debt would increase our debt service costs and affect our results of operations. In addition, a future increase in interest rates could adversely affect our future ability to obtain financing or materially increase the cost of any additional financing.

Economic uncertainty may affect our access to capital and/or increase the costs of such capital.

Global economic conditions continue to be volatile and uncertain due to, among other things, consumer confidence in future economic conditions, fears of recession and trade wars, global conflicts, including the ongoing conflict between Russia and Ukraine, the price of energy, increasing interest rates, the availability and cost of consumer credit, the availability and timing of government stimulus programs, levels of unemployment, increased inflation, and tax rates. These conditions remain unpredictable and create uncertainties about our ability to raise capital in the future. In the event required capital becomes unavailable in the future, or more costly, it could have a material adverse effect on our business, results of operations, and financial condition.

Risks Relating to Our Operations, Business and Industry

Unanticipated problems at, or downtime effecting, our facilities and those operated by third parties on which we rely, could have a material adverse effect on our results of operations.*

Our ability to process feedstocks depends on our ability to operate our refining/processing operations and facilities, including our Mobile Refinery, and those operated by third parties on which we rely, including, but not limited to Monument Chemical, and the total time that such facilities are online and operational. The occurrence of significant unforeseen conditions or events in connection with the operation or maintenance of such facilities, such as the need to refurbish such facilities, complete capital projects at such facilities, shortages of workers or materials, adverse weather, including, but not limited to lightning strikes, floods, hurricanes, tornadoes and earthquakes, equipment failures, fires, explosions, oil or other leaks, damage to or destruction of property and equipment associated therewith, environmental releases and/or damage, government regulation changes affecting the use of such facilities, terrorist attacks, mechanical or physical failures of equipment, acts of God, or other conditions or events, could prevent us from operating our facilities, or prevent such third parties from operating their facilities, or could force us or such third parties to shut such facilities down for repairs, maintenance, refurbishment or upgrades for a significant period of time. In the event any of our facilities or those of third parties on which we rely are offline for an extended period of time, it could have a material adverse effect on our results of operations and consequently the price of our securities. For example, on October 7, 2020, we had a fire at our Marrero refinery which took the facility offline for repairs for about two weeks. The refinery suffered some minor structural damage along with piping, valves and instrumentation in the immediate area of the fire, the largest impact was the damage to the electrical conduit that feeds the power to the refinery equipment and was back up October 26, 2020. Additionally, during August and September 2020, two hurricanes brought severe flooding and high winds that adversely impacted operations in the Gulf Coast and, specifically at the Company’s Marrero, Louisiana refinery, while also limiting outbound shipments of finished product along adjacent waterways between Houston and New Orleans for approximately two weeks. Additionally, during August 2021, Hurricane Ida made landfall in southeast Louisiana, approximately 30 miles directly south and west of the Myrtle Grove facility, which resulted in the entire 42 acre Myrtle Grove site to be covered with 4-6 feet of storm surge and thus damages of assets and equipment. The Company reviewed the inspection report and related information from insurance companies and a third party engineer, and determined that there is no 100% certainty around the recoverability of some Construction-In-Progress assets such as fire heaters and pumps and instrumentation. The Company recorded $2.1 million of loss on assets impairment on the Consolidated Statements of Operations in the fourth quarter of 2021, of which the entire amount is related to our Black Oil segment. Subsequent downtime at our facilities, including our newly acquired Mobile Refinery, losses of equipment or use of such facilities may have a material adverse effect on our operations, cash flows or assets. The Company believes that it maintains adequate insurance coverage.

Unanticipated problems or delays, or increases in costs, in connection with the ongoing capital project at the Mobile Refinery may harm our business and viability.

We are in the process of completing a $90-100 million capital project designed to modify the Mobile Refinery’s hydrocracking unit to produce renewable diesel fuel on a standalone basis (the “Conversion”). The occurrence of significant unforeseen conditions or events in connection with the Conversion may make the Conversion more expensive, prevent us from completing the Conversion, delay the completion of the Conversion or require us to reexamine our business model. Any change to our business model or management’s evaluation of the viability of the Conversion or timing associated therewith may adversely affect our business. Construction costs for the Conversion may also increase to a level that would make such Conversion too expensive to complete or unprofitable to operate, due to increases in material, labor, inflation or otherwise. Contractors, engineering firms, construction firms and equipment suppliers also receive requests and orders from other companies and, therefore, we may not be able to secure their services or products on a timely basis or on acceptable financial terms. We may suffer significant delays or cost overruns as a result of a variety of factors, such as increases in the prices of raw materials, shortages of workers or materials, transportation constraints, adverse weather, equipment failures, fires, damage to or

destruction of property and equipment, environmental damage, unforeseen difficulties or labor issues, or issues associated with planned capital projects, including cost overruns and unforeseen delays, and have already delayed the completion of the project once due to supply constraints, any of which could prevent us from timely completing the Conversion.

We may be unable to sell our UMO Business and no do not anticipate seeking shareholder approval for such sale.*

Our agreement with Safety-Kleen to acquire our UMO Business was terminated in January 2022. We are continuing to seek sales opportunities relating to such UMO Business, but we may be unable to find a purchaser to purchase such UMO Business on as favorable terms as Safety-Kleen had previously agreed to acquire such assets, such sale may be unable to be completed due to required conditions to closing, including governmental regulations, and the knowledge that we are actively trying to sell our UMO Business may result in depressed prices. As a result, we may not be able to sell our UMO Business on favorable terms, if at all and/or may face termination and other fees in connection with any planned sale which is subsequently abandoned. Additionally, as a result of the acquisition of the Mobile Refinery, we no longer anticipate needing, or obtaining, shareholder approval for the future sale of our UMO Business or our Heartland Business.

Claims above our insurance limits, or significant increases in our insurance premiums, may reduce our profitability.*

We currently employ approximately 95 full-time drivers. From time to time, some of these employee drivers are involved in automobile accidents. We currently carry liability insurance of $1,000,000 for our drivers, subject to applicable deductibles, and carry umbrella coverage up to $25,000,000. We currently employ over 500 employees. Claims against us may exceed the amounts of available insurance coverage. If we were to experience a material increase in the frequency or severity of accidents, liability claims or workers’ compensation claims or unfavorable resolutions of claims, our operating results could be materially affected.

Our hedging activities have in the past and may in the future prevent us from benefiting fully from increases in oil prices and may expose us to other risks, including counterparty risk.

