UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal quarter ended ~~June~~September 30, 2020

☐ 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		(I.R.S. Employer Identification No.)
incorporation or organization)


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

1331 Gemini Street,, Suite 25077058

Houston,, Texas

(Address of principal executive offices) (Zip Code)

Registrant's telephone number, including area code: ~~866~~-~~660-8156~~866-660-8156

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 ý 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 ý 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

☐

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 ý

State the number of shares of the issuer’s common stock outstanding, as of the latest practicable date: 45,554,841 shares of common stock are issued and outstanding as of ~~August 10,~~November 9, 2020.

TABLE OF CONTENTS


					Page
			PART I
Item 1.			Financial Statements

			Consolidated Balance Sheets (unaudited)		F-1

			Consolidated Statements of Operations (unaudited)		F-3

			Consolidated Statements of Equity (unaudited)		F-4

				~~Page~~
	~~PART I~~
~~Item 1.~~	~~Financial Statements~~

	~~Consolidated Balance Sheets (unaudited)~~	~~F-1~~

	~~Consolidated Statements of Operations (unaudited)~~	~~F-3~~

	~~Consolidated Statements of Equity (unaudited)~~	~~F-4~~

	Consolidated Statements of Cash Flows (unaudited)	F-~~F-6~~6

			Notes to Consolidated Financial Statements (unaudited)		F-~~F-8~~8

Item 2			Management’s Discussion and Analysis of Financial Condition and Results of Operations		1

Item 3.			Quantitative and Qualitative Disclosures About Market Risk		2428

Item 4.			Controls and Procedures		2529


			PART II
Item 1.			Legal Proceedings		2630

Item 1A.			Risk Factors		2731

Item 2.			Unregistered Sales of Equity Securities and Use of Proceeds		3338

Item 3.			Defaults Upon Senior Securities		3338

Item 4.			Mine Safety Disclosures		3338

Item 5.			Other Information		3338

Item 6.			Exhibits		3539

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

VERTEX ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


	September 30, 2020		December 31, 2019
ASSETS
Current assets
Cash and cash equivalents	$	15,552,980	$	4,099,655
Restricted cash	100,125		100,170
Accounts receivable, net	9,090,927		12,138,078
Federal income tax receivable	0		68,606
Inventory	3,584,317		6,547,479

Prepaid expenses and other current assets	4,597,361		4,452,920
Total current assets	32,925,710		27,406,908

Noncurrent assets
Fixed assets, at cost	73,444,184		69,469,548
Less accumulated depreciation	(28,175,982)		(24,708,151)
Fixed assets, net	45,268,202		44,761,397
Finance lease right-of-use assets	1,640,694		851,570
Operating lease right-of use assets	34,014,076		35,586,885
Intangible assets, net	9,880,310		11,243,800
Deferred income taxes	0		68,605
Other assets	1,424,288		840,754

TOTAL ASSETS	$	125,153,280	$	120,759,919

F-1

June 30,
2020 December 31,
2019
ASSETS
Current assets
Cash and cash equivalents $ 17,754,312
$ 4,099,655
Restricted cash 100,125
100,170
Accounts receivable, net 9,163,208
12,138,078
Federal income tax receivable —
68,606
Inventory 3,812,752
6,547,479
Prepaid expenses and other current assets 2,499,104
4,452,920
Total current assets 33,329,501
27,406,908

Noncurrent assets

Fixed assets, at cost 70,977,927
69,469,548
Less accumulated depreciation (26,992,136 ) (24,708,151 )
Fixed assets, net 43,985,791
44,761,397
Finance lease right-of-use assets 1,613,661
851,570
Operating lease right-of use assets 34,739,105
35,586,885
Intangible assets, net 10,363,179
11,243,800
Deferred income taxes —
68,605
Other assets 1,219,301
840,754
TOTAL ASSETS $ 125,250,538
$ 120,759,919


	September 30, 2020		December 31, 2019
LIABILITIES, TEMPORARY EQUITY, AND EQUITY
Current liabilities
Accounts payable	$	8,275,862	$	7,620,098
Accrued expenses	3,312,018		5,016,132
Dividends payable	591,763		389,176
Finance lease liability-current	489,974		217,164
Operating lease liability-current	5,830,681		5,885,304
Current portion of long-term debt, net of unamortized finance costs	4,867,167		2,017,345
Derivative commodity liability	23,995		375,850
Revolving note	0		3,276,230

Total current liabilities	23,391,460		24,797,299
Long-term liabilities
Long-term debt, net of unamortized finance costs	8,297,605		12,433,000
Finance lease liability-long-term	1,072,623		610,450
Operating lease liability-long-term	28,183,395		29,701,581

Derivative warrant liability	124,847		1,969,216
Total liabilities	61,069,930		69,511,546

COMMITMENTS AND CONTINGENCIES (Note 3)	0		0

TEMPORARY EQUITY
Series B Convertible Preferred Stock, $0.001 par value per share; 10,000,000 shares designated, 4,002,619 and 3,826,055 shares issued and outstanding at September 30, 2020 and December 31, 2019, respectively with a liquidation preference of $12,408,119 and $11,860,771 at September 30, 2020 and December 31, 2019, respectively.	12,408,119		11,006,406

Series B1 Convertible Preferred Stock, $0.001 par value per share; 17,000,000 shares designated, 7,219,164 and 9,028,085 shares issued and outstanding at September 30, 2020 and December 31, 2019, respectively with a liquidation preference of $11,261,896 and $14,083,813 at September 30, 2020 and December 31, 2019, respectively.	10,567,161		12,743,047

Redeemable non-controlling interest	29,928,211		4,396,894
Total Temporary Equity	52,903,491		28,146,347
EQUITY
50,000,000 of total Preferred shares authorized:
Series A Convertible Preferred Stock, $0.001 par value; 5,000,000 shares designated, 419,859 shares issued and outstanding at September 30, 2020 and December 31, 2019, with a liquidation preference of $625,590 at September 30, 2020 and December 31, 2019.	420		420

Series C Convertible Preferred Stock, $0.001 par value; 44,000 shares designated, 0 shares issued or outstanding.	0		0

Common stock, $0.001 par value per share; 750,000,000 shares authorized; 45,554,841 and 43,395,563 shares issued and outstanding at September 30, 2020 and December 31, 2019, respectively.	45,555		43,396
Additional paid-in capital	94,404,520		81,527,351
Accumulated deficit	(84,323,362)		(59,246,514)
Total Vertex Energy, Inc. stockholders' equity	10,127,133		22,324,653
Non-controlling interest	1,052,726		777,373
Total Equity	11,179,859		23,102,026
TOTAL LIABILITIES, TEMPORARY EQUITY, AND EQUITY	$	125,153,280	$	120,759,919

June 30,
2020 December 31,
2019
LIABILITIES, TEMPORARY EQUITY, AND EQUITY

Current liabilities

Accounts payable $ 8,373,449
$ 7,620,098
Accrued expenses 2,950,439
5,016,132
Dividends payable 360,203
389,176
Finance lease liability-current 450,835
217,164
Operating lease liability-current 6,004,500
5,885,304
Current portion of long-term debt, net of unamortized finance costs 2,814,306
2,017,345
Derivative commodity liability 538,297
375,850
Revolving note —
3,276,230
Total current liabilities
21,492,029
24,797,299
Long-term liabilities

Long-term debt, net of unamortized finance costs 7,440,308
12,433,000
Finance lease liability-long-term 1,103,231
610,450
Operating lease liability-long-term 28,734,605
29,701,581
Derivative warrant liability 381,434
1,969,216
Total liabilities 59,151,607
69,511,546

COMMITMENTS AND CONTINGENCIES (Note 3) —
—

TEMPORARY EQUITY
Series B Convertible Preferred Stock, $0.001 par value per share;
10,000,000 shares designated, 3,941,704 and 3,826,055 shares issued and outstanding at June 30, 2020 and December 31, 2019, respectively with a liquidation preference of $12,219,282 and $11,860,771 at June 30, 2020 and December 31, 2019, respectively. 12,219,282
11,006,406

Series B1 Convertible Preferred Stock, $0.001 par value per share;
17,000,000 shares designated, 7,109,305 and 9,028,085 shares issued and outstanding at June 30, 2020 and December 31, 2019, respectively with a liquidation preference of $11,090,516 and $14,083,813 at June 30, 2020 and December 31, 2019, respectively. 10,366,624
12,743,047

Redeemable non-controlling interest 28,334,401
4,396,894
Total Temporary Equity 50,920,307
28,146,347
EQUITY

50,000,000 of total Preferred shares authorized:

Series A Convertible Preferred Stock, $0.001 par value;
5,000,000 shares designated, 419,859 shares issued and outstanding at June 30, 2020 and December 31, 2019, with a liquidation preference of $625,590 at June 30, 2020 and December 31, 2019. 420
420

Series C Convertible Preferred Stock, $0.001 par value;
44,000 shares designated, no shares issued or outstanding. —
—

Common stock, $0.001 par value per share;
750,000,000 shares authorized; 45,554,841 and 43,395,563 shares issued and outstanding at June 30, 2020 and December 31, 2019, respectively. 45,555
43,396
Additional paid-in capital 94,233,371
81,527,351
Accumulated deficit (79,979,484 ) (59,246,514 )
Total Vertex Energy, Inc. stockholders' equity 14,299,862
22,324,653
Non-controlling interest 878,762
777,373
Total Equity 15,178,624
23,102,026
TOTAL LIABILITIES, TEMPORARY EQUITY, AND EQUITY $ 125,250,538
$ 120,759,919

See accompanying notes to the consolidated financial ~~statements~~

statements.

F-2

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues	$	37,383,632	$	37,799,259	$	94,961,188	$	120,777,263
Cost of revenues (exclusive of depreciation and amortization shown separately below)	31,186,684		32,372,316		80,221,343		103,732,086
Depreciation and amortization attributable to costs of revenues	1,313,162		1,359,629		3,731,320		3,965,626
Gross profit	4,883,786		4,067,314		11,008,525		13,079,551

Operating expenses:
Selling, general and administrative expenses	6,241,570		6,153,184		18,972,648		17,529,784
Depreciation and amortization attributable to operating expenses	482,869		455,953		1,412,719		1,367,859


Total operating expenses	6,724,439		6,609,137		20,385,367		18,897,643

Loss from operations	(1,840,653)		(2,541,823)		(9,376,842)		(5,818,092)

Other income (expense):


Other income	1		918,153		101		920,071
Gain (loss) on sale of assets	(136,434)		0		(124,090)		31,443
Gain on change in value of derivative warrant liability	256,587		1,290,792		1,844,369		331,715

Interest expense	(234,671)		(826,005)		(796,930)		(2,322,780)
Total other income (expense)	(114,517)		1,382,940		923,450		(1,039,551)
Loss before income tax	(1,955,170)		(1,158,883)		(8,453,392)		(6,857,643)
Income tax benefit (expense)	0		0		0		0
Net loss	(1,955,170)		(1,158,883)		(8,453,392)		(6,857,643)
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest	480,215		(67,102)		190,771		(374,862)
Net loss attributable to Vertex Energy, Inc.	(2,435,385)		(1,091,781)		(8,644,163)		(6,482,781)

Accretion of redeemable noncontrolling interest to redemption value	(1,287,559)		(1,849,930)		(13,635,797)		(1,849,930)
Accretion of discount on Series B and B1 Preferred Stock	(29,157)		(550,774)		(1,500,395)		(1,644,374)
Dividends on Series B and B1 Preferred Stock	(591,777)		(419,096)		(1,296,493)		(1,238,766)
Net loss available to common shareholders	$	(4,343,878)	$	(3,911,581)	$	(25,076,848)	$	(11,215,851)
Loss per common share
Basic	$	(0.10)	$	(0.09)	$	(0.55)	$	(0.28)
Diluted	$	(0.10)	$	(0.09)	$	(0.55)	$	(0.28)
Shares used in computing earnings per share
Basic	45,554,841		41,376,335		45,494,235		40,626,700
Diluted	45,554,841		41,376,335		45,494,235		40,626,700

Three Months Ended June 30, Six Months Ended June 30,
2020 2019 2020 2019
Revenues $ 21,374,127
$ 43,657,292
$ 57,577,556
$ 82,978,004
Cost of revenues (exclusive of depreciation and amortization shown separately below) 22,197,805
36,515,421
49,034,659
71,359,770
Gross profit (loss) (823,678 ) 7,141,871
8,542,897
11,618,234

Operating expenses:
Selling, general and administrative expenses 6,030,560
6,028,859
12,731,078
11,376,600
Depreciation and amortization 1,713,461
1,780,890
3,348,008
3,517,903
Total operating expenses 7,744,021
7,809,749
16,079,086
14,894,503
Loss from operations (8,567,699 ) (667,878 ) (7,536,189 ) (3,276,269 )
Other income (expense):

Other income 20
1,918
100
1,918
Gain on sale of assets 12,344
29,150
12,344
31,443
Gain (loss) on change in value of derivative warrant liability (110,965 ) 746,017
1,587,782
(959,077 )
Interest expense (222,173 ) (738,972 ) (562,259 ) (1,496,775 )
Total other income (expense) (320,774 ) 38,113
1,037,967
(2,422,491 )
Loss before income tax (8,888,473 ) (629,765 ) (6,498,222 ) (5,698,760 )
Income tax benefit (expense) —
—
—
—
Net loss (8,888,473 ) (629,765 ) (6,498,222 ) (5,698,760 )
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest 109,165
(202,329 ) (289,444 ) (307,760 )
Net loss attributable to Vertex Energy, Inc. (8,997,638 ) (427,436 ) (6,208,778 ) (5,391,000 )

Accretion of redeemable noncontrolling interest to redemption value (1,381,889 ) —
(12,348,238 ) —
Accretion of discount on Series B and B1 Preferred Stock (539,235 ) (532,925 ) (1,471,238 ) (1,093,600 )
Dividends on Series B and B1 Preferred Stock (360,217 ) (412,875 ) (704,716 ) (819,670 )
Net loss available to common shareholders $ (11,278,979 ) $ (1,373,236 ) $ (20,732,970 ) $ (7,304,270 )
Loss per common share

Basic $ (0.25 ) $ (0.03 ) $ (0.46 ) $ (0.18 )
Diluted $ (0.25 ) $ (0.03 ) $ (0.46 ) $ (0.18 )
Shares used in computing earnings per share

Basic 45,554,841
40,294,870
45,463,600
40,245,671
Diluted 45,554,841
40,294,870
45,463,600
40,245,671

See accompanying notes to the consolidated financial ~~statements~~

statements.