We use derivative instruments to hedge the impact of fluctuations in oil and other prices on our results of operations and cash flows and are also required to use such hedges pursuant to the terms of the Loan and Security Agreement. We have in the past, and to the extent that we continue to engage in hedging activities to protect ourselves against commodity price declines, we may be prevented from fully realizing the benefits of increases in oil prices above the prices established by our hedging contracts and/or may result in us paying more for oil feedstocks then we receive upon the sale of finished products as we hedge finished product sales and not feedstock purchases. For example, as of September 30, 2022, our outstanding oil hedges had a fair value of positive $1.2 million. Our hedging activities may expose us to the risk of financial loss in certain circumstances, including instances in which the counterparties to our hedging contracts fail to perform under the contracts. Finally, we are subject to risks associated with the adoption of derivatives legislation and regulations related to derivative contracts which if adopted, could have an adverse impact on our ability to hedge risks associated with our business. If regulations adopted in the future require that we post margin for our hedging activities or require our counterparties to hold margin or maintain capital levels, the cost of which could be passed through to us, or impose other requirements that are more burdensome than current regulations, hedging transactions in the future would become more expensive than we experienced in the past. Our hedges have in the past and may in the future result in significant losses and reduce the amount of revenue we would otherwise obtain upon the sale of finished products and may also increase our margins and decrease our net revenues.

We depend on certain third-party pipelines for transportation of feedstocks and products, and if these pipelines become unavailable to us, our revenues and cash available for payment of our debt obligations could decline.

Our Mobile Refinery is interconnected to a pipeline that supplies a portion of its crude oil feedstock. Since we do not own or operate this pipeline, its continuing operation is not within our control. The unavailability of any third-party pipelines for the transportation of crude oil or finished products, because of acts of God, accidents, earthquakes or hurricanes, government regulation, terrorism or other third-party events, could lead to disputes or litigation with certain of our suppliers or a decline in our sales, net income and cash available for payments of our debt obligations.

We make capital expenditures in our facilities to maintain their reliability and efficiency. If we are unable to complete capital projects at their expected costs and/or in a timely manner, or if the market conditions assumed in our projected economics deteriorate, results of operations or cash flows could be adversely affected.

Delays or cost increases related to the engineering, procurement and construction of new facilities, or improvements and repairs to our existing facilities and equipment, could have a material adverse effect on our business, financial condition,

results of operations or our ability to make payments on our debt obligations. Such delays or cost increases may arise as a result of unpredictable factors in the marketplace, many of which are beyond our control, including:

• denial or delay in obtaining regulatory approvals and/or permits;

• changes in government regulations, including environmental and safety regulations;

• unplanned increases in the cost of equipment, materials or labor;

• disruptions in transportation of equipment and materials;

• severe adverse weather conditions, natural disasters or other events (such as equipment malfunctions, explosions, fires or spills) affecting our facilities, or those of our vendors and suppliers;

• shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;

• market-related increases in a project’s debt or equity financing costs; and/or

• nonperformance or declarations of force majeure by, or disputes with, our vendors, suppliers, contractors or sub-contractors.

Equipment, even if properly maintained, may require significant capital expenditures and expenses to keep it operating at optimum efficiency.

Any one or more of these occurrences noted above could have a significant impact on our business or subject us to significant cost overruns. If we were unable to make up the delays or to recover the related costs, or if market conditions change, we may not realize the anticipated benefits of our capital projects and it could materially and adversely affect our financial position, results of operations or cash flows and, as a result, our ability to make payments of our debt obligations.

From time to time, we may seek to divest portions of our business, which could materially affect our results of operations and result in disruption to other parts of the business.

We may dispose of portions of our current business or assets (including, but not limited to our UMO Business, which we are actively seeking to divest), based on a variety of factors and strategic considerations, consistent with our strategy of preserving liquidity and streamlining our business to better focus on the advancement of our core business. We expect that any potential divestitures of assets will also provide us with cash to reinvest in our business and repay indebtedness. These dispositions, together with any other future dispositions we make, may involve risks and uncertainties, including disruption to other parts of our business, potential loss of employees, customers or revenue, exposure to unanticipated liabilities or result in ongoing obligations and liabilities to us following any such divestiture. In addition, any such divestitures may not yield the targeted improvements in our business. Any of the foregoing could adversely affect our financial condition and results of operations or cash flows and, as a result, our ability to make payments of our debt obligations.

The prices of crude oil and refined and finished lubricant products materially affect our profitability, and are dependent upon many factors that are beyond our control, including general market demand and economic conditions, seasonal and weather-related factors, regional and grade differentials and governmental regulations and policies.

Among these factors is the demand for crude oil and refined and finished lubricant products, which is largely driven by the conditions of local and worldwide economies, as well as by weather patterns, changes in consumer preferences and the taxation of these products relative to other energy sources. Governmental regulations and policies, particularly in the areas of taxation, energy and the environment, and more recently in response to the COVID-19 pandemic, also have a significant impact on our activities. Operating results can be affected by these industry factors, product and crude pipeline capacities, crude oil differentials (including regional and grade differentials), changes in transportation costs, accidents or interruptions in transportation, competition in the particular geographic areas that we serve, global market conditions, actions by foreign nations and factors that are specific to us, such as the efficiency of our refinery operations. The demand for crude oil and refined and finished lubricant products can also be reduced due to a local or national recession or other adverse economic condition, which results in lower spending by businesses and consumers on gasoline and diesel fuel, higher gasoline prices due to higher crude oil prices, a shift by consumers to more fuel-efficient vehicles or alternative fuel vehicles (such as ethanol or wider adoption of gas/electric hybrid vehicles), or an increase in vehicle fuel economy, whether as a result of technological advances by manufacturers, legislation mandating or encouraging higher fuel economy or the use of alternative fuel.

We do not produce crude oil and must purchase all our crude oil, the price of which fluctuates based upon worldwide and local market conditions. Our profitability depends largely on the spread between market prices for refined petroleum products and crude oil prices. This margin is continually changing and may fluctuate significantly from time to time. Crude oil and refined products are commodities whose price levels are determined by market forces beyond our control. For example, the reversal of certain existing pipelines or the construction of certain new pipelines transporting additional crude oil or refined products to markets that serve competing refineries could affect the market dynamic that has allowed us to take advantage of favorable pricing. A deterioration of crack spreads or price differentials between domestic and foreign crude oils could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Additionally, due to the seasonality of refined products markets and refinery maintenance schedules, results of operations for any particular quarter of a fiscal year are not necessarily indicative of results for the full year and can vary year to year in the event of unseasonably cool weather in the summer months and/or unseasonably warm weather in the winter months in the markets in which we sell our petroleum products. In general, prices for refined products are influenced by the price of crude oil. Although an increase or decrease in the price for crude oil may result in a similar increase or decrease in prices for refined products, there may be a time lag in the realization of the similar increase or decrease in prices for refined products. The effect of changes in crude oil prices on operating results, therefore, depends in part on how quickly refined product prices adjust to reflect these changes. A substantial or prolonged increase in crude oil prices without a corresponding increase in refined product prices, a substantial or prolonged decrease in refined product prices without a corresponding decrease in crude oil prices, or a substantial or prolonged decrease in demand for refined products could have a significant negative effect on our earnings and cash flow. Also, our crude oil and refined products inventories are valued at the lower of cost or market under the last-in, first-out (“LIFO”) inventory valuation methodology, excluding commodity inventories at the Mobile Refinery which use the weighted average inventory accounting method. If the market value of our inventory were to decline to an amount less than our LIFO cost, we would record a write-down of inventory and a non-cash charge to cost of products sold even when there is no underlying economic impact at that point in time. Continued volatility in crude oil and refined products prices could result in lower of cost or market inventory charges in the future, or in reversals reducing cost of products sold in subsequent periods should prices recover.

To successfully operate our facilities, we are required to expend significant amounts for capital outlays and operating expenditures. If we are unable to complete capital projects at their expected costs or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations, or cash flows could be materially and adversely affected.

Our facilities consist of many processing units, a number of which have been in operation for many years. One or more of the units may require unscheduled downtime for unanticipated maintenance or repairs that are more frequent than our scheduled turnaround for such units. Scheduled and unscheduled maintenance could reduce our revenues during the period of time that the units are not operating. The installation and redesign of key equipment at our facilities, including the ongoing renewable diesel capital project at the Mobile Refinery, involves significant uncertainties, including the following: our upgraded equipment may not perform at expected levels; operating costs of the upgraded equipment may be higher than expected; the yield and product quality of new equipment may differ from design and/or specifications and redesign, modification or replacement of the equipment may be required to correct equipment that does not perform as expected, which could require facility shutdowns until the equipment has been redesigned or modified. Any of these risks associated with new equipment, redesigned older equipment, or repaired equipment could lead to lower revenues or higher costs or otherwise have a negative impact on our future financial condition and results of operations.

One of the ways we may grow our business is through the construction of new refinery processing units (or the purchase and refurbishment of used units from another refinery) and the conversion or expansion of existing ones, such as the ongoing conversion at the Mobile Refinery to produce renewable biodiesel. Projects are generally initiated to increase the yields of higher-value products, increase the amount of lower cost crude oils that can be processed, increase refinery production capacity, meet new governmental requirements or take advantage of new government incentive programs, or maintain the operations of our existing assets. Additionally, our growth strategy includes projects that permit access to new and/or more profitable markets, including the growing demand for renewable diesel. The construction process involves numerous regulatory, environmental, political, and legal uncertainties, most of which are not fully within our control, including:

•third party challenges to, denials, or delays with respect to the issuance of requisite regulatory approvals and/or obtaining or renewing permits, licenses, registrations and other authorizations;

•societal and political pressures and other forms of opposition;

•compliance with or liability under environmental regulations;

•unplanned increases in the cost of construction materials or labor;

•disruptions in transportation of modular components and/or construction materials;

•severe adverse weather conditions, natural disasters, terror or cyberattacks, vandalism or other events (such as equipment malfunctions, explosions, fires or spills) affecting our facilities, or those of vendors and suppliers;

•shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;

•market-related increases in a project’s debt or equity financing costs; and/or

•nonperformance or force majeure by, or disputes with, vendors, suppliers, contractors, or sub-contractors involved with a project.

If we are unable to complete capital projects at their expected costs or in a timely manner our financial condition, results of operations, or cash flows could be materially and adversely affected. Delays in making required changes or upgrades to our facilities could subject us to fines or penalties as well as affect our ability to supply certain products we make. In addition, our revenues may not increase immediately upon the expenditure of funds on a particular project. For instance, the construction of our previously announced renewable diesel capital project at the Mobile Refinery will occur over an extended period of time and we will not receive any material increases in revenues until after completion of the project. Moreover, we may construct facilities to capture anticipated future growth in demand for refined products or renewable diesel in a region in which such growth does not materialize. As a result, new capital investments may not achieve our expected investment return, which could adversely affect our financial condition or results of operations.

In addition, from time to time, we have, and expect in the future to execute turnarounds at our refineries, which involve numerous risks and uncertainties. These risks include delays and incurrence of additional and unforeseen costs. The turnarounds allow us to perform maintenance, upgrades, overhaul and repair of process equipment and materials, during which time all or a portion of the refinery will be under scheduled downtime.

Our forecasted internal rates of return are also based upon our projections of future market fundamentals which are not within our control, including changes in general economic conditions, available alternative supply, global market conditions, actions by foreign nations and customer demand.

Competition in the refining industry is intense, and an increase in competition in the markets in which we sell our products could adversely affect our earnings and profitability.

We compete with a broad range of refining companies, including certain multinational oil companies. Because of their geographic diversity, larger and more complex refineries, integrated operations and greater resources, some of our competitors may be better able to withstand volatile market conditions, to obtain crude oil in times of shortage and to bear the economic risks inherent in all areas of the refining industry.

We are not engaged in petroleum exploration and production activities and do not produce any of the crude oil feedstocks used at our refineries. We do not have a retail business and therefore are dependent upon others for outlets for our refined products. Certain of our competitors, however, obtain a portion of their feedstocks from company-owned production and have retail outlets. Competitors that have their own production or extensive retail outlets, with brand-name recognition, are at times able to offset losses from refining operations with profits from producing or retailing operations, and may be better positioned to withstand periods of depressed refining margins or feedstock shortages.

In recent years there have been several refining and marketing consolidations or acquisitions between entities competing in our geographic market. These transactions could increase the future competitive pressures on us.

The markets in which we compete may be impacted by competitors’ plans for expansion projects and refinery improvements that could increase the production of refined products in our areas of operation and significantly affect our profitability.

Also, the potential operation of new or expanded refined product transportation pipelines, or the conversion of existing pipelines into refined product transportation pipelines, could impact the supply of refined products to our existing markets and negatively affect our profitability.

In addition, we compete with other industries that provide alternative means to satisfy the energy and fuel requirements of our industrial, commercial and individual consumers. The more successful these alternatives become as a result of governmental regulations, technological advances, consumer demand, improved pricing or otherwise, the greater the impact on pricing and demand for our products and our profitability. There are presently significant governmental and consumer pressures to increase the use of alternative fuels in the United States.

The market for our lubricants is highly competitive and requires us to continuously develop and introduce new products and product enhancements.

Our ability to grow our lubricants depends, in part, on our ability to continuously develop, manufacture and introduce new products and product enhancements on a timely and cost-effective basis, in response to customers’ demands for higher performance process lubricants and other product offerings. Our competitors may develop new products or enhancements to their products that offer performance, features and lower prices that may render our products less competitive or obsolete, and, as a consequence, we may lose business and/or significant market share. Our efforts to respond to changes in consumer demand in a timely and cost-efficient manner to drive growth could be adversely affected by unfavorable margins or difficulties or delays in product development and service innovation, including the inability to identify viable new products, successfully complete research and development, obtain regulatory approvals, obtain intellectual property protection or gain market acceptance of new products or service techniques. The development and commercialization of new products requires significant expenditures over an extended period of time, and some products that we seek to develop may never become profitable, and we could be required to write-off our investments related to a new product that does not reach commercial viability.