F-3

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

FOR THE ~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2020 AND 2019

(UNAUDITED)


Nine Months Ended September 30, 2020
	Common Stock			Series A Preferred			Series C Preferred
	Shares	$0.001 Par		Shares	$0.001 Par		Shares	$0.001 Par		Additional Paid-In Capital		Retained Earnings		Non-controlling Interest		Total Equity
Balance on January 1, 2020	43,395,563	$	43,396	419,859	$	420	0	$	0	$	81,527,351	$	(59,246,514)	$	777,373	$	23,102,026
Purchase of shares of consolidated subsidiary	—	—		—	—		—	—		(71,171)		—		—		(71,171)

Adjustment of carrying mount of non-controlling interest	—	—		—	—		—	—		9,091,068		—		—		9,091,068
Share based compensation expense	—	—		—	—		—	—		163,269		—		—		163,269


Conversion of Series B1 Preferred stock to common	2,159,278	2,159		—	—		—	—		3,366,315		—		—		3,368,474
Dividends on Series B and B1	—	—		—	—		—	—		—		(344,499)		—		(344,499)
Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(932,003)		—		(932,003)
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—	—		—		(10,966,349)		—		(10,966,349)
Net income	—	—		—	—		—	—		—		2,788,860		119,268		2,908,128
Balance on March 31, 2020	45,554,841	$	45,555	419,859	$	420	0	$	0	$	94,076,832	$	(68,700,505)	$	896,641	$	26,318,943

Share based compensation expense	—	—		—	—		—	—		156,539		—		—		156,539
Dividends on Series B and B1	—	—		—	—		—	—		—		(360,217)		—		(360,217)
Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(539,235)		—		(539,235)
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—	—		—		(1,381,889)		—		(1,381,889)
Net loss	—	—		—	—		—	—		—		(8,997,638)		(17,879)		(9,015,517)
Balance on June 30, 2020	45,554,841	$	45,555	419,859	$	420	0	$	0	$	94,233,371	$	(79,979,484)	$	878,762	$	15,178,624

Share based compensation expense	—	—		—	—		—	—		171,149		—		—		171,149
Dividends on Series B and B1	—	—		—	—		—	—		—		(591,777)		—		(591,777)
Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(29,157)		—		(29,157)

Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—	—		—		(1,287,559)		—		(1,287,559)


Net loss	—	—		—	—		—	—		—		(2,435,385)		173,964		(2,261,421)
Balance on September 30, 2020	45,554,841	$	45,555	419,859	$	420	0	$	0	$	94,404,520	$	(84,323,362)	$	1,052,726	$	11,179,859

F-4


Nine Months Ended September 30, 2019																							Nine Months Ended September 30, 2019
																								Common Stock			Series A Preferred			Series C Preferred
																								Shares	$0.001 Par		Shares	$0.001 Par		Shares	$0.001 Par		Additional Paid-In Capital		Retained Earnings		Non-controlling Interest		Total Equity
Six Months Ended June 30, 2020
Balance on January 1, 2019																							Balance on January 1, 2019	40,174,821	$	40,175	419,859	$	420	0	$	0	$	75,131,122	$	(47,800,886)	$	1,438,213	$	28,809,044
	Common Stock			Series A Preferred			Series C Preferred
	Shares	$0.001 Par		Shares	$0.001 Par		Shares		$0.001 Par		Additional Paid-In Capital			Retained Earnings			Non-controlling Interest			Total Equity
Balance on January 1, 2020	43,395,563	$	43,396	419,859	$	420	—		$	—	$	81,527,351		$	(59,246,514	)	$	777,373		$	23,102,026
Purchase of shares of consolidated subsidiary	—	—		—	—		—		—		(71,171		)	—			—			(71,171		)
Adjustment of carrying mount of non-controlling interest	—	—		—	—		—		—		9,091,068			—			—			9,091,068

Share based compensation expense	—	—		—	—		—		—		163,269			—			—			163,269			Share based compensation expense	—	—		—	—		—	—		143,063		—		—		143,063

Conversion of Series B1 Preferred stock to common	2,159,278	2,159		—	—		—		—		3,366,315			—			—			3,368,474			Conversion of Series B1 Preferred stock to common	96,160	96		—	—		—	—		149,914		—		—		150,010
Dividends on Series B and B1	—	—		—	—		—		—		—			(344,499		)	—			(344,499		)	Dividends on Series B and B1	—	—		—	—		—	—		—		(406,795)		—		(406,795)
Accretion of discount on Series B and B1	—	—		—	—		—		—		—			(932,003		)	—			(932,003		)	Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(560,675)		—		(560,675)
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		—		—			(10,966,349		)	—			(10,966,349		)
Net income	—	—		—	—		—		—		—			2,788,860			119,268			2,908,128
Balance on March 31, 2020	45,554,841	$	45,555	419,859	$	420	$	—	$	—	$	94,076,832		$	(68,700,505	)	$	896,641		$	26,318,943
Net loss																							Net loss	—	—		—	—		—	—		—		(4,963,564)		(105,431)		(5,068,995)
Balance on March 31, 2019																							Balance on March 31, 2019	40,270,981	$	40,271	419,859	$	420	0	$	0	$	75,424,099	$	(53,731,920)	$	1,332,782	$	23,065,652
Exercise of options to purchase common stock																							Exercise of options to purchase common stock	75,925	76		—	—		—	—		4,424		—		—		4,500
Share based compensation expense	—	—		—	—		—		—		156,539			—			—			156,539			Share based compensation expense	—	—		—	—		—	—		171,002		—		—		171,002
Distribution to noncontrolling																							Distribution to noncontrolling	—	—		—	—		—	—		—		—		(285,534)		(285,534)

Dividends on Series B and B1	—	—		—	—		—		—		—			(360,217		)	—			(360,217		)	Dividends on Series B and B1	—	—		—	—		—	—		—		(412,875)		—		(412,875)
Accretion of discount on Series B and B1	—	—		—	—		—		—		—			(539,235		)	—			(539,235		)	Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(532,925)		—		(532,925)
Net income																							Net income	—	—		—	—		—	—		—		(427,436)		(202,329)		(629,765)
Balance on June 30, 2019																							Balance on June 30, 2019	40,346,906	$	40,347	419,859	$	420	0	$	0	$	75,599,525	$	(55,105,156)	$	844,919	$	21,380,055
Exercise of options to common																							Exercise of options to common	2,500	3		—	—		—	—		2,572		—		—		2,575
Share based compensation expense																							Share based compensation expense	—	—		—	—		—	—		159,426		—		—		159,426
Adjustment of carrying amount of non-controlling interest																							Adjustment of carrying amount of non-controlling interest	—	—		—	—		—	—		970,809		—		—		970,809
Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—		—		—			(1,381,889		)	—			(1,381,889		)	Accretion of redeemable non-controlling interest to redemption value	—	—		—	—		—	—		—		(1,849,930)		—		(1,849,930)
Net loss	—	—		—	—		—		—		—			(8,997,638		)	(17,879		)	(9,015,517		)
Balance on June 30, 2020	45,554,841	$	45,555	419,859	$	420	$	—	$	—	$	94,233,371		$	(79,979,484	)	$	878,762		$	15,178,624
Issuance of common stock and warrants																							Issuance of common stock and warrants	1,500,000	1,500		—	—		—	—		2,987,413		(772,202)		—		2,216,711
Dividends on Series B and B1																							Dividends on Series B and B1	—	—		—	—		—	—		—		(419,096)		—		(419,096)
Accretion of discount on Series B and B1																							Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(550,774)		—		(550,774)
Net income																							Net income	—	—		—	—		—	—		—		(1,091,781)		(37,981)		(1,129,762)
Balance on September 30, 2019																							Balance on September 30, 2019	41,849,406	$	41,850	419,859	$	420	0	$	0	$	79,719,745	$	(59,788,939)	$	806,938	$	20,780,014

Six Months Ended June 30, 2019
Common Stock Series A Preferred Series C Preferred
Shares $0.001 Par Shares $0.001 Par Shares $0.001 Par Additional Paid-In Capital Retained Earnings Non-controlling Interest Total Equity
Balance on January 1, 2019 40,174,821
$ 40,175
419,859
$ 420
—
$ —
$ 75,131,122
$ (47,800,886 ) $ 1,438,213
$ 28,809,044
Share based compensation expense —
—
—
—
—
—
143,063
—
—
143,063
Conversion of Series B1 Preferred stock to common 96,160
96
—
—
—
—
149,914
—
—
150,010
Dividends on Series B and B1 —
—
—
—
—
—
—
(406,795 ) —
(406,795 )
Accretion of discount on Series B and B1 —
—
—
—
—
—
—
(560,675 ) —
(560,675 )
Net loss —
—
—
—
—
—
—
(4,963,564 ) (105,431 ) (5,068,995 )
Balance on March 31, 2019 40,270,981
$ 40,271
419,859
$ 420
—
$ —
$ 75,424,099
$ (53,731,920 ) $ 1,332,782
$ 23,065,652
Exercise of options to common 75,925
76
—
—
—
—
4,424
—
—
4,500
Share based compensation expense —
—
—
—
—
—
171,002
—
—
171,002
Distribution to noncontrolling —
—
—
—
—
—
—
—
(285,534 ) (285,534 )
Dividends on Series B and B1 —
—
—
—
—
—
—
(412,875 ) —
(412,875 )
Accretion of discount on Series B and B1 —
—
—
—
—
—
—
(532,925 ) —
(532,925 )
Net income —
—
—
—
—
—
—
(427,436 ) (202,329 ) (629,765 )
Balance on June 30, 2019 40,346,906
$ 40,347
419,859
$ 420
—
$ —
$ 75,599,525
$ (55,105,156 ) $ 844,919
$ 21,380,055

See accompanying notes to the consolidated financial ~~statements~~

statements.

F-5

VERTEX ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2020 AND 2019 (UNAUDITED)


	Nine Months Ended
	September 30, 2020		September 30, 2019
Cash flows from operating activities
Net loss	$	(8,453,392)	$	(6,857,643)
Adjustments to reconcile net loss to cash provided by operating activities
Stock based compensation expense	490,957		473,491
Depreciation and amortization	5,144,039		5,333,485

Loss (gain) on sale of assets	124,090		(31,443)

Contingent consideration reduction	0		(15,564)
Bad debt and reduction in allowance for bad debt	34,127		(389,943)
(Decrease) increase in fair value of derivative warrant liability	(1,844,369)		(331,715)
(Gain) loss on commodity derivative contracts	(4,489,355)		2,691,833
Net cash settlements on commodity derivatives	5,484,734		(3,446,274)
Amortization of debt discount and deferred costs	47,826		430,431
Changes in operating assets and liabilities, net of effect of acquisition
Accounts receivable	4,952,388		(987,778)

Inventory	3,939,674		2,212,989
Prepaid expenses	(1,477,191)		(833,485)
Accounts payable	(367,327)		(1,046,149)
Accrued expenses	(1,788,693)		(260,341)
Other assets	(446,324)		0
Net cash provided by (used in) operating activities	1,351,184		(3,058,106)
Cash flows from investing activities
Acquisition	(1,822,690)		0

Internally developed software	(49,229)		(380,216)


Purchase of fixed assets	(4,170,166)		(2,907,330)



Proceeds from sale of fixed assets	36,465		86,846
Net cash used in investing activities	(6,005,620)		(3,200,700)
Cash flows from financing activities
Payments on finance leases	(282,655)		(113,241)
Proceeds from exercise of stock options	0		7,075
Distribution VRM LA	0		(285,534)
Contributions received from redeemable noncontrolling interest	21,000,000		3,150,000
Proceeds received from issuance of common stock and warrants	0		2,216,711
Line of credit (payments) proceeds, net	(3,276,230)		1,543,003

Proceeds from note payable (includes proceeds from PPP note)	7,992,346		2,809,139
Payments on note payable	(9,325,745)		(3,514,365)
Net cash provided by financing activities	16,107,716		5,812,788
Net change in cash, cash equivalents and restricted cash	11,453,280		(446,018)
Cash, cash equivalents, and restricted cash at beginning of the period	4,199,825		2,849,831
Cash, cash equivalents, and restricted cash at end of period	$	15,653,105	$	2,403,813

F-6

Six Months Ended
June 30,
2020 June 30,
2019
Cash flows from operating activities
Net loss $ (6,498,222 ) $ (5,698,760 )
  Adjustments to reconcile net loss to cash provided by operating activities