A material decrease in the supply, or a material increase in the price, of crude oil or other raw materials or equipment available to our refineries and other facilities could significantly reduce our production levels and negatively affect our operations.

To maintain or increase production levels at our refineries, we must continually contract for crude oil supplies from third parties. There are a limited number of crude oil suppliers in certain geographic regions, and in such cases, we may be required to source from more than one supplier. If we are unable to maintain or extend our existing contracts with any such crude oil suppliers, or enter into new agreements on similar terms, the supply of crude oil could be adversely impacted, or we may incur a higher cost. A material decrease in crude oil production from the fields that supply our refineries, as a result of depressed commodity prices, decreased demand, lack of drilling activity, natural production declines, catastrophic events or otherwise, could result in a decline in the volume of crude oil available to our refineries. In addition, any prolonged disruption of a significant pipeline that is used in supplying crude oil to our refineries or the potential operation of a new, converted or expanded crude oil pipeline that transports crude oil to other markets could result in a decline in the volume of crude oil available to our refineries. Such an event could result in an overall decline in volumes of refined products processed at our refineries and therefore a corresponding reduction in our cash flow. If we are unable to secure additional crude oil supplies of sufficient quality or crude pipeline expansion to our refineries, we will be unable to take full advantage of current and future expansion of our refineries’ production capacities.

For certain raw materials and utilities used by our refineries and other facilities, there are a limited number of suppliers, and, in some cases, we source from a single supplier and/or suppliers in economies that have experienced instability or the supplies are specific to the particular geographic region in which a facility is located. Any significant disruption in supply could affect our ability to obtain raw materials, or increase the cost of such raw materials, which could significantly reduce our production levels or have a material adverse effect on our business, financial condition and results of operations. In addition, certain raw materials that we use are subject to various regulatory laws, and a change in the ability to legally use such raw materials may impact our liquidity, financial position and results of operations.

It is also common in the refining industry for a facility to have a sole, dedicated source for its utilities, such as steam, electricity, water and gas. Having a sole or limited number of suppliers may limit our negotiating power, particularly in the case of rising raw material costs. Any new supply agreements we enter into may not have terms as favorable as those contained in our current supply agreements. Additionally, there is growing concern over the reliability of water sources. The decreased availability or less favorable pricing for water as a result of population growth, drought or regulation could negatively impact our operations.

In addition, periods of disruption in the global supply chain, including as a result of COVID-19, have caused shortages in the equipment and parts necessary to operate our facilities and complete our capital projects. Certain suppliers have experienced, and may continue to experience, delays related to a variety of factors, including logistical delays and component shortages from vendors. We continue to monitor the situation and work closely with our suppliers to minimize disruption to our operations as a result of supply chain interruptions.

If our raw material, utility or water supplies or access to the equipment necessary to operate our facilities were disrupted, our businesses may incur increased costs to procure alternative supplies or equipment or incur excessive downtime, which would have a direct negative impact on our operations.

We depend upon Shell for a substantial portion of the crude supply and distribution network that serve our Mobile Refinery.

Currently Shell supplies all of the crude oil which we refine at the Mobile Refinery. Shell is subject to its own operating and regulatory risks and the occurrence of any of these risks could directly or indirectly affect Shell’s as well as our financial condition, results of operations and cash flows if Shell is unable to deliver us sufficient crude oil to operate the Mobile Refinery at full capacity. Additionally, these risks could affect Shell’s ability to continue operations which could affect its ability to serve our supply and distribution network needs.

We have been and may in the future be negatively impacted by inflation.

Increases in inflation have already, and may in the future, have an adverse effect on us. Current and future inflationary effects may be driven by, among other things, supply chain disruptions and governmental stimulus or fiscal policies. Continuing increases in inflation have already, and could in the future, impact the commodity markets generally, the overall demand for our products, our costs for feedstocks, labor, material and services and the margins we are able to realize on our products and services, all of which have already, and could in the future, have an adverse impact on our business, financial position, results of operations and cash flows. Inflation may and has already resulted in higher interest rates, which in turn results in higher interest expense related to our variable rate indebtedness and any borrowings we undertake to refinance existing fixed rate indebtedness.

Large capital projects can take many years to complete, and the political and regulatory environments or other market conditions may change or deteriorate over time, negatively impacting project returns.

We may engage in capital projects based on the forecasted project economics, political and regulatory environments, and the expected return on the capital to be employed in the project, including the in process Mobile Refinery renewal biodiesel capital project. Large-scale projects take many years to complete, during which time the political and regulatory environment or other market conditions may change from our forecast. As a result, we may not fully realize our expected returns, which could negatively impact our business, financial condition, results of operations, and liquidity.

Our industry and the broader US economy have experienced higher than expected inflationary pressures in the first three quarters of 2022, related to continued supply chain disruptions, labor shortages and geopolitical instability. Should these conditions persist our business, results of operations and cash flows could be materially and adversely affected.

The first three quarters of 2022 have seen significant increases in the costs of certain materials, including construction material required for our ongoing capital project at our Mobile Refinery and longer lead times for such materials, as a result of availability constraints, supply chain disruption, increased demand, labor shortages associated with a fully employed US labor force, high inflation and other factors. Supply and demand fundamentals have been further aggravated by disruptions in global energy supply caused by multiple geopolitical events, including the ongoing conflict between Russia and Ukraine. During 2022 and 2021, refining margins have experienced significant volatility, resulting in an increase in the first nine months of 2022, in each of the benchmark commodities we track compared to the same period in 2021. The increase in market prices was a result of the ongoing conflict between Russia and Ukraine and increased inflation. The Ukraine conflict coupled with disruptions in supply chain that began with the COVID-19 pandemic in 2020, have resulted in increased inflation and higher market prices in crude oil and refined products. During the twelve months ended September 30, 2022, the Consumer Price Energy Index in the United States increased 19.7% impacting our gross margins. The Consumer Price All Items Index increased 8.2% for the same period impacting our operating expenses and slowing economic growth. Recent supply chain constraints and inflationary pressures have in the past, and may in the future continue to, adversely impact our operating costs and timelines for capital projects and may negatively impact our ability to procure materials and equipment in a timely and cost-effective manner, if at all, which could result in delays in the completion of ongoing and future capital projects, delays in turn-arounds at our facilities, increased down-time, reduced margins and delays and, as a result, our business, financial condition, results of operations and cash flows could be materially and adversely affected.

The conflict in Ukraine and related price volatility and geopolitical instability has negatively impacted and may continue to negatively impact our business.

In late February 2022, Russia launched significant military action against Ukraine. The conflict has caused, and could intensify, volatility in natural gas, oil and NGL prices, and the extent and duration of the military action, sanctions and resulting market disruptions could be significant and could potentially have a substantial negative impact on the global economy and/or our business for an unknown period of time. We believe that the increase in crude oil prices during the first three quarters of 2022 has partially been due to the impact of the conflict between Russia and Ukraine on the global commodity and financial markets, and in response to economic and trade sanctions that certain countries have imposed on Russia. Any such volatility and disruptions may also magnify the impact of other risks described herein and in our Annual Report on Form 10-K.

Worsening economic recessions and economic conditions and trends and downturns in the business cycles of the industries we serve and which provide services to impact our business and operating results.*

A significant portion of our customer base is comprised of companies in the chemical manufacturing and hydrocarbon recovery industries. The overall levels of demand for our products, refining operations, and future planned re-refined oil products are driven by fluctuations in levels of end-user demand, which depend in large part on general macroeconomic conditions in the U.S., as well as regional economic conditions and many economists are now forecasting the U.S. to enter into a recession in the next several months. For example, many of our principal consumers are themselves heavily dependent on general economic conditions, including the price of fuel and energy, availability of affordable credit and capital, employment levels, interest rates, consumer confidence and housing demand. These cyclical shifts in our customers’ businesses may result in fluctuations in demand, volumes, pricing and operating margins for our services and products.

In addition to our customers, the suppliers of our feedstock are also affected by downturns in the economy and adverse changes in the price of feedstock. For example, we previously experienced difficulty obtaining feedstock from our suppliers who, because of prior sharp downturns in the price of oil (used and otherwise) in 2015-16 saw their margins decrease substantially, which in some cases made it uneconomical for such suppliers to purchase feedstock from their suppliers and/or sell to us at the rates set forth in their contracts. Similarly, the economic slowdown and general market uncertainty caused by the COVID-19 coronavirus outbreak and the steps taken by local, state and federal governments to attempt to reduce the spread of, and effects of, such virus, significantly reduced the demand for, and price of oil (which reached all-time lows during 2020), but has more recently recovered to pre-pandemic levels, and concurrent therewith, the slowdown in the U.S. economy caused by stay-at-home and similar orders during 2020, reduced the amount of feedstock being produced and as a result, our ability to obtain feedstocks, and produce finished products. Future recessions, economic downturns or reduced demand for oil are expected to have a material adverse effect on our results of operations, cash flows, and as a result the value of our securities.

Legal, Environmental, Governmental and Regulatory Risks

We are subject to numerous environmental and other laws and regulations and, to the extent we are found to be in violation of any such laws and regulations, or agree that we violated such laws and regulations, our business could be materially and adversely affected.*

We are subject to extensive federal, state, and local laws and regulations relating to the protection of the environment which, among other things:

•regulate the collection, transportation, handling, processing and disposal of hazardous and non-hazardous wastes;

•impose liability on persons involved in generating, handling, processing, transporting or disposing hazardous materials;

•impose joint and several liability for remediation and clean-up of environmental contamination;

•require us to prepare and maintain certain plans and guidelines; and

•require financial assurance that funds will be available for the closure and post-closure care of sites where hazardous wastes are stored, processed or disposed.

The breadth and complexity of all of these laws and regulations impacting us make consistent compliance extremely difficult and often result in increased operating and compliance costs, including requiring the implementation of new programs to promote compliance. Even with these programs, we and other companies in the industry are routinely faced with legal and administrative proceedings which can result in civil and criminal penalties, interruption of business operations, fines or other sanctions and require expenditures.

Our operations involve the risks of fuel spillage or seepage, environmental damage and hazardous waste disposal, among others. If we are involved in a spill or other accident involving hazardous substances, or if we are found to be in violation of applicable environmental laws or regulations, it could significantly increase our cost of doing business.

Additionally, under current law, we may be held liable for damage caused by conditions that existed before we acquired our assets and/or before we took control of our leased properties or if we arranged for the transportation, disposal or treatment of hazardous substances that cause environmental contamination. In the future, we may be subject to monetary fines, civil or criminal penalties, remediation, clean-up or stop orders, injunctions, orders to cease or suspend certain practices or denial of permits required to operate our facilities and conduct our operations. The outcome of any proceeding and associated costs and expenses could have a material adverse impact on our operations and financial condition.

Our trucking operations are subject to a number of federal, state and local rules and regulations generally governing such activities as authorization to engage in motor carrier operations, safety compliance and reporting, contract compliance, insurance requirements, taxation and financial reporting. We could be subject to new or more restrictive regulations, such as regulations relating to engine emissions, drivers’ hours of service, occupational safety and health, ergonomics or cargo security. Compliance with such regulations could substantially reduce equipment productivity, and the costs of compliance could increase our operating expenses.

Environmental laws also govern the presence, maintenance and removal of asbestos-containing building materials, or ACBMs, and may impose fines and penalties for failure to comply with these requirements. Such laws require that owners or operators of buildings containing ACBM (and employers in such buildings) properly manage and maintain the asbestos, adequately notify or train those who may come into contact with asbestos, and undertake special precautions, including removal or other abatement, if asbestos would be disturbed during renovation or demolition of a building or plant. In addition, the presence of ACBM in our properties or plants may expose us to third-party liability (e.g., liability for personal injury associated with exposure to asbestos).

We may also be subject to claims from time to time that we have violated certain environmental laws and regulations. For example, during 2022, we entered into a Consent Agreement with the U.S. Environmental Protection Agency (EPA) to settle allegations that we failed to develop and implement an Spill Prevention Control & Countermeasure (SPCC) plan and/or a Facility Response Plan (FRP) for the Cedar Marine Terminal in violation of the Clean Water Act. Pursuant to the Consent Agreement, we agreed to pay $18,600 to the EPA as a penalty in connection therewith and to enter into a Final Order with the EPA. Environmental laws and regulations are subject to change and may become increasingly stringent or relaxed. Interpretation or enforcement of existing laws and regulations, or the adoption of new laws and regulations, may require us to modify or curtail our operations or replace or upgrade our facilities or equipment at substantial costs which we may not be able to pass on to our customers. On the other hand, if new laws and regulations are less stringent, then our customers or competitors may be able to compete with us more effectively, without reliance on our services, which could decrease the need for our services and/or increase competition which could adversely affect our revenues and profitability, if any. Our failure to comply with existing laws and regulations could result in penalties, fines, or injunctions, any of which could have a material adverse effect on our reputation, results of operations, or cash flows, and could further subject us to additional claims or litigation which may be material.