Stock based compensation expense 319,809
314,065
Depreciation and amortization 3,348,008
3,517,903
Gain on sale of assets (12,344 ) (31,443 )
Contingent consideration reduction —
(15,564 )
Bad debt and reduction in allowance for bad debt 65,443
(360,926 )
(Decrease) increase in fair value of derivative warrant liability (1,587,782 ) 959,077
     (Gain) loss on commodity derivative contracts (4,484,798 ) 1,069,778
     Net cash settlements on commodity derivatives 4,781,183
(967,708 )
     Amortization of debt discount and deferred costs 47,826
286,954
Changes in operating assets and liabilities
Accounts receivable 4,986,003
(2,111,591 )
Inventory 3,711,239
2,338,814
Prepaid expenses 1,834,361
1,948,771
Accounts payable (269,740 ) (518,050 )
Accrued expenses (2,150,272 ) (187,349 )
     Other assets (378,547 ) —
Net cash provided by operating activities 3,712,167
543,971
Cash flows from investing activities

Acquisition (1,822,690 ) —
Internally developed software (49,229 ) —
Purchase of fixed assets (1,526,379 ) (2,419,599 )
Proceeds from sale of fixed assets 22,844
86,846
Net cash used in investing activities (3,375,454 ) (2,332,753 )
Cash flows from financing activities

Payments on finance leases (162,312 ) (61,638 )
Proceeds from exercise of stock options —
4,500
Distribution VRM LA —
(285,534 )
Contributions received from redeemable noncontrolling interest 21,000,000
—
Line of credit (payments) proceeds, net (3,276,230 ) 1,235,251
Proceeds from note payable (includes proceeds from PPP note) 4,374,643
187,501
Payments on note payable (8,618,202 ) (1,542,903 )
Net cash provided by (used in) financing activities 13,317,899
(462,823 )
Net change in cash, cash equivalents and restricted cash 13,654,612
(2,251,605 )
Cash, cash equivalents, and restricted cash at beginning of the period 4,199,825
2,849,831
Cash, cash equivalents, and restricted cash at end of period $ 17,854,437
$ 598,226


SUPPLEMENTAL INFORMATION
Cash paid for interest	$	812,887	$	1,887,012
Cash paid for taxes	$	0	$	0
NON-CASH INVESTING AND FINANCING TRANSACTIONS


Conversion of Series B1 Preferred Stock into common stock	$	3,368,474	$	149,914
Accretion of discount on Series B and B1 Preferred Stock	$	1,500,395	$	1,644,374
Dividends-in-kind accrued on Series B and B1 Preferred Stock	$	1,296,493	$	1,238,766
Equipment acquired under finance leases	$	1,017,638	$	621,000
Initial adjustment of carrying amount redeemable noncontrolling interests	$	9,091,068	$	970,809
Accretion of redeemable noncontrolling interest to redemption value	$	13,635,797	$	1,849,930

SUPPLEMENTAL INFORMATION
Cash paid for interest $ 562,259
$ 1,221,363
Cash paid for taxes $ —
$ —
NON-CASH INVESTING AND FINANCING TRANSACTIONS
Conversion of Series B1 Preferred Stock into common stock $ 3,368,474
$ 150,010
Accretion of discount on Series B and B1 Preferred Stock $ 1,471,238
$ 1,093,600
Dividends-in-kind accrued on Series B and B1 Preferred Stock $ 704,716
$ 819,670
Equipment acquired under finance leases $ 888,764
$ 621,000
Initial adjustment of carrying amount redeemable noncontrolling interest $ 9,091,068
$ —
Accretion of redeemable noncontrolling interest to redemption value $ 12,348,238
$ —

See accompanying notes to the consolidated financial ~~statements~~

statements.

F-7

VERTEX ENERGY, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

~~JUNE~~SEPTEMBER 30, 2020

(UNAUDITED)

NOTE 1. BASIS OF PRESENTATION AND NATURE OF OPERATIONS

The accompanying unaudited consolidated interim financial statements of Vertex Energy, Inc. (the "Company" or "Vertex Energy") 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, 2019, contained in the Company's annual report, as filed with the SEC on Form 10-K on March 4, 2020 (the "Form 10-K"). The December 31, 2019 balance sheet was derived from the audited financial statements of our 2019 Form 10-K. 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. 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 2019 as reported in Form 10-K have been omitted.

Novel Coronavirus (COVID-19)

In December 2019, a novel strain of coronavirus, which causes the infectious disease known as COVID-19, was reported in Wuhan, China. The World Health Organization declared COVID-19 a “Public Health Emergency of International Concern” on January 30, 2020 and a global pandemic on March 11, 2020. In March and April, many U.S. states and local jurisdictions began issuing ‘stay-at-home’ orders, which continue in various forms as of the date of this report. Notwithstanding such ‘stay-at-home’ orders, to date, our operations have for the most part been deemed an essential business under applicable governmental orders based on the critical nature of the products we offer.

We sell products and services primarily in the U.S. domestic oil and gas commodity markets. Throughout the first quarter of 2020, the industry experienced multiple factors which lowered both the demand for, and prices of, oil and gas. First, the COVID-19 pandemic lowered global demand for hydrocarbons, as social distancing and travel restrictions were implemented across the world. Second, the lifting of Organization of the Petroleum Exporting Countries (OPEC)+ supply curtailments, and the associated increase in production of oil, drove the global supply of hydrocarbons higher through the first quarter of 2020. As a result of both dynamics, prices for hydrocarbons declined 67% from peak prices within the ~~quarter.~~first quarter of 2020. While global gross domestic product (GDP) growth was impacted by COVID-19 during the first ~~half~~nine months of 2020, we expect GDP to continue to decline globally in the ~~third and~~ fourth ~~quarters~~quarter of 2020 and for at least the early part of 2021, as a result of the COVID-19 pandemic. As a result, we expect oil and gas related markets will continue to experience significant volatility in 2020 and 2021. Our goal through this downturn has been to remain disciplined in allocating capital and to focus on liquidity and cash preservation. We are taking the necessary actions to right-size the business for expected activity levels.

As a result of the impact of the COVID-19 outbreak, some of our feedstock suppliers have permanently or temporarily closed their businesses, limited our access to their businesses, and/or have experienced a decreased demand for services. As a result of the above, and due to ‘stay-at-home’ and other social distancing orders, as well as the decline in U.S. travel caused by COVID-19, we have seen a significant decline in the ~~amount~~volume of feedstocks (specifically used oil) that we have been able to collect, and therefore process through our facilities. A prolonged economic slowdown, period of social quarantine (imposed by the government or otherwise), or a prolonged period of decreased travel due to COVID-19 or the responses thereto, will likely continue to have a material negative adverse impact on our ability to produce products, and consequently our revenues and results of operations.

The full extent of the impact of COVID-19 on our business and operations currently cannot be estimated and will depend on a number of factors including the scope and duration of the global pandemic.

Currently we believe that we have sufficient cash on hand and will generate sufficient cash through operations to support our operations for the foreseeable future; however, we will continue to evaluate our business operations based on new information as it becomes available and will make changes that we consider necessary in light of any new developments regarding the pandemic.

F-8

The pandemic is developing rapidly and the full extent to which COVID-19 will ultimately impact us depends on future developments, including the duration and spread of the virus, as well as potential seasonality of new ~~outbreaks.~~outbreaks, including, but not limited to the recent increase in infection rates, which may lead to further or extended stay-at-home and similar orders in the markets in which we operate.

NOTE 2. SUMMARY OF CRITICAL ACCOUNTING POLICIES AND ESTIMATES

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.

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.


	September 30, 2020 unaudited		September 30, 2019
Cash and cash equivalents	$	15,552,980	$	2,303,725
Restricted cash	100,125		100,088
Cash and cash equivalents and restricted cash as shown in the consolidated statements of cash flows	$	15,653,105	$	2,403,813

June 30, 2020 June 30, 2019
Cash and cash equivalents $ 17,754,312
$ 498,219
Restricted cash 100,125
100,007
Cash and cash equivalents and restricted cash as shown in the consolidated statements of cash flows $ 17,854,437
$ 598,226

The Company placed all the restricted cash in a money market account, to serve as collateral for payment of a credit card.

Inventory

Inventories of products consist of feedstocks, refined petroleum products and recovered ferrous and non-ferrous metals and are reported at the lower of cost or ~~market.~~net realizable value. Cost is determined using the first-in, first-out (“FIFO”) method. The Company reviews its inventory commodities for impairment whenever events or circumstances indicate that the value may not be recoverable.

Impairment of long-lived assets

The Company evaluates the carrying value and recoverability of its long-lived assets when circumstances warrant such evaluation by applying the provisions of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification ("ASC") regarding long-lived assets. It requires that long-lived assets be 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 0 long-lived asset impairment existed ~~at June~~during the nine months ended September 30, 2020. During the three months ended June 30, 2020, the Company considered the effects of COVID-19 and evolving changes in demand and pricing for oil, and prepared an impairment assessment. The Company concluded that the carrying amount of the long-lived assets are recoverable, and the Company will continue to evaluate the impact of macroeconomic conditions including, but not limited to, the impact of the COVID-19 pandemic on the Company, customers and the greater economy, as well as the impact on trends of oil demand.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP 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.

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.

Redeemable Noncontrolling Interests

F-9

Redemption", as applicable) to require MG SPV and Heartland SPV to redeem the non-controlling interest from the holder of such interest. Per the agreements, the cash purchase price for such redeemed Class B Units (MG SPV) and Class A Units (Heartland

SPV) is the greater of (y) the fair market value of such units (without discount for illiquidity, minority status or otherwise) as determined by a qualified third party agreed to in writing by a majority of the holders seeking an MG SPV Redemption and Heartland SPV Redemption and Vertex Operating, , LLC, our wholly-owned subsidiary (“Vertex Operating”) (provided that Vertex Operating still owns Class A Units (as to MG SPV) or Class B Units (as to Heartland SPV) on such date, as applicable) and (z) the original per-unit price for such Class B Units/Class A Units plus any unpaid Class A/Class B preference. The preference is defined as the greater of (A) the aggregate unpaid “Class B/Class A Yield” (equal to an annual return of 22.5% per annum) and (B) an amount equal to fifty percent (50%) of the aggregate capital invested by the Class B/Class A Unit holders. The agreements also permit the Company to acquire the non-controlling interest from the holders thereof upon certain events. 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 has classified the MG SPV and Heartland SPV non-controlling interests between the liabilities and equity sections of the accompanying ~~June~~September 30, 2020 and December 31, 2019 consolidated balance sheets (provided that the Heartland SPV interest was not outstanding until January 2020). 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 will 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 will become redeemable. The Company has 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 income in the consolidated financial statements. Rather, such adjustments are treated as equity transactions.

Variable Interest Entities

The Company accounts for the investments it makes in certain legal entities in which equity investors do not have (1) sufficient equity at risk for the legal entity to finance its activities without additional subordinated financial support, (2) as a group (the holders of the equity investment at risk), either the power, through voting or similar rights, to direct the activities of the legal entity that most significantly impacts the entity’s economic performance, or (3) the obligation to absorb the expected losses of the legal entity or the right to receive expected residual returns of the legal entity. These certain legal entities are referred to as “variable interest entities” or “VIEs.”

The Company consolidates the results of any such entity in which it determines that it has a controlling financial interest. The Company has a “controlling financial interest” in such an entity if the Company has both the power to direct the activities that most significantly affect the VIE’s economic performance and the obligation to absorb the losses of, or right to receive benefits from, the VIE that could be potentially significant to the VIE. On a quarterly basis, the Company reassesses whether it has a controlling financial interest in any investments it has in these certain legal entities.

NOTE 3. CONCENTRATIONS, SIGNIFICANT CUSTOMERS, COMMITMENTS AND CONTINGENCIES

At ~~June~~September 30, 2020 and 2019 and for each of the ~~six~~nine months then ended, the Company’s revenues and receivables were comprised of the following customer concentrations:


	Nine Months Ended September 30, 2020		Nine Months Ended September 30, 2019
	% of Revenues	% of Receivables	% of Revenues	% of Receivables
Customer 1	35%	11%	35%	25%
Customer 2	11%	13%	8%	15%
Customer 3	3%	11%	0%	0%
Customer 4	0%	0%	12%	0%

F-10

Six Months Ended June 30, 2020 Six Months Ended
June 30, 2019

% of
Revenues

% of
Receivables

% of
Revenues

% of
Receivables
Customer 1 38% 7% 31% 20%
Customer 2 12% 16% 7% 14%
Customer 3 3% —% 11% 8%
Customer 4 2% 2% 4% 10%
Customer 5 —% —% 17% —%

For each of the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, the Company's segment revenues were comprised of the following customer concentrations:


	% of Revenue by Segment			% Revenue by Segment
	Nine Months Ended September 30, 2020			Nine Months Ended September 30, 2019
	Black Oil	Refining	Recovery	Black Oil	Refining	Recovery
Customer 1	54%	0%	0%	41%	0%	0%
Customer 2	17%	0%	0%	10%	0%	0%
Customer 3	0%	0%	25%	0%	0%	0%
Customer 4	0%	0%	0%	14%	0%	0%

% of Revenue by Segment % Revenue by Segment
Six Months Ended June 30, 2020 Six Months Ended June 30, 2019
Black Oil Refining Recovery Black Oil Refining Recovery
Customer 1 53% —% —% 36% —% —%
Customer 2 17% —% —% 8% —% —%
Customer 3 4% —% —% 12% —% —%
Customer 4 2% —% —% 4% —% —%
Customer 5 —% —% —% 20% —% —%

The Company had one and no vendors that represented 10% of total purchases or payables for the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, respectively. The vendor represents 19% of total purchases for the nine months ended September 30, 2020 and 17% of accounts payable at September 30, 2020.

The Company’s revenue, profitability and future rate of growth are substantially dependent on prevailing prices for petroleum-based products. Historically, the energy markets have been very volatile, and there can be no assurance that these prices will not be subject to wide fluctuations in the future. A substantial or extended decline in such prices could have a material adverse effect on the Company’s financial position, results of operations, cash flows, access to capital, and the quantities of petroleum-based products that the Company can economically produce.

Throughout the first quarter of 2020, the industry experienced multiple issues which lowered both the demand for, and prices of, oil and gas. First, the COVID-19 pandemic lowered global demand for hydrocarbons, as social distancing and travel restrictions were implemented across the world. Second, the lifting of Organization of the Petroleum Exporting Countries (OPEC)+ supply curtailments, and the associated increase in production of oil, drove the global supply of hydrocarbons higher through the first quarter of 2020. As a result of both dynamics, prices for hydrocarbons declined 67% from peak prices within the quarter. While global gross domestic product (GDP) growth was impacted by COVID-19 during the first half of 2020, we expect GDP to decline globally in the third and fourth quarters of 2020 and continuing into 2021, as a result of the COVID-19 pandemic. As a result, we expect oil and gas related markets will continue to experience significant volatility in 2020. Our goal through this downturn is to remain disciplined in allocating capital and to focus on liquidity and cash preservation. We are taking the necessary actions to right-size the business for expected activity levels.

Litigation

The Company, in its normal course of business, is involved in various 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 5 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.

Related Parties

From time to time, the Company consults with a related party law firm. During the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, we paid ~~$30,061~~$56,971 and ~~$49,766,~~$62,239, respectively, to such law firm for services rendered.

F-11

NOTE 4. REVENUES

Disaggregation of Revenue

The following ~~table presents~~tables present our revenues disaggregated by geographical market and revenue source:


	Three Months Ended September 30, 2020
	Black Oil		Refining & Marketing		Recovery		Total
Primary Geographical Markets
Northern United States	$	7,484,798	$	0	$	0	$	7,484,798
Southern United States	12,503,324		13,501,749		3,893,761		29,898,834
	$	19,988,122	$	13,501,749	$	3,893,761	$	37,383,632
Sources of Revenue
Base oil	$	5,632,592	$	0	$	733,180	$	6,365,772
Pygas	0		1,184,433		0		1,184,433
Industrial fuel	21,190		82,644		0		103,834
Distillates	0		12,234,672		0		12,234,672
Oil collection services	2,449,454		0		0		2,449,454
Metals	0		0		3,160,581		3,160,581
Other re-refinery products	834,438		0		0		834,438
VGO/Marine fuel sales	11,050,448		0		0		11,050,448
Total revenues	$	19,988,122	$	13,501,749	$	3,893,761	$	37,383,632


	Three Months Ended June 30, 2020									Nine Months Ended September 30, 2020
	Black Oil		Refining & Marketing		Recovery		Total			Black Oil		Refining & Marketing		Recovery		Total
Primary Geographical Markets									Primary Geographical Markets
Northern United States	$	6,167,062	$	—	$	—	$	6,167,062	Northern United States	$	23,210,428	$	0	$	0	$	23,210,428
Southern United States	5,376,073		6,297,328		3,533,664		15,207,065		Southern United States	37,852,200		22,309,670		11,588,890		71,750,760
	$	11,543,135	$	6,297,328	$	3,533,664	$	21,374,127		$	61,062,628	$	22,309,670	$	11,588,890	$	94,961,188
Sources of Revenue									Sources of Revenue
Petroleum products	$	11,543,135	$	6,297,328	$	553,783	$	18,394,246
Base oil									Base oil	$	17,914,941	$	0	$	2,091,430	$	20,006,371
Pygas									Pygas	0		4,815,040		0		4,815,040
Industrial fuel									Industrial fuel	1,262,266		135,396		0		1,397,662
Distillates									Distillates	0		17,359,234		0		17,359,234
Oil collection services									Oil collection services	5,707,017		0		0		5,707,017
Metals	—		—		2,979,881		2,979,881		Metals	0		0		9,549,144		9,549,144
Other re-refinery products									Other re-refinery products	4,341,027		0		(51,684)		4,289,343
VGO/Marine fuel sales									VGO/Marine fuel sales	31,837,377		0		0		31,837,377
Total revenues	$	11,543,135	$	6,297,328	$	3,533,664	$	21,374,127	Total revenues	$	61,062,628	$	22,309,670	$	11,588,890	$	94,961,188

F-12


	Three Months Ended September 30, 2019
	Black Oil		Refining & Marketing		Recovery		Total
Primary Geographical Markets
Northern United States	$	12,325,941	$	0	$	0	$	12,325,941
Southern United States	20,004,590		3,076,454		2,392,274		25,473,318
	$	32,330,531	$	3,076,454	$	2,392,274	$	37,799,259
Sources of Revenue
Base oil	$	9,135,650	$	0	$	640,642	$	9,776,292
Pygas	0		2,741,557		0		2,741,557
Industrial fuel	891,676		334,897		0		1,226,573
Distillates	0		0		0		0
Oil collection services	1,953,924		0		0		1,953,924
Metals	0		0		1,724,025		1,724,025
Other re-refinery products	3,057,171		0		27,607		3,084,778
VGO/Marine fuel sales	17,292,110		0		0		17,292,110
Total revenues	$	32,330,531	$	3,076,454	$	2,392,274	$	37,799,259


	Nine Months Ended September 30, 2019
	Black Oil		Refining & Marketing		Recovery		Total
Primary Geographical Markets
Northern United States	$	31,530,289	$	0	$	0	$	31,530,289
Southern United States	71,523,240		9,212,477		8,511,257		89,246,974
	$	103,053,529	$	9,212,477	$	8,511,257	$	120,777,263
Sources of Revenue
Base oil	$	23,918,490	$	0	$	2,439,071	$	26,357,561
Pygas	0		7,656,125		0		7,656,125
Industrial fuel	5,714,478		1,501,655		0		7,216,133
Distillates	0		54,697		0		54,697
Oil collection services	4,261,391		0		0		4,261,391
Metals	0		0		5,988,895		5,988,895
Other re-refinery products	10,399,007		0		83,291		10,482,298
VGO/Marine fuel sales	58,760,163		0		0		58,760,163
Total revenues	$	103,053,529	$	9,212,477	$	8,511,257	$	120,777,263

Six Months Ended June 30, 2020
Black Oil Refining & Marketing Recovery Total
Primary Geographical Markets
Northern United States $ 15,725,631
$ —
$ —
$ 15,725,631
Southern United States 25,348,876
8,807,921
7,695,128
41,851,925
$ 41,074,507
$ 8,807,921
$ 7,695,128
$ 57,577,556
Sources of Revenue
Petroleum products $ 41,074,507
$ 8,807,921
$ 1,306,564
$ 51,188,992
Metals —
—
6,388,564
6,388,564
Total revenues $ 41,074,507
$ 8,807,921
$ 7,695,128
$ 57,577,556

Three Months Ended June 30, 2019
Black Oil Refining & Marketing Recovery Total
Primary Geographical Markets
Northern United States $ 9,880,565
$ —
$ —
$ 9,880,565
Southern United States 28,027,246
3,277,402
2,472,079
33,776,727
$ 37,907,811
$ 3,277,402
$ 2,472,079
$ 43,657,292
Sources of Revenue
Petroleum products $ 37,907,811
$ 3,277,402
$ 642,596
$ 41,827,809
Metals —
—
1,829,483
1,829,483
Total revenues $ 37,907,811
$ 3,277,402
$ 2,472,079
$ 43,657,292

Six Months Ended June 30, 2019
Black Oil Refining & Marketing Recovery Total
Primary Geographical Markets
Northern United States $ 19,204,348
$ —
$ —
$ 19,204,348
Southern United States 51,518,650
6,136,023
6,118,983
63,773,656
$ 70,722,998
$ 6,136,023
$ 6,118,983
$ 82,978,004
Sources of Revenue
Petroleum products $ 70,722,998
$ 6,136,023
$ 1,854,113
$ 78,713,134
Metals —
—
4,264,870
4,264,870
Total revenues $ 70,722,998
$ 6,136,023
$ 6,118,983
$ 82,978,004

~~Petroleum products- We derive a majority of our revenues from the sale of recovered/re-refined petroleum products, which include Base Oil, VGO (Vacuum Gas Oil), Pygas, Gasoline, Cutterstock and Fuel Oils.~~

~~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 metal items. These materials are segregated, processed, cut-up and sent back to a steel mill for re-purposing.

NOTE 5. ACCOUNTS RECEIVABLE

Accounts receivable, net, consists of the following at ~~June~~September 30, 2020 and December 31, 2019:


	September 30, 2020 Unaudited		December 31, 2019
Accounts receivable trade	$	9,441,141	$	12,540,553
Allowance for doubtful accounts	(350,214)		(402,475)
Accounts receivable trade, net	$	9,090,927	$	12,138,078

June 30, 2020 December 31, 2019
Accounts receivable trade $ 9,548,277
$ 12,540,553
Allowance for doubtful accounts (385,069 ) (402,475 )
Accounts receivable trade, net $ 9,163,208
$ 12,138,078

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 6. LINE OF CREDIT AND LONG-TERM DEBT

F-13

On April 24, 2020, (a) Encina Business Credit, LLC (“EBC”) and the lenders under our Revolving Credit Agreement with EBC (the “EBC Lenders”), and Vertex Operating, entered into a Fourth Amendment and Limited Waiver to Credit Agreement, effective on April 24, 2020, pursuant to which the EBC Lenders agreed to amend the EBC Credit Agreement; and (b) the EBC Lenders and Vertex Operating entered into a Fourth Amendment and Limited Waiver to ABL Credit Agreement, effective on April 24, 2020, pursuant to which the EBC Lenders agreed to amend the Revolving Credit Agreement (collectively, the “Waivers”). The Waivers amended the credit agreements to extend the due date of amounts owed thereunder from February 1, 2021 to February 1, 2022. ~~This was considered~~

On August 7, 2020, the Company and Vertex Operating entered into a ~~debt extinguishment per ASC 470-50; however, this results~~Fifth Amendment to Credit Agreement with EBC (the “Fifth Amendment”), which amended the EBC Credit Agreement to provide the Company up to a $2 million term loan to be used for capital expenditures (the “CapEx Loan”), which amounts may be requested from time to time by the Company, provided that not more than four advances of such amount may be requested, with each advance being not less than $500,000 (in multiples of $100,000). The amendment also provided that any prepayments of the EBC Credit Agreement would first be applied to the term loan and then to the CapEx Loan. The CapEx Loan bears interest at the rate of LIBOR (1.55% at September 30, 2020) plus 7%, or to the extent that LIBOR is not available, the highest of the prime rate and the Federal Funds Rate plus 0.50%, in ~~no gain~~each case, plus 6%. We are required to repay the CapEx Loan in monthly installments of 1/48th of the amount borrowed, each month that the CapEx Loan is outstanding, with a final balloon payment due at maturity. The obligation of EBC to fund the CapEx Loan is subject to customary conditions and requirements set forth in the Fifth Amendment, including the requirement that the Company has maintained daily availability under the ABL Credit Agreement greater than $1 million for the last thirty days, and that such availability would remain over $1 million, on a pro forma basis with such new loan. We are also required to provide the agent for the EBC Credit Agreement, a first priority security interest in the rolling stock collection assets or ~~loss recognition in earnings on~~other assets acquired with the ~~consolidated statements of operations at June 30, 2020.~~CapEx Loan.

Loan Agreements

On May 4, 2020, the Company applied for a loan from Texas Citizens Bank in the principal amount of ~~$4.222~~$4.22 million, pursuant to the Paycheck Protection Program (the “PPP”) under the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”), which was enacted on March 27, 2020. On May 5, 2020, the Company received the loan funds. The Note is unsecured, matures on April 28, 2022, and bears interest at a rate of 1.00% per annum, payable monthly commencing on ~~November 15, 2020,~~February 2021, following an initial deferral period as specified under the PPP. Under the terms of the PPP, the entire amount may be forgiven to the extent loan proceeds are used for qualifying expenses. As of the date of this report, the Company believes it has used the PPP funds for qualifying expenses.

On May 27, 2020, the Company entered into a loan contract security agreement with John Deere to finance $152,643 to purchase equipment. The Note matures on June 27, 2024, and bears interest at a rate of 2.45% per annum, payable monthly commencing on June 27, 2020. The payment of the note is secured by the equipment purchased.

Insurance Premiums

The Company financed insurance premiums through various financial institutions bearing interest rates from 4.00% to 4.90% per annum. All such premium finance agreements have maturities of less than one year and have a balance of $0$1,893,668 at ~~June~~September 30, 2020 and $1,165,172 at December 31, 2019.

Finance Leases

On April 2, 2020, the Company obtained 1 finance ~~lease. Payments are~~lease with payments of $9,322 per month for three years and on July 28, 2020, the ~~amount~~Company entered into another finance lease with payments of $3,545 per month for three years. The amount of the finance lease obligation has been reduced to ~~$313,272~~$410,928 at ~~June~~September 30, 2020.