We are required to obtain and maintain permits, licenses and approvals to conduct our operations in compliance with such laws and regulations. If we are unable to maintain our currently held permits, licenses and approvals, we may not be able to continue certain of our operations. If we are unable to obtain any additional permits, licenses and approvals which may be required as we expand our operations, we may be forced to curtail or abandon our current and/or future planned business operations.

In addition, mandatory fuel standards have been adopted in many jurisdictions which can be costly to implement and maintain compliance. For example, the International Maritime Organization required, as of January 1, 2020, that ships must comply with new low sulfur fuel oil requirements (“IMO 2020”). Shipping companies were able to comply with this requirement by either using fuel with low sulfur content, which is more expensive than standard marine fuel, or by upgrading vessels to provide cleaner exhaust emissions, such as by installing “scrubbers” or retrofitting vessels to be powered by liquefied natural gas (“LNG”). The continued cost of compliance with these regulatory changes may be significant for shipping companies and it is uncertain how the availability and price of fuel globally will be affected by the implementation of the IMO 2020 regulations as refineries adjust their capacity to increase production of compliant fuels. These and future changes to applicable standards or other more stringent requirements in the industries we serve could reduce our ability to procure feedstocks, reduce our margins, increase our operational expenses, increase fuel prices, require us to incur additional handling costs and/or require the expenditure of capital. To the extent these expenditures, as with all costs, are not ultimately reflected in the prices of our products or we are unable to adequately source compliant fuels, our business and result of operations would be

adversely affected. Furthermore, IMO 2020 and/or other regulations may decrease demand for our products or force us to change the mix of products we offer. With the COVID-19 pandemic during 2020, it has been hard to see the real impact of IMO 2020 on our operations; however, so far, we are seeing strong demand for our finished products.

We may incur significant environmental remediation costs and liabilities in the operation of our refineries, facilities, terminals and related facilities.

The operation of our refineries, facilities, terminals, and related facilities subject us to the risk of incurring significant environmental remediation costs and liabilities due to our handling of petroleum hydrocarbons and other products, because of air emissions and water discharges related to our operations and activities, and as a result of historical operations and waste disposal practices at our facilities or in connection with our activities, some of which may have been conducted by prior owners or operators. We could incur significant remedial costs in the cleanup of any petroleum hydrocarbons or wastes or hazardous substances or wastes that may have been released on, under or from the properties owned or operated by us.

Some environmental laws may impose joint and several, strict liability for releases of petroleum hydrocarbons and wastes or hazardous substances or wastes, which means in some situations, we could be exposed to liability as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior operators or other third parties. Private parties, including the owners of properties adjacent to our operations and facilities where our petroleum hydrocarbons or wastes or hazardous substances or wastes are taken for reclamation or disposal, may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. We may not be able to recover some or any of these costs from insurance or other sources of indemnity. To the extent that the costs associated with meeting any or all of these requirements are significant and not adequately secured or indemnified for, there could be a material adverse effect on our business, financial condition and results of operations or cash flows and, as result, our ability to make payments of our debt obligations.

The nature of our operations exposes us, and the communities in which we work, to a wide range of health, safety, security and environment risks.

The health, safety, security and environment (HSSE) risks to which we and the communities in which we work are potentially exposed cover a wide spectrum, given the wide geographical area and diversity of our operations. These risks include the effects of natural disasters (including weather events), earthquakes, social unrest, pandemic diseases, criminal actions by external parties, and safety lapses. If a major risk materializes, such as an explosion or hydrocarbon leak or spill, this could result in injuries, loss of life, environmental harm, disruption of business activities, loss or suspension of permits, loss of our licenses to operate. Accordingly, this could have a material adverse effect on our earnings, cash flows and financial condition. Our operations are subject to extensive HSSE regulatory requirements that often change and are likely to become more stringent over time. We could incur significant extra costs in the future because of the need to comply with such requirements. We could also incur significant extra costs due to violations of or liabilities under laws and regulations that involve elements such as fines, penalties, clean-up costs and third-party claims. If HSSE risks materialize, they could have a material adverse effect on our earnings, cash flows and financial condition.

The availability and cost of renewable identification numbers could have an adverse effect on our financial condition and results of operations.

Pursuant to the Energy Policy Act of 2005, Congress established a Renewable Fuel Standard (“RFS”) program that requires annual volumes of renewable fuel be blended into domestic transportation fuel. A Renewable Identification Number (“RIN”) is assigned to each gallon of renewable fuel produced in, or imported into, the United States. We are exposed to the volatility in the market price of RINs. We cannot predict the future prices of RINs. RINs prices are dependent upon a variety of factors, including EPA regulations, the availability of RINs for purchase, and levels of transportation fuels produced, which can vary significantly from quarter to quarter. Additionally, the status of EPA RFS exemptions may impact the price of RINs. EPAs policy on granting certain RFS exemptions has changed under the Biden administration, and some previously granted exemptions have been the subject of legal proceedings that may ultimately result in the reversal of past exemptions. The occurrence of any one or more of these events may increase our operating expenses or make it more difficult for us to operate.

Risks Related to Our Securities

Our outstanding options and convertible securities may adversely affect the trading price of our common stock.*

As of the date of the filing, we had (i) outstanding stock options to purchase an aggregate of 3.6 million shares of common stock at a weighted average exercise price of $1.87 per share; (ii) outstanding warrants to purchase 2.6 million shares

of common stock at an exercise price of $4.50 per share and 0.2 million shares of common stock at an exercise price of $9.25 per share; and (iii) outstanding Convertible Senior Notes which may be converted into a maximum of 22.2 million shares of common stock, based on the initial maximum conversion rate of 233.6449 shares of the Company’s common stock per $1,000 principal amount of Notes, which is subject to customary and other adjustments described in the Indenture. For the life of the options and warrants, the holders have the opportunity to profit from a rise in the market price of our common stock without assuming the risk of ownership. The issuance of shares upon the exercise of outstanding securities will also dilute the ownership interests of our existing stockholders.

The availability of these shares for public resale, as well as any actual resales of these shares, could adversely affect the trading price of our common stock. We cannot predict the size of future issuances of our common stock pursuant to the exercise of outstanding options or warrants or conversion of other securities, or the effect, if any, that future issuances and sales of shares of our common stock may have on the market price of our common stock. Sales or distributions of substantial amounts of our common stock (including shares issued in connection with an acquisition), or the perception that such sales could occur, may cause the market price of our common stock to decline.

In addition, the common stock issuable upon exercise/conversion of outstanding convertible securities may represent overhang that may also adversely affect the market price of our common stock. Overhang occurs when there is a greater supply of a company’s stock in the market than there is demand for that stock. When this happens the price of our stock will decrease, and any additional shares which stockholders attempt to sell in the market will only further decrease the share price. If the share volume of our common stock cannot absorb shares sold by holders of our outstanding convertible securities, then the value of our common stock will likely decrease.