On May 22, 2020, the Company ~~obtained~~entered into 1 finance lease. Payments are $15,078 per month for three years and the amount of the finance lease obligation has been reduced to ~~$520,191~~$485,745 at ~~June~~September 30, 2020.

The Company's outstanding debt facilities as of ~~June~~September 30, 2020 and December 31, 2019 are summarized as follows:

Creditor Loan Type Origination Date Maturity Date Loan Amount Balance on June 30, 2020 Balance on December 31, 2019
Encina Business Credit, LLC Term Loan February 1, 2017 February 1, 2022 $ 20,000,000
$ 5,883,000
$ 13,333,000
Encina Business Credit SPV, LLC Revolving Note February 1, 2017 February 1, 2022 $ 10,000,000
—
3,276,230
Wells Fargo Equipment Lease-Ohio Finance Lease April-May, 2019 April-May, 2024 $ 621,000
494,573
551,260
AVT Equipment Lease-Ohio Finance Lease April 2, 2020 April 2, 2023 $ 337,155
313,272
—
AVT Equipment Lease-HH Finance Lease May 22, 2020 May 22, 2023 $ 551,609
520,191
—
John Deere Note Note May 27, 2020 June 24, 2024 $ 152,643
149,613
—
Tetra Capital Lease Finance Lease May, 2018 May, 2022 $ 419,690
218,896
264,014
Well Fargo Equipment Lease-VRM LA Finance Lease March, 2018 March, 2021 $ 30,408
7,135
12,341
Texas Citizens Bank PPP Loan May 5, 2020 April 28, 2022 $ 4,222,000
4,222,000
—
Various institutions Insurance premiums financed Various < 1 year $ 2,902,428
—
1,165,172
Total 11,808,680
18,602,017
Deferred finance costs, net —
(47,826 )
Total, net of deferred finance costs $ 11,808,680
$ 18,554,191

F-14


Creditor	Loan Type	Origination Date	Maturity Date	Loan Amount		Balance on September 30, 2020		Balance on December 31, 2019
Encina Business Credit, LLC	Term Loan	February 1, 2017	February 1, 2022	$	20,000,000	$	5,658,000	$	13,333,000
Encina Business Credit SPV, LLC	Revolving Note	February 1, 2017	February 1, 2022	$	10,000,000	0		3,276,230
Encina Business Credit, LLC	Capex Loan	August 7, 2020	February 1, 2022	$	2,000,000	1,250,617		0
Wells Fargo Equipment Lease-Ohio	Finance Lease	April-May, 2019	April-May, 2024	$	621,000	465,678		551,260
AVT Equipment Lease-Ohio	Finance Lease	April 2, 2020	April 2, 2023	$	337,155	410,928		0
AVT Equipment Lease-HH	Finance Lease	May 22, 2020	May 22, 2023	$	551,609	485,745		0
John Deere Note	Note	May 27, 2020	June 24, 2024	$	152,643	140,487		0
Tetra Capital Lease	Finance Lease	May, 2018	May, 2022	$	419,690	195,761		264,014
Well Fargo Equipment Lease-VRM LA	Finance Lease	March, 2018	March, 2021	$	30,408	4,485		12,341
Texas Citizens Bank	PPP Loan	May 5, 2020	April 28, 2022	$	4,222,000	4,222,000		0
Various institutions	Insurance premiums financed	Various	< 1 year	$	2,902,428	1,893,668		1,165,172
Total						14,727,369		18,602,017
Deferred finance costs						0		(47,826)
Total, net of deferred finance costs						$	14,727,369	$	18,554,191

Future contractual maturities of notes payable as of ~~June~~September 30, 2020 are summarized as follows:


Creditor	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter
Encina Business Credit, LLC	$	900,000	$	4,758,000	$	0	$	0	$	0	$	0
Encina Business Credit SPV, LLC	0		0		0		0		0		0
Encina Business Credit, LLC	158,966		1,091,651		0		0		0		0
John Deere Note	37,071		37,991		38,934		26,491		0		0
Well Fargo Equipment Lease- Ohio	119,356		125,643		132,261		88,418		0		0
AVT Equipment Lease-Ohio	124,308		135,272��		151,348		0		0		0
AVT Equipment Lease-HH	145,296		158,111		182,338		0		0		0
Tetra Capital Lease	96,530		99,231		0		0		0		0
Well Fargo Equipment Lease- VRM LA	4,485		0		0		0		0		0
Texas Citizens Bank	1,877,461		2,344,539		0		0		0		0
Various institutions	1,893,668		0		0		0		0		0
Totals	$	5,357,141	$	8,750,438	$	504,881	$	114,909	$	0	$	0

Creditor Year 1 Year 2 Year 3 Year 4 Year 5 Thereafter
Encina Business Credit, LLC $ 900,000
$ 4,983,000
$ —
$ —
$ —
$ —
Encina Business Credit SPV, LLC —
—
—
—
—
—
John Deere Note 36,845
37,759
38,695
36,313
—
—
Well Fargo Equipment Lease- Ohio 117,834
124,039
130,574
122,127
—
—
AVT Equipment Lease-Ohio 88,689
96,512
128,071
—
—
—
AVT Equipment Lease-HH 142,258
154,805
223,128
—
—
—
Tetra Capital Lease 94,920
123,976
—
—
—
—
Well Fargo Equipment Lease- VRM LA 7,135
—
—
—
—
—
Texas Citizens Bank 1,877,461
2,344,539
—
—
—
—
Various institutions —
—
—
—
—
—
Totals $ 3,265,142
$ 7,864,630
$ 520,468
$ 158,440
$ —
$ —

F-15

NOTE 7. EARNINGS PER SHARE

Basic earnings per share includes no dilution and is computed by dividing income available to common shareholders by the weighted average number of common shares outstanding for the periods presented. Diluted earnings per share reflects the potential dilution of securities that could share in the earnings of an entity, such as convertible preferred stock, stock options, warrants or convertible securities. Due to their anti-dilutive effect, the calculation of diluted earnings per share for the three and ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 excludes: 1) options to purchase 5,104,288 and ~~3,878,632~~4,218,250 shares, respectively, of common stock, 2) warrants to purchase ~~8,633,188~~ 8,633,193 and ~~7,353,056~~8,853,056 shares, respectively, of common stock, 3) Series B Preferred Stock which is convertible ~~into 3,941,704~~into 4,002,619 and ~~3,713,794~~3,769,505 shares, respectively, of common stock, 4) Series B1 Preferred Stock which is convertible into ~~7,109,305 and 10,264,001~~7,219,164 and 10,417,966 shares, respectively, of common stock, and 5) Series A Preferred Stock which is convertible into 419,859 shares of common stock as of ~~June~~September 30, 2020 and 2019.

F-16

NOTE 8. COMMON STOCK

The total number of authorized shares of the Company’s common stock is 750,000,000 shares, $0.001 par value per share. As of ~~June~~September 30, 2020, there were 45,554,841 common shares issued and outstanding.

During the ~~six~~nine months ended ~~June~~September 30, 2020, the Company issued 2,159,278 ~~shares of common stock in connection with the conversions of Series B1 Convertible Preferred Stock into common stock of the Company, pursuant to the terms of such securities.~~

~~During the six months ended June 30, 2019, the Company issued 96,160~~ shares of common stock in connection with the conversion of Series B1 Convertible Preferred Stock into common stock of the Company, pursuant to the terms of such securities. ~~In addition,~~

During the nine months ended September 30, 2019, the Company issued ~~75,925~~1,596,160 shares of common stock in connection with the July 2019 Tensile Capital Partners Master Fund LP, an investment fund based in San Francisco, California (“Tensile”), Share Purchase and Subscription Agreement and conversions of Series B1 Convertible Preferred Stock into common stock of the Company, pursuant to the terms of such securities. In addition, during the nine months ended September 30, 2019, the Company issued 78,425 shares of common stock in connection with the exercise of options.

Stock Option Agreements

On June 19, 2020, the Board of Directors approved the grant to 3 employees and 1 officer/director (Benjamin P. Cowart, the Company’s Chief Executive Officer) of options to purchase an aggregate of 416,885 and 269,153 shares of common stock, respectively, at an exercise price of $0.78 and $0.86 per share, respectively, with a ten year and five year term, respectively (subject to continued employment/directorship), vesting at the rate of 1/4th of such options per year on the first four anniversaries of the grant, under our 2019 Stock Incentive Plan, as amended, in consideration for services rendered and to be rendered to the Company. The grant date fair value is $355,404 ~~and will amortize~~which amount is being amortized at the rate of $7,404 per month starting in ~~July.~~July 2020.

F-17

NOTE 9. 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 5,000,000 (“Series A Preferred”). The total number of designated shares of the Company’s Series B Convertible Preferred Stock is 10,000,000. The total number of designated shares of the Company’s Series B1 Convertible Preferred Stock is 17,000,000. As of ~~June~~September 30, 2020 and December 31, 2019, there were 419,859 shares of Series A Preferred Stock issued and outstanding. As of ~~June~~September 30, 2020 and December 31, 2019, there were ~~3,941,704~~4,002,619 and 3,826,055 shares of Series B Preferred Stock issued and outstanding, respectively. As of ~~June~~September 30, 2020 and December 31, 2019, there were ~~7,109,305~~7,219,164 and 9,028,085 shares of Series B1 Preferred Stock issued and outstanding, respectively.

Series B Preferred Stock and Temporary Equity

The following table represents the activity related to the Series B Preferred Stock, classified as Temporary Equity on the accompanying unaudited consolidated balance sheet, during the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019:










	2020		2019
Balance at beginning of period	$	11,006,406	$	8,900,208

Plus: discount accretion	854,364		1,031,483

Plus: dividends in kind	547,349		510,502

Balance at end of period	$	12,408,119	$	10,442,193

2020 2019
Balance at beginning of period $ 11,006,406
$ 8,900,208
Plus: discount accretion 854,364
666,048
Plus: dividends in kind 358,512
337,798
Balance at end of period $ 12,219,282
$ 9,904,054

The Series B Warrants and Series B1 Warrants were revalued at ~~June~~September 30, 2020 and December 31, 2019 using the Dynamic Black Scholes model that computes the impact of a possible change in control transaction upon the exercise of the warrant shares at approximately ~~$381,434~~$124,847 and $1,969,216, respectively. At ~~June~~September 30, 2020, the Series B Warrants and Series B1 Warrants were valued at approximately $0 and ~~$381,434,~~$124,847, respectively. The Dynamic Black Scholes Merton inputs used were: expected dividend rate of 0%, expected volatility of 66%-100%, risk free interest rate of ~~0.16%~~0.11% (Series B Warrants) and ~~0.16%~~0.13% (Series B1 Warrants), and expected term of ~~0.50~~0.25 years (Series B Warrants) and ~~1.50~~1.25 years (Series B1 Warrants). ~~The Series B Warrants expired at the end of June 30, 2020.~~

At ~~June~~September 30, 2020 and December 31, 2019, a total of ~~$188,837~~$310,220 and $177,921 of dividends were accrued on our outstanding Series B Preferred Stock, respectively. During the three months ended ~~June~~September 30, 2020 and 2019, we paid dividends in-kind in additional shares of Series B Preferred Stock of ~~$180,591~~$188,837 and ~~$167,642,~~$175,305, respectively. Because such preferred stock was not redeemed on June 24, 2020, the preferred stock accrues a 10% per annum dividend (payable in-kind at the option of the Company), until such preferred stock is redeemed or converted into common stock.

Series B1 Preferred Stock and Temporary Equity

The following table represents the activity related to the Series B1 Preferred Stock, classified as Temporary Equity on the accompanying unaudited consolidated balance sheet, for the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019:










	2020		2019
Balance at beginning of period	$	12,743,047	$	13,279,755
Less: conversions of shares to common	(3,368,474)		(119,768)
Plus: discount accretion	646,031		582,649
Plus: dividends in kind	546,557		712,185
Balance at end of period	$	10,567,161	$	14,454,821

2020 2019
Balance at beginning of period $ 12,743,047
$ 13,279,755
Less: conversions of shares to common (3,368,474 ) (119,768 )
Plus: discount accretion 616,874
472,000
Plus: dividends in kind 375,177
397,310
Balance at end of period $ 10,366,624
$ 14,029,297

As of ~~June~~September 30, 2020 and December 31, 2019, respectively, a total of ~~$171,380~~$281,557 and $211,269 of dividends were accrued on our outstanding Series B1 Preferred Stock. During the three months ended ~~June~~September 30, 2020 and 2019, we paid dividends in-kind in additional shares of Series B1 Preferred Stock of ~~$163,908~~$171,380 and ~~$235,360,~~$240,185, respectively.

The following is an analysis of changes in the derivative liability for the ~~six~~nine months ended June 30:

F-18


Level Three Roll-Forward
	2020		2019



Balance at beginning of period	$	1,969,216	$	1,481,692
Change in valuation of warrants	(1,844,369)		(331,715)
Balance at end of period	$	124,847	$	1,149,977

Level Three Roll-Forward
2020 2019
Balance at beginning of period $ 1,969,216
$ 1,481,692
Change in valuation of warrants (1,587,782 ) 959,077
Balance at end of period $ 381,434
$ 2,440,769

NOTE 10. SEGMENT REPORTING

The Company’s reportable segments include the (1) Black Oil, (2) Refining &and Marketing, and (3) Recovery ~~divisions.~~ segments.

(1) The Black Oil segment consists primary 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; and (e) the sale of VGO (vacuum gas oil)/marine fuel.