A significant number of our shares of common stock are eligible for sale and their sale or potential sale may depress the market price of our common stock.

Sales of a significant number of shares of our common stock in the public market could harm the market price of our common stock. Most of our common stock is available for resale in the public market, and if sold would increase the supply of our common stock, thereby causing a decrease in its price. Some or all of our shares of common stock may be offered from time to time in the open market pursuant to effective registration statements and/or compliance with Rule 144, which sales could have a depressive effect on the market for our shares of common stock. Subject to certain restrictions, a person who has held restricted shares for a period of six months may generally sell common stock into the market. The sale of a significant portion of such shares when such shares are eligible for public sale may cause the value of our common stock to decline in value.

The Warrants have certain anti-dilutive rights, put and call rights upon the occurrence of a fundamental transaction, and include a limitation on the number of shares of common stock which may be issued upon exercise thereof without shareholder approval.

A total of 2,584,900 of the Warrants have a term through April 1, 2027 and a $4.50 per share exercise price and a total of 235,000 of the Warrants have a term through November 26, 2027 and a $9.25 exercise price. All of the Warrants include weighted average anti-dilutive rights in the event any shares of common stock or other equity or equity equivalent securities payable in common stock are granted, issued or sold (or the Company enters into any agreement to grant, issue or sell), or in accordance with the terms of the Warrant Agreements, are deemed to have granted, issued or sold, in each case, at a price less than the exercise price, which automatically decreases the exercise price of the Warrants upon the occurrence of such event, as described in greater detail in the Warrant Agreements, and increases the number of shares of common stock issuable upon exercise of the Warrants, such that the aggregate exercise price of all Warrants remains the same before and after any such dilutive event. Such anti-dilution rights, if triggered, could result in a significant decrease in the exercise price of the Warrants combined with a significant increase in the number of shares of common stock issuable upon exercise thereof, which could result in significant dilution to existing shareholders.

Upon the occurrence of a fundamental transaction (as described in the Warrant Agreements) the Warrant Agreements (a) provide each holder a put right and (b) provide the Company with a call right in respect of the Warrants. Upon the exercise of a put right by the holder or a call right by the Company, the Company is obligated to repurchase the Warrants for the Black Scholes Value of the Warrants repurchased, as calculated in the Warrant Agreements. Such Black Scholes value may be significant and the requirement to pay such amount may prohibit us from completing a transaction which would otherwise be accretive to shareholders or make such transaction more costly.

Additionally, until or unless the Company receives shareholder approval under applicable Nasdaq listing rules for the issuance of more than 19.9% of the Company’s outstanding shares of common stock on the date the Warrant Agreements were

entered into (i.e., more than 12,828,681 shares of common stock)(the “Share Cap”), the Company may not issue more shares of common stock upon exercise of the Warrants than totals the Share Cap, and is required to pay the Lenders cash, based on the fair market value of any shares required to be issued upon exercise of the Warrants (as calculated in the Warrant Agreements), which would exceed the Share Cap. In the event the anti-dilutive rights of the Warrants result in more than 12,828,681 shares of common stock being issuable upon exercise of the Warrants, we could be required to pay cash to the holders of the Warrants in the amount equal to such excess shares, which could have a significant adverse effect on our available funds and liquidity.

The Warrants also include cashless exercise rights. As a result, we may not receive any cash upon the exercise of the Warrants.

We face significant penalties and damages in the event a registration statement registering the resale of the shares of common stock issuable upon exercise of the Warrants is not available for the sale of such shares.

In connection with the grant of the Warrants, the Company and the holders of such Warrants entered into a Registration Rights Agreement. Under the Registration Rights Agreement, the Company agreed to use commercially reasonable efforts to file a registration statement (the “Registration Statement”) with the SEC, for purposes of registering the resale of the shares of common stock issuable upon exercise of the Warrants no later than July 1, 2022. The Company also agreed to use commercially reasonable efforts to cause the SEC to declare the Registration Statement effective as soon as practicable and no later than 45 days following the filing of the Registration Statement; provided, that such date is extended until 75 days after the filing date if the Initial Registration Statement is reviewed by the staff of the Commission. The Registration Statement was filed with the SEC and became effective on July 8, 2022. The Registration Rights Agreement also provides the holders of the Warrants certain piggyback and demand registration rights (including pursuant to an underwritten offering, in the event the gross proceeds from such underwritten offering are expected to exceed $35 million).

If, subject to certain limited exceptions described in the Registration Rights Agreement, during the period commencing on the effective date of the Registration Statement and ending on the earlier of the date when there are no registrable securities or the third anniversary of the effective date of the Registration Statement, a registration statement is not continuously effective to allow the sale of the shares underlying the Warrants, for more than 10 consecutive calendar days or more than an aggregate of 15 calendar days (which need not be consecutive) during any 12-month period, then, in addition to any other rights such holder of Warrants may have under the Registration Rights Agreement or applicable law, (x) on the first such applicable default date, the Company is required to pay to such holder of a Warrant an amount in cash, as partial liquidated damages and not as a penalty, equal to 1.0% of the fair market value (such fair market value calculated as required under the Registration Rights Agreement) of the registrable securities held by such holder (the “1% Penalty”), and (y) on each monthly anniversary of such default date until all applicable defaults have been cured, shall pay the 1% Penalty, subject to a maximum penalty of 10% of the fair market value of the registrable securities held by each applicable holder of Warrants (such fair market value calculated as required under the Registration Rights Agreement).

The Company has agreed, among other things, to indemnify the holders of the Warrants and their affiliates with respect to certain liabilities and to pay all fees and expenses incident to the Company’s obligations under the Registration Rights Agreement.

In the event the Registration Statement is suspended or terminated, or we otherwise fail to meet certain requirements set forth in the Registration Rights Agreement, we could be required to pay significant penalties which could adversely affect our cash flow and cause the value of our securities to decline in value.

We have established preferred stock which can be designated by the Board of Directors without shareholder approval.*

We have 50 million shares of preferred stock authorized of which no shares are currently designated and no shares are issued and outstanding. Our directors, within the limitations and restrictions contained in our Articles of Incorporation and without further action by our shareholders, have the authority to issue shares of preferred stock from time to time in one or more series and to fix the number of shares and the relative rights, conversion rights, voting rights, and terms of redemption, liquidation preferences and any other preferences, special rights and qualifications of any such series. Any issuance of shares of preferred stock could adversely affect the rights of holders of our common stock. Should we issue additional shares of our common stock at a later time, each investor’s ownership interest in our stock would be proportionally reduced. Because our board of directors is entitled to designate the powers and preferences of the preferred stock without a vote of our shareholders, subject to Nasdaq rules and regulations, our shareholders will have no control over what designations and preferences our future preferred stock, if any, will have.

Item 2. Recent Sales of Unregistered Securities

There have been no sales of unregistered securities during the quarter ended September 30, 2022 and from the period from October 1, 2022, to the filing date of this report, which have not previously been disclosed in a Current Report on Form 8-K, except as set forth below:

In July 2022, warrants to purchase 100 shares of common stock with an exercise price of $4.50 per share were exercised by a holder thereof in consideration for $450 and we issued 100 shares of common stock.

In July 2022, warrants to purchase an aggregate of 165,000 shares of common stock with an exercise price of $4.50 per share were exercised by two holders thereof via cashless exercises, and were issued a net of an aggregate of 95,974 shares of common stock. Additionally, in July 2022, warrants to purchase an aggregate of 15,000 shares of common stock with an exercise price of $9.25 per share were exercised by a holder thereof in a cashless exercise, pursuant to which the holder was due a net of 2,101 shares of common stock in connection therewith, which shares have not been issued to date, or included in the number of issued and outstanding shares disclosed throughout this report.

The above exercises were exempt from registration pursuant to Section 4(a)(2) of the Securities Act because they did not involve a public offering.

Use of Proceeds from Sale of Registered Securities

None.

Purchases of Equity Securities by the Issuer and Affiliate Purchasers

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information.

None.

Item 6. Exhibits



Incorporated by Reference
Exhibit Number	Description of Exhibit	Filed or Furnished Herewith	Form	Exhibit	Filing Date/Period End Date	File No.

3.1	Certificate, Amendment or Withdrawal of Designation, relating to the Series A Convertible Preferred Stock, filed with the Secretary of State of Nevada on August 24, 2022		8-K	3.1	8/25/2022	001-11476
3.2	Certificate, Amendment or Withdrawal of Designation, relating to the Series B Preferred Stock, filed with the Secretary of State of Nevada on August 24, 2022		8-K	3.2	8/25/2022	001-11476
3.3	Certificate, Amendment or Withdrawal of Designation, relating to the Series B1 Preferred Stock, filed with the Secretary of State of Nevada on August 23, 2022		8-K	3.3	8/25/2022	001-11476
3.4	Certificate, Amendment or Withdrawal of Designation, relating to the Series C Convertible Preferred Stock, filed with the Secretary of State of Nevada on August 23, 2022		8-K	3.4	8/25/2022	001-11476
4.1	Indenture, dated as of November 1, 2021, by and between Vertex Energy, Inc. and U.S. Bank National Association, as Trustee.		8-K	4.1	11/2/2021	001-11476
4.2	Form of Global Note, representing Vertex Energy, Inc.’s 6.25% Convertible Senior Notes due 2027 (included as Exhibit A to the Indenture incorporated by reference as Exhibit 4.1).		8-K	4.2	11/2/2021	001-11476
4.3	Warrant Agreement dated April 1, 2022, by and among Vertex Energy, Inc. and Continental Stock Transfer & Trust Company, as warrant agent		8-K	4.1	4/7/2022	001-11476
4.4	Warrant Agreement dated May 26, 2022, by and among Vertex Energy Inc. and Continental Stock Transfer & Trust Company, as warrant agent		8-K	4.1	5/27/2022	001-11476
10.1#	Loan and Security Agreement dated April 1, 2022, by and among Vertex Refining Alabama LLC, as borrower, Vertex Energy, Inc., as parent and as a guarantor, certain direct and indirect subsidiaries of Vertex Energy, Inc., as guarantors, the lenders party thereto, and Cantor Fitzgerald Securities, as administrative agent and collateral agent for the lenders		8-K	10.1	4/7/2022	001-11476
10.2#	Amendment Number One to Loan and Security Agreement dated May 26, 2022, by and among Vertex Refining Alabama LLC, as borrower, Vertex Energy Inc., as parent and as a guarantor, certain direct and indirect subsidiaries of Vertex Energy Inc., as guarantors, the lenders party thereto, and Cantor Fitzgerald Securities, as administrative agent and collateral agent for the lenders		8-K	10.1	5/27/2022	001-11476
10.3#	Amendment Number Two to Loan and Security Agreement dated September 30, 2022, by and among Vertex Refining Alabama LLC, as borrower, Vertex Energy, Inc., as parent and as a guarantor, certain direct and indirect subsidiaries of Vertex Energy, Inc., as guarantors, the lenders party thereto, and Cantor Fitzgerald Securities, as administrative agent and collateral agent for the lenders		8-K	10.1	10/5/2022	001-11476

10.4

Guarantor Joinder dated September 30, 2022, relating to that certain Loan and Security Agreement dated April 1, 2022, as amended from time to time, by and among Vertex Refining Alabama LLC, as borrower, Vertex Energy, Inc., as parent and as a guarantor, certain direct and indirect subsidiaries of Vertex Energy, Inc., as guarantors, the lenders party thereto, and Cantor Fitzgerald Securities, as administrative agent and collateral agent for the lenders

8-K

10.2

10/5/2022

001-11476

31.1

Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act*

31.2

Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act*

32.1

Certification of Principal Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act**

32.2

Certification of Principal Accounting Officer Pursuant to Section 906 of the Sarbanes-Oxley Act**

101*

Inline XBRL Document Set for the condensed consolidated financial statements and accompanying notes in Part I, Item 1, “Financial Statements” of this Quarterly Report on Form 10-Q

101.INS*

Inline XBRL Instance Document- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH*

Inline XBRL Taxonomy Extension Schema Document

101.CAL*

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*

Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*

Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE*

Inline XBRL Taxonomy Extension Presentation Linkbase Document

104*

Inline XBRL for the cover page of this Quarterly Report on Form 10-Q, included in the Exhibit 101 Inline XBRL Document Set

* Filed herewith.

** Furnished herewith.

*** Indicates management contract or compensatory plan or arrangement.

# Certain schedules and exhibits have been omitted pursuant to Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule or exhibit will be furnished supplementally to the Securities and Exchange Commission upon request; provided, however that Vertex Energy, Inc. may request confidential treatment pursuant to Rule 24b-2 of the Securities Exchange Act of 1934, as amended, for any schedule or exhibit so furnished.

SIGNATURES

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, hereunto duly authorized.


			VERTEX ENERGY, INC.

Date: November 7, 2022			By: /s/ Benjamin P. Cowart
			Benjamin P. Cowart
			Chief Executive Officer
			(Principal Executive Officer)


Date: November 7, 2022			By: /s/ Chris Carlson
			Chris Carlson
			Chief Financial Officer
			(Principal Financial/Accounting Officer)

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Vertex Energy (VTNRQ) 10-Q2022 Q3 Quarterly report

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