(2) The Refining and Marketing segment consists primarily of the sale of pygas; industrial fuels, which are produced at a third-party facility; and distillates

(3) 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.

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 ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 is as follows:

THREE MONTHS ENDED JUNE 30, 2020
Black Oil Refining &
Marketing Recovery Total
Revenues $ 11,543,135
$ 6,297,328
$ 3,533,664
$ 21,374,127

Loss from operations $ (6,504,341 ) $ (459,243 ) $ (1,604,115 ) $ (8,567,699 )

THREE MONTHS ENDED JUNE 30, 2019
Black Oil Refining &
Marketing Recovery Total
Revenues $ 37,907,811
$ 3,277,402
$ 2,472,079
$ 43,657,292

Income (loss) from operations $ 125,851
$ (132,408 ) $ (661,321 ) $ (667,878 )

SIX MONTHS ENDED JUNE 30, 2020
Black Oil Refining &
Marketing Recovery Total
Revenues $ 41,074,507
$ 8,807,921
$ 7,695,128
$ 57,577,556

Loss from operations $ (3,722,434 ) $ (1,343,257 ) $ (2,470,498 ) $ (7,536,189 )

SIX MONTHS ENDED JUNE 30, 2019
Black Oil Refining &
Marketing Recovery Total
Revenues $ 70,722,998
$ 6,136,023
$ 6,118,983
$ 82,978,004

Loss from operations $ (2,166,354 ) $ (535,422 ) $ (574,493 ) $ (3,276,269 )


THREE MONTHS ENDED SEPTEMBER 30, 2020
	Black Oil		Refining & Marketing		Recovery		Total
Revenues:
Base oil	$	5,632,592	$	0	$	733,180	$	6,365,772
Pygas	0		1,184,433		0		1,184,433
Industrial fuel	21,190		82,644		0		103,834
Distillates (1)	0		12,234,672		0		12,234,672
Oil collection services	2,449,454		0		0		2,449,454
Metals (2)	0		0		3,160,581		3,160,581
Other re-refinery products (3)	834,438		0		0		834,438
VGO/Marine fuel sales	11,050,448		0		0		11,050,448
Total revenues	19,988,122		13,501,749		3,893,761		37,383,632
Cost of revenues (exclusive of depreciation and amortization shown separately below)	14,687,141		13,217,757		3,281,786		31,186,684
Depreciation and amortization attributable to costs of revenues	1,041,719		121,744		149,699		1,313,162
Gross profit	4,259,262		162,248		462,276		4,883,786
Selling, general and administrative expenses	4,899,956		696,611		645,003		6,241,570
Depreciation and amortization attributable to operating expenses	390,105		72,314		20,450		482,869
Loss from operations	$	(1,030,799)	$	(606,677)	$	(203,177)	$	(1,840,653)

F-19


THREE MONTHS ENDED SEPTEMBER 30, 2019
	Black Oil		Refining & Marketing		Recovery		Total
Revenues:
Base oil	$	9,135,650	$	0	$	640,642	$	9,776,292
Pygas	0		2,741,557		0		2,741,557
Industrial fuel	891,676		334,897		0		1,226,573
Distillates (1)	0		0		0		0
Oil collection services	1,953,924		0		0		1,953,924
Metals (2)	0		0		1,724,025		1,724,025
Other re-refinery products (3)	3,057,171		0		27,607		3,084,778
VGO/Marine fuel sales	17,292,110		0		0		17,292,110
Total revenues	32,330,531		3,076,454		2,392,274		37,799,259
Cost of revenues (exclusive of depreciation and amortization shown separately below)	27,663,983		2,511,314		2,197,019		32,372,316
Depreciation and amortization attributable to costs of revenues	1,073,520		147,658		138,451		1,359,629
Gross profit	3,593,028		417,482		56,804		4,067,314
Selling, general and administrative expenses	5,040,772		494,781		617,631		6,153,184
Depreciation and amortization attributable to operating expenses	335,105		100,398		20,450		455,953
Loss from operations	$	(1,782,849)	$	(177,697)	$	(581,277)	$	(2,541,823)


NINE MONTHS ENDED SEPTEMBER 30, 2020
	Black Oil		Refining & Marketing		Recovery		Total
Revenues:
Base oil	$	17,914,941	$	0	$	2,091,430	$	20,006,371
Pygas	0		4,815,040		0		4,815,040
Industrial fuel	1,262,266		135,396		0		1,397,662
Distillates (1)	0		17,359,234		0		17,359,234
Oil collection services	5,707,017		0		0		5,707,017
Metals (2)	0		0		9,549,144		9,549,144
Other re-refinery products (3)	4,341,027		0		(51,684)		4,289,343
VGO/Marine fuel sales	31,837,377		0		0		31,837,377
Total revenues	61,062,628		22,309,670		11,588,890		94,961,188
Cost of revenues (exclusive of depreciation and amortization shown separately below)	46,601,716		21,772,587		11,847,040		80,221,343
Depreciation and amortization attributable to costs of revenues	2,960,699		341,498		429,123		3,731,320
Gross profit (loss)	11,500,213		195,585		(687,273)		11,008,525
Selling, general and administrative expenses	15,180,569		1,867,027		1,925,052		18,972,648
Depreciation and amortization attributable to operating expenses	1,072,877		278,492		61,350		1,412,719
Loss from operations	$	(4,753,233)	$	(1,949,934)	$	(2,673,675)	$	(9,376,842)

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NINE MONTHS ENDED SEPTEMBER 30, 2019
	Black Oil		Refining & Marketing		Recovery		Total
Revenues:
Base oil	$	23,918,490	$	0	$	2,439,071	$	26,357,561
Pygas	0		7,656,125		0		7,656,125
Industrial fuel	5,714,478		1,501,655		0		7,216,133
Distillates (1)	0		54,697		0		54,697
Oil collection services	4,261,391		0		0		4,261,391
Metals (2)	0		0		5,988,895		5,988,895
Other re-refinery products (3)	10,399,007		0		83,291		10,482,298
VGO/Marine fuel sales	58,760,163		0		0		58,760,163
Total revenues	103,053,529		9,212,477		8,511,257		120,777,263
Cost of revenues (exclusive of depreciation and amortization shown separately below)	88,374,446		7,767,882		7,589,758		103,732,086
Depreciation and amortization attributable to costs of revenues	3,122,664		431,948		411,014		3,965,626
Gross profit	11,556,419		1,012,647		510,485		13,079,551
Selling, general and administrative expenses	14,500,306		1,424,572		1,604,906		17,529,784
Depreciation and amortization attributable to operating expenses	1,005,315		301,194		61,350		1,367,859
Loss from operations	$	(3,949,202)	$	(713,119)	$	(1,155,771)	$	(5,818,092)

(1) Distillates are finished fuel products such as gasoline and diesel fuels.

(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 11. 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 ~~June~~September 30, 2020 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 ~~$57.3~~$55.2 million as of ~~June~~September 30, 2020 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 ~~$6.5~~$8.5 million from January 1, 2020 through ~~June~~September 30, 2020.

NOTE 12. 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 swap and futures arrangements for oil. In a commodity swap agreement, if the agreed-upon published third-party index price (“index price”) is lower than the swap fixed price, the Company receives the difference between the index price and the swap fixed price. If the index price is higher than the swap fixed price, the Company pays the difference. For 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 ~~June~~September 30, 2020 and December 31, 2019, are summarized in the following table. The notional amount is equal to the total net volumetric derivative position during the period indicated. The fair

F-21

value of the crude oil swap agreements is based on the difference between the strike price and the New York Mercantile Exchange futures price for the applicable trading months.


As of September 30, 2020
Contract Type	Contract Period	Weighted Average Strike Price (Barrels)		Remaining Volume (Barrels)	Fair Value

Swap	Sep. 2020- Oct. 2020	$	37.10	10,000	$	9,000
Swap	Sep. 2020- Oct. 2020	$	46.33	10,000	(28,896)
Futures	Sep. 2020- Dec. 2020	$	48.67	26,000	(4,099)
					$	(23,995)


As of December 31, 2019
Contract Type	Contract Period	Weighted Average Strike Price (Barrels)		Remaining Volume (Barrels)	Fair Value

Swap	Dec. 2019-Mar. 2020	$	40.88	130,000	$	539,800
Swap	Dec. 2019-Mar. 2020	$	81.19	130,000	(673,428)
Futures	Dec. 2019-Mar. 2020	$	84.53	105,000	(242,222)
					$	(375,850)

As of June 30, 2020
Contract Type Contract Period Weighted Average Strike Price (Barrels) Remaining Volume (Barrels) Fair Value

Futures Jun. 2020- Oct. 2020 $ 50.57
108,000
(538,297 )
$ (538,297 )

As of December 31, 2019
Contract Type Contract Period Weighted Average Strike Price (Barrels) Remaining Volume (Barrels) Fair Value

Swap Dec. 2019-Mar. 2020 $ 40.88
130,000
$ 539,800
Swap Dec. 2019-Mar. 2020 $ 81.19
130,000
(673,428 )
Futures Dec. 2019-Mar. 2020 $ 84.53
105,000
(242,222 )
$ (375,850 )

The carrying values of the Company's derivatives positions and their locations on the consolidated balance sheets as of ~~June~~September 30, 2020 and December 31, 2019 are presented in the table below.


Balance Sheet Classification	Contract Type	2020		2019

	Crude oil swaps	$	(19,896)	$	(133,628)
	Crude oil futures	(4,099)		(242,222)

Derivative commodity liability		$	(23,995)	$	(375,850)

Balance Sheet Classification Contract Type 2020 2019

Crude oil swaps $ —
$ (133,628 )
Crude oil futures (538,297 ) (242,222 )

Derivative commodity liability $ (538,297 ) $ (375,850 )

For the three months ended ~~June~~September 30, 2020 and 2019, we recognized a ~~$57,016~~$4,557 gain and a ~~$310,011~~$1,622,056 loss, respectively, on commodity derivative contracts on the consolidated statements of operations as part of our costs of revenues. For the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, we recognized a ~~$4,484,798~~$4,489,355 gain and a ~~$1,069,778~~$2,691,833 loss, respectively, on commodity derivative contracts on the consolidated statements of operations as part of our costs of revenues.

NOTE 13. LEASES

Finance Leases

Finance leases are included in finance lease right-of-use lease assets and finance lease liability current and long-term liabilities on the unaudited consolidated balance sheets. The associated amortization expenses for the three months ended ~~June~~September 30, 2020 and 2019 were ~~$73,552~~$101,841 and ~~$38,633,~~$53,121, respectively, and are included in depreciation and amortization on the unaudited consolidated statements of operations. The associated interest ~~expenses~~expense for the three months ended ~~June~~September 30, 2020 and 2019

F-22

were ~~$22,019~~ $33,077 and ~~$12,123,~~$12,436, respectively, and are included in interest expense on the unaudited consolidated statements of operations. The associated amortization ~~expenses~~expense for the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 were ~~$126,673~~$228,514 and ~~$60,704,~~$113,825, respectively, and are included in depreciation and amortization on the unaudited consolidated statements of operations. The associated interest ~~expenses~~expense for the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 were ~~$32,938~~ $66,014 and ~~$17,770,~~$30,206, respectively, and are included in interest expense on the unaudited consolidated statements of operations. Please see “Note 6. Line of Credit and Long-Term Debt” for more details.

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 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 ~~six~~nine months ended ~~June~~September 30, 2020 and 2019. Total operating lease costs for the three months ended ~~June~~September 30, 2020 and 2019 were $1.5 million and $1.6 million, respectively. Total operating lease costs, including some small leases with initial terms less than twelve months, for the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 were ~~$3.0~~$4.5 million and ~~$3.1~~$4.7 million, respectively.

Cash Flows

An initial right-of-use asset of $37.8 million was recognized as a non-cash asset addition with the adoption of the new lease accounting standard. Cash paid for amounts included in operating lease liabilities, including some small leases with initial terms less than twelve months was ~~$0.9 million and $1.0~~$1.6 million during the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, ~~respectively,~~ and is included in operating cash flows. Cash paid for amounts included in finance lease was ~~$162,312~~$282,655 and ~~$61,638~~$113,241 during the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019, respectively, and is included in financing cash flows.

Maturities of our lease liabilities for all operating leases are as follows as of ~~June~~September 30, 2020:


September 30, 2020
	Facilities		Equipment		Plant		Railcar		Total
Year 1	$	710,879	$	161,539	$	4,060,417	$	897,846	$	5,830,681
Year 2	446,869		67,338		4,060,417		229,656		4,804,280
Year 3	346,733		0		4,060,417		56,712		4,463,862
Year 4	300,000		0		4,060,417		0		4,360,417
Year 5	300,000		0		4,060,417		0		4,360,417
Thereafter	2,150,000		0		30,479,594		0		32,629,594
Total lease payments	$	4,254,481	$	228,877	$	50,781,679	$	1,184,214	$	56,449,251
Less: interest	(1,510,219)		(10,024)		(20,856,360)		(58,572)		(22,435,175)
Present value of lease liabilities	$	2,744,262	$	218,853	$	29,925,319	$	1,125,642	$	34,014,076

June 30, 2020
Facilities Equipment Plant Railcar Total
Year 1 $ 750,108
$ 161,539
$ 4,060,417
$ 1,032,436
$ 6,004,500
Year 2 496,361
107,723
4,060,417
328,416
4,992,917
Year 3 375,507
—
4,060,417
93,846
4,529,770
Year 4 300,000
—
4,060,417
—
4,360,417
Year 5 300,000
—
4,060,417
—
4,360,417
Thereafter 2,225,000
—
31,494,699
—
33,719,699
Total lease payments $ 4,446,976
$ 269,262
$ 51,796,784
$ 1,454,698
$ 57,967,720
Less: interest (1,573,677 ) (13,675 ) (21,557,397 ) (83,866 ) (23,228,615 )
Present value of lease liabilities $ 2,873,299
$ 255,587
$ 30,239,387
$ 1,370,832
$ 34,739,105

The weighted average remaining lease terms and discount rates for all of our operating leases were as follows as of ~~June~~September 30, 2020:

F-23



Remaining lease term and discount rate:	~~June~~September 30, 2020
Weighted average remaining lease terms (years)
Lease facilities	~~5.78~~		5.53
Lease equipment	~~1.67~~		1.42
Lease plant	~~12.76~~		12.51
Lease railcar	~~1.36~~		1.15
Weighted average discount rate
Lease facilities	~~9.15~~9.19	%
Lease equipment	8.00	%
Lease plant	9.37	%
Lease railcar	8.00	%

Significant Judgments

Significant judgments include the discount rates applied, the expected lease terms, lease renewal options and residual value guarantees. There are several leases with renewal options or purchase options. Using the practical expedient, the Company utilized existing lease classifications as of ~~June~~September 30, 2020 and 2019.

The purchase options are not expected to have a material impact on the lease obligation. There are several facility and plant leases which have lease renewal options from one to twenty years.

The largest facility lease has an initial term through 2032. That lease does not have an extension option. The 2 plant leases both have multiple 5-year extension options for a total of 20 years. NaN extension options have been included in the lease ~~right to use~~right-of-use asset and lease obligation at January 1, 2019.

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 14. SHARE PURCHASE AND SUBSCRIPTION AGREEMENTS

Myrtle Grove Share Purchase and Subscription Agreement

Amounts received by MG SPV from its direct sale of Class B Units to Tensile-MG may only be used for additional investments in the MG refinery or for day to day operations at the MG refinery. At ~~June~~September 30, 2020, ~~$2.2~~$2.0 million reported as cash and cash equivalents on the balance sheet is restricted to MG refinery investments or operating expenses.

The Class B Unit holders may force MG SPV to redeem the outstanding Class B Units at any time on or after the earlier of (a) the fifth anniversary of the Closing Date and (ii) the occurrence of a Triggering Event (defined below)(an “MG Redemption”). The

cash purchase price for such redeemed Class B Units is the greater of (y) the fair market value of such units (without discount for illiquidity, minority status or otherwise) as determined by a qualified third party agreed to in writing by a majority of the holders seeking an MG Redemption and Vertex Operating (provided that Vertex Operating still owns Class A Units on such date) and (z) the original per-unit price for such Class B Units plus any unpaid Class B preference. The preference is defined as the greater of (A) the aggregate unpaid “Class B Yield” (equal to an annual return of 22.5% per annum) and (B) an amount equal to fifty percent (50%) of the aggregate capital invested by the Class B Unit holders. The Company did not pay the preferential yield during the three and ~~six~~nine months ended ~~June~~September 30, 2020. “Triggering Events” mean (a) any dissolution, winding up or liquidation of the Company, Vertex Operating or any significant subsidiary of Vertex Operating, (b) any sale, lease, license or disposition of any material assets of the Company, Vertex Operating or any significant subsidiary of Vertex Operating, (c) any transaction or series of related transactions (whether by merger, exchange, contribution, recapitalization, consolidation, reorganization, combination or otherwise) involving the Company, Vertex Operating or any significant subsidiary of Vertex Operating, the result of which is that the holders of the voting securities of the relevant entity as of the Closing Date are no longer the beneficial owners, in the aggregate, after giving effect to such transaction or series of transactions, directly or indirectly, of more than fifty percent (50%) of the voting power of the outstanding voting securities of the entity, subject to certain other requirements set forth in the MG Company Agreement, (d) the failure to consummate the

F-24

Heartland Closing (defined below) by June 30, 2020 (a “Failure to Close”), provided that such Heartland Closing was consummated by June 30, 2020, (e) the failure of Vertex Operating to operate MG SPV in good faith with appropriate resources, or (f) the material failure of the Company and its affiliates to comply with the terms of the contribution agreement, whereby the Company contributed assets and operations to MG SPV. No triggering events occurred during the ~~six and~~nine months ended ~~June~~September 30, 2020.

Myrtle Grove Redeemable Noncontrolling Interest

As a result of the MG Share Purchase, Tensile, through Tensile-Myrtle Grove Acquisition Corporation, acquired an approximate 15.58% ownership interest in Vertex Refining Myrtle Grove LLC, a Delaware limited liability company, which entity was formed as a special purpose vehicle in connection with the transactions. This is considered a redeemable noncontrolling equity interest, as it is redeemable in the future and not solely within our control.

The initial carrying amount that is recognized in temporary equity for redeemable noncontrolling interests is the initial carrying amount determined in accordance with the accounting requirements for noncontrolling interests in ASC 810-10. In accordance with ASC 810-10-45-23, changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary are accounted for as equity transactions. Therefore, the Company recognized no gain or loss in consolidated net income and the carrying amount of the noncontrolling interest was adjusted to reflect the change in our ownership interest of the subsidiary. The difference of $970,809 between the fair value of the consideration received of $3,150,000 and the carrying amount of the noncontrolling interest determined in accordance with ASC 810-10 of $2,179,191, was recognized in additional paid in capital.

After initial recognition, 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 ~~subsidiaries~~subsidiary's net loss of ~~$82,401~~$120,031 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 adjustment of ~~$519,792~~$833,354 increased the carrying amount of redeemable noncontrolling interests to the redemption value as of ~~June~~September 30, 2020 of ~~$4,905,456.~~$5,181,388. 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 ~~June~~September 30, 2020.


	September 30, 2020
Beginning balance	$	4,396,894


Net loss attributable to redeemable non-controlling interest	(120,031)
Change in ownership	71,171
Accretion of non-controlling interest to redemption value	833,354
Ending balance	$	5,181,388

June 30, 2020
Beginning balance $ 4,396,894
Net loss attributable to redeemable non-controlling interest (82,401 )
Change in ownership 71,171
Accretion of non-controlling interest to redemption value 519,792
Ending balance $ 4,905,456

Heartland Share Purchase and Subscription Agreement

On January 17, 2020 (the “Heartland Closing Date”), Vertex Operating, Tensile-Heartland, and solely for the purposes of the Heartland Guaranty (defined below), the Company, and HPRM LLC, a Delaware limited liability company, which entity was formed as a special purpose vehicle in connection with the transactions, described in greater detail below (“Heartland SPV”), entered into a Share Purchase and Subscription Agreement (the “Heartland Share Purchase”).

Prior to entering into the Heartland Share Purchase, the Company transferred 100% of the ownership of Vertex Refining OH, LLC, its indirect wholly-owned subsidiary (“Vertex OH”) to Heartland SPV in consideration for 13,500 Class A Units, 13,500 Class A-1 Preferred Units and 11,300 Class B Units of Heartland SPV and immediately thereafter contributed 248 Class B

F-25

Units to the Company’s wholly-owned subsidiary, Vertex Splitter Corporation, a Delaware corporation (“Vertex Splitter”), as a contribution to capital.

Vertex OH owned the Company’s Columbus, Ohio, Heartland facility, which produces a base oil product that is sold to lubricant packagers and distributors.

Pursuant to the Heartland Share Purchase, Vertex Operating sold Tensile-Heartland the 13,500 Class A Units and 13,500 Class A-1 Preferred Units of Heartland SPV in consideration for $13.5 million. Also, on the Heartland Closing Date, Tensile-Heartland purchased 7,500 Class A Units and 7,500 Class A-1 Units in consideration for $7.5 million (less the expenses of Tensile-Heartland in connection with the transaction) directly from Heartland SPV.

The approximate $7.5 million purchase amount and future free cash flows from the operation of Heartland SPV are planned to be available for investments at the Heartland facility to increase self-collections, maximize the throughput of the refinery, enhance the quality of the output and complete other projects.

Concurrently with the closing of the transactions described above, and pursuant to the terms of the Heartland Share Purchase, the Company, through Vertex Operating, purchased 1,000 newly issued Class A Units from MG SPV at a cost of $1,000 per unit ($1 million in aggregate). As a result of this transaction, MG SPV is owned 85.00% by Vertex Operating and 15.00% by Tensile-MG.

The Heartland Share Purchase provides Tensile-Heartland an option, exercisable at its election, at any time, subject to the terms of the Heartland Share Purchase, to purchase up to an additional 7,000 Class A-2 Preferred Units at a cost of $1,000 per Class A-2 Preferred Unit from Heartland SPV.

The Heartland SPV is currently owned 35% by Vertex Operating and 65% by Tensile-Heartland. Heartland SPV is managed by a 5-member Board of Managers, of which 3 members are appointed by Tensile-Heartland and 2 are appointed by the Company. The Class A Units held by Tensile-Heartland are convertible into Class B Units as provided in the Limited Liability Company Agreement of Heartland SPV (the “Heartland Company Agreement”), based on a conversion price (initially 1-for-one) which may be reduced from time to time if new Units of Heartland SPV are issued and will automatically convert into Series AB Units upon certain events described in the Heartland Company Agreement.

The Class A-1 and A-2 Preferred Units (“Class A Preferred Units”), which are 100% owned by Tensile-Heartland, accrue a 22.5% per annum preferred return subject to terms of the Heartland Company Agreement (the “Class A Yield”).

Additionally, the Class A Unit holders (common and preferred) may force Heartland SPV to redeem the outstanding Class A Units at any time on or after the earlier of (a) the fifth anniversary of the Heartland Closing Date and (ii) the occurrence of a Heartland Triggering Event (defined below)(a “Heartland Redemption”). The cash purchase price for such redeemed Class A Unit will be

the greater of (y) the fair market value of such units (without discount for illiquidity, minority status or otherwise) as determined by a qualified third party agreed to in writing by a majority of the holders seeking Heartland Redemption and Vertex Operating (provided that Vertex Operating still owns Class B Units on such date) and (z) the original per-unit price for such Class A Units plus fifty percent (50%) of the aggregate capital invested by the Class A Unit holders through such Heartland Redemption date. “Heartland Triggering Events” include (a) any termination of an Administrative Services Agreement entered into with Tensile, pursuant to its terms and/or any material breach by us of the environmental remediation and indemnity agreement entered into with Tensile, (b) any dissolution, winding up or liquidation of the Company, Vertex Operating or any significant subsidiary of Vertex Operating, (c) any sale, lease, license or disposition of any material assets of the Company, Vertex Operating or any significant subsidiary of Vertex Operating, or (d) any transaction or series of related transactions (whether by merger, exchange, contribution, recapitalization, consolidation, reorganization, combination or otherwise) involving the Company, Vertex Operating or any significant subsidiary of Vertex Operating, the result of which is that the holders of the voting securities of the relevant entity as of the Heartland Closing Date are no longer the beneficial owners, in the aggregate, after giving effect to such transaction or series of transactions, directly or indirectly, of more than fifty percent (50%) of the voting power of the outstanding voting securities of the entity, subject to certain other requirements set forth in the Heartland Company Agreement.

In the event that Heartland SPV fails to redeem such Class A Units within 180 days after a redemption is triggered, the Class A Yield is increased to 25% until such time as such redemption is completed (with such increase being effective back to the original date of a notice of redemption). In addition, in such event, the Class A Unit holders may cause Heartland SPV to initiate a process intended to result in a sale of Heartland SPV.

F-26

Distributions of available cash of Heartland SPV pursuant to the Heartland Company Agreement (including pursuant to liquidations of Heartland SPV), subject to certain exceptions set forth therein, are to be made (a) first, to the holders of the Class A Preferred Units, in amount equal to the greater of (A) the aggregate unpaid Class A Yield and (B) an amount equal to fifty percent (50%) of the aggregate capital invested by the Class A Preferred Unit holders (initially Tensile-Heartland)(such aggregate capital invested by the Class A Preferred Unit holders, the “Heartland Invested Capital”, which totaled approximately $21 million as of the Heartland Closing Date, subject to adjustment as provided in the Heartland Share Purchase), less prior distributions (such greater amount of (A) and (B), the “Class A Preferred Priority Distributions”); (b) second, the Class A Preferred Unit holders, together as a separate and distinct class, are entitled to receive an amount equal to the aggregate Heartland Invested Capital; (c) third, the Class B Unitholders (other than Class B Unitholders which received Class B Units upon conversion of Class A Preferred Units), together as a separate and distinct class, are entitled to receive all or a portion of any distribution equal to the sum of all distributions made under sections (a) and (b) above; and (d) fourth, to the holders of Units who are eligible to receive such distributions in proportion to the number of Units held by such holders.

Heartland Variable interest entity

The Company has assessed the Heartland SPV under the variable interest guidance in ASC 810. The Company determined that the Class A Units are not at risk due to a 22.5% preferred return and a redemption provision that, if elected, would require Heartland SPV to repurchase the Class A Units at their original cost plus the preferred return. The Company further determined that as a minority shareholder, holding only 35% of the voting rights, the Company does not have the ability to direct the activities of Heartland SPV that most significantly impact the entity’s performance. Based on this assessment, the Company concluded that Heartland SPV is a variable interest entity.

In assessing if the Company is the primary beneficiary of Heartland SPV, the Company determined that certain provisions of the Heartland Company Agreement prohibiting the transfer of its Class B Units result in the Class A Unit holders being related parties under the de facto agents criteria in ASC 810. The Company and the Class A Unit holders, as a group, have the power to direct the significant activities of Heartland SPV and the obligations to absorb the losses and the right to receive the benefits that could potentially be significant to Heartland SPV. The Company concluded that substantially all of the activities of Heartland SPV are conducted on its behalf, and not on behalf of the Class A Unit holders, the decision maker, thus the Company is the primary beneficiary and required to consolidate Heartland SPV in accordance with ASC 810.

The Company's consolidated financial statements include the assets, liabilities and results of operations of Heartland SPV for which the Company is the primary beneficiary. The other equity holders’ interests are reflected in net loss attributable to noncontrolling interests and redeemable noncontrolling interest in the consolidated statements of income and noncontrolling interests in the consolidated balance sheets.

The following table summarizes the carrying amounts of Heartland SPV's assets and liabilities included in the Company’s consolidated balance sheets at ~~June~~September 30, 2020:

June 30, 2020
Cash and cash equivalents $ 8,407,926
Accounts receivable, net 3,031,746
Inventory 457,119
Prepaid expense and other current assets 439,702
Total current assets 12,336,493

Fixed assets, net 5,719,408
Finance lease right-of-use assets 1,050,973
Operating lease right-of-use assets 437,716
Intangible assets, net 1,190,080
Other assets 108,643
Total assets $ 20,843,313

Accounts payable $ 1,247,601
Accrued expenses 288,694
Finance lease liability-current 301,443
Operating lease liability-current 285,837
Total current liabilities 2,123,575

Finance lease liability-long term 725,298
Operating lease liability-long term 151,879
Total liabilities $ 3,000,752
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	September 30, 2020
Cash and cash equivalents	$	8,072,347
Accounts receivable, net	2,879,431
Inventory	310,596
Prepaid expense and other current assets	1,968,335
Total current assets	13,230,709

Fixed assets, net	5,619,248
Finance lease right-of-use assets	1,106,671
Operating lease right-of-use assets	369,333
Intangible assets, net	1,127,352
Other assets	108,643
Total assets	$	21,561,956

Accounts payable	$	1,413,378
Accrued expenses	335,267
Finance lease liability-current	340,193
Operating lease liability-current	268,437
Total current liabilities	2,357,275

Finance lease liability-long term	732,174
Operating lease liability-long term	100,896
Total liabilities	$	3,190,345

The assets of Heartland SPV may only be used to settle the obligations of Heartland SPV, and may not be used for other consolidated entities. The liabilities of Heartland SPV are non-recourse to the general credit of the Company’s other consolidated entities.

Heartland Redeemable Noncontrolling Interest

As a result of the Heartland Share Purchase (as defined and discussed above), Tensile Capital Partners Master Fund LP, an investment fund based in San Francisco, California (“Tensile”), through Tensile-Heartland, acquired an approximate 65.00% ownership interest in Heartland SPV, a Delaware limited liability company, which entity was formed as a special purpose vehicle in connection with the transactions. This is considered a redeemable noncontrolling equity interest, as it is redeemable in the future and not solely within our control.

The initial carrying amount that is recognized in temporary equity for redeemable noncontrolling interests is the initial carrying amount determined in accordance with the accounting requirements for noncontrolling interests in ASC 810-10. In accordance with ASC 810-10-45-23, changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary are accounted for as equity transactions. Therefore, the Company recognized no gain or loss in consolidated net income and the carrying amount of the noncontrolling interest was adjusted to reflect the change in our ownership interest of the subsidiary. The difference of $9,091,068 between the fair value of the consideration received of $21,000,000 and the carrying amount of the noncontrolling interest determined in accordance with ASC 810-10 of $11,908,932, was recognized in additional paid in capital.

After initial recognition, 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 ~~subsidiaries~~subsidiary's net ~~loss~~gain of ~~$308,432~~$35,449 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 adjustment of ~~$11,828,445~~$12,802,442 increased the carrying amount of redeemable noncontrolling interests to the redemption value as of ~~June~~

F-28

September 30, 2020 of ~~$23,428,945.~~$24,746,823. 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 Heartland SPV as of ~~June~~September 30, 2020.


	September 30, 2020
Beginning balance	$	0

Initial adjustment of carrying amount of non-controlling interest	11,908,932
Net gain attributable to redeemable non-controlling interest	35,449
Accretion of non-controlling interest to redemption value	12,802,442
Ending balance	$	24,746,823

June 30, 2020
Beginning balance $ —
Initial adjustment of carrying amount of non-controlling interest 11,908,932
Net loss attributable to redeemable non-controlling interest (308,432 )
Accretion of non-controlling interest to redemption value 11,828,445
Ending balance $ 23,428,945

The amounts of accretion of redeemable noncontrolling interest to redemption value of ~~$1,381,889~~$1,287,559 and ~~$12,348,238~~$13,635,797 presented as an adjustment to net loss attributable to Vertex Energy, Inc., to arrive at net loss available to common shareholders on the consolidated statements of operations represent the MG SPV and Heartland SPV accretion of redeemable noncontrolling interest to redemption value combined for the three and ~~six~~nine months ended ~~June~~September 30, 2020, respectively.

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NOTE 15. ACQUISITION

Crystal Energy, LLC

On June 1, 2020, the Company entered into and closed a Member Interest Purchase Agreement with Crystal Energy, LLC ("Crystal") pursuant to which the Company agreed to buy all of the outstanding membership ~~interest~~interests of Crystal for aggregate cash consideration of $1,822,690. This resulted in the recognition of $1,939,364 in accounts receivable, $976,512 in inventory, $14,484 in other current assets, and $1,107,670 in current liabilities. Upon the closing of the acquisition, Crystal became a wholly-owned subsidiary of the Company. The acquisition was accounted for as a business combination.

Crystal is an Alabama limited liability company that was organized on September 7, 2016, for the purpose of purchasing, storing, selling, and distributing refined motor fuels. These activities include the wholesale distribution of gasoline, blended gasoline, and diesel for use as engine fuel to operate automobiles, trucks, locomotives, and construction equipment. Crystal markets its products to third-party customers, and customers will typically resell these products to retailers, end use consumers, and others. These assets are used in our Refining division.

NOTE 16. SUBSEQUENT EVENTS

Issuance of Series B and B1 Preferred Stock Shares In-Kind and Common Stock

We paid the accrued dividends on our Series B Preferred Stock and Series B1 Preferred Stock, which were accrued as of ~~June~~September 30, 2020, in-kind by way of the issuance of ~~60,915~~100,071 restricted shares of Series B Preferred Stock pro rata to each of the then holders of our Series B Preferred Stock in ~~July~~October 2020 and the issuance of ~~109,859~~180,485 restricted shares of Series B1 Preferred Stock pro rata to each of the then holders of our Series B1 Preferred Stock in ~~July~~October 2020. If converted in full, the ~~60,915~~100,071 shares of Series B Preferred Stock would convert into ~~60,915~~100,071 shares of common stock and the ~~109,859~~180,485 shares of Series B1 Preferred Stock would convert into ~~109,859~~180,485 shares of common stock.

~~Fifth Amendment to EBC Credit Agreement~~Marrero Refinery Fire

On ~~August~~October 7, 2020, we had a fire at our Marrero refinery which took the ~~Company~~facility offline for repairs for about two weeks. The refinery suffered some minor structural damage along with piping, valves and ~~Vertex Operating entered into a Fifth Amendment to Credit Agreement with EBC (the “Fifth Amendment”), which amended~~instrumentation in the ~~EBC Credit Agreement. Pursuant~~immediate area of the fire. The largest impact was the damage to the ~~Fifth Amendment, EBC agreed to provide~~electrical conduit that feeds the ~~Company up to a $2 million term loan to be used for capital expenditures (the “CapEx Loan~~”), which amounts may be requested from time to time by the Company, provided that not more than four advances of such amount may be requested, with each advance being not less than $500,000 (in multiples of $100,000). The amendment also provided that any prepayments of the EBC Credit Agreement would first be appliedpower to the ~~term loan~~refinery equipment. As of October 26, 2020, the facility was back up and ~~then to the CapEx Loan. The CapEx Loan bears interest at the rate of LIBOR (1.17% at June 30, 2020) plus 7%, or to the extent that LIBOR is not available, the highest of the prime rate~~running and ~~the Federal Funds Rate plus 0.50%, in each case, plus 6%. We are required to repay the CapEx Loan in monthly installments of 1/48~~^th of the amount borrowed, each month that the CapEx Loan is outstanding, through maturity. The Fifth Amendment also included provisions providing for either the prime rate or Federal Funds Rate, plus 0.50%, to apply as the interest rate of loans made under the EBC Credit Agreement, in the ~~event LIBOR is unavailable or unable to be used for such interest rate calculations.~~process of filing a claim with our insurance company. The ~~obligation of EBC to fund the CapEx Loan is subject to customary conditions and requirements set forth in the Fifth Amendment, including the requirement~~Company believes that the Company have maintained daily availability under the ABL Credit Agreement greater than $1 million for the last thirty days, and that such availability would remain over $1 million, on a pro forma basis with such new loan. We are also required to provide the agent for the EBC Credit Agreement, a first priority security interest in the rolling stock collection assets or other assets acquired with the CapEx Loan.it maintains adequate insurance coverage.

F-30

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

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Report contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. 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. These factors include:

•risks associated with our outstanding credit facilities, including amounts owed, restrictive covenants, security interests thereon and our ability to repay such facilities and amounts due thereon when due;

•risks associated with our outstanding preferred stock, including redemption obligations in connection therewith, restrictive covenants and our ability to redeem such securities when required pursuant to the terms of such securities and applicable law;

•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 relationship with KMTEX;

•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;

•rules and regulations making our operations more costly or restrictive, including IMO 2020 (defined below);

•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;

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

•liabilities associated with acquired companies, assets or businesses;

•interruptions at our facilities;

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

•our ability to acquire and construct new facilities;

•certain events of default which have occurred under our debt facilities and previously been waived;

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

•our ability to effectively manage our growth;

•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 associated with COVID-19, the global efforts to stop the spread of COVID-19, potential downturns in the U.S. and global economies due to COVID-19 and the efforts to stop the spread of the virus, and COVID-19 in general;

•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~~”.

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

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. 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.

This information 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, 2019, filed with the Securities and Exchange Commission on March 4, 2020 (the "Annual Report").

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”.

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.

Please see the “Glossary of Selected Terms” incorporated by reference hereto as Exhibit 99.1, for a list of abbreviations and definitions used throughout this 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.

In addition, unless the context otherwise requires and for the purposes of this report only:

“Base Oil” means the lubrication grade oils initially produced from refining crude oil (mineral base oil) or through chemical synthesis (synthetic base oil). In general, only 1% to 2% of a barrel of crude oil is suitable for refining into base oil. The majority of the barrel is used to produce gasoline and other hydrocarbons;

“Cutterstock” means fuel oil used as a blending agent added to other fuels. For example, to lower viscosity;

“Crack” means breaking apart crude oil into its component products, including gases like propane, heating fuel, gasoline, light distillates like jet fuel, intermediate distillates like diesel fuel and heavy distillates like grease;

"Exchange Act" refers to the Securities Exchange Act of 1934, as amended;

"Feedstock” means a product or a combination of products derived from crude oil and destined for further processing in the refining or re-refining industries. It is transformed into one or more components and/or finished products;

“Gasoline Blendstock” means naphthas and various distillate products used for blending or compounding into finished motor gasoline. These components can include reformulated gasoline blendstock for oxygenate blending (RBOB) but exclude oxygenates (alcohols and ethers), butane, and pentanes (an organic compound with properties similar to a butane);

“Hydrotreating” means the process of reacting oil fractions with hydrogen in the presence of a catalyst to produce high-value clean products;

“IMO 2020” effective January 1, 2020, the International Maritime Organization (IMO) mandated a maximum sulphur content of 0.5% in marine fuels globally;

“MDO” means marine diesel oil, which is a type of fuel oil and is a blend of gasoil and heavy fuel oil, with less gasoil than intermediate fuel oil used in the maritime field;

“Naphthas” means any of various volatile, highly flammable liquid hydrocarbon mixtures used chiefly as solvents and diluents and as raw materials for conversion to gasoline;

“Pygas” means pyrolysis gasoline, an aromatics-rich gasoline stream produced in sizeable quantities by an ethylene plant. These plants are designed to crack a number of feedstocks, including ethane, propane, naphtha, and gasoil. Pygas can serve as a high-octane blendstock for motor gasoline or as a feedstock for an aromatics extraction unit;

"SEC" or the "Commission" refers to the United States Securities and Exchange Commission;

"Securities Act" refers to the Securities Act of 1933, as amended; and

"VGO" refers to Vacuum Gas Oil (also known as cat feed) - a feedstock for a fluid catalytic cracker typically found in a crude oil refinery and used to make gasoline No. 2 oil and other byproducts.

Where You Can Find Other Information

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.

Novel Coronavirus (COVID-19)

We sell products and services primarily in the U.S. domestic oil and gas commodity markets. Throughout the first quarter of 2020, the industry experienced multiple factors which lowered both the demand for, and prices of, oil and gas. First, the COVID-19 pandemic lowered global demand for hydrocarbons, as social distancing and travel restrictions were implemented across the world. Second, the lifting of Organization of the Petroleum Exporting Countries (OPEC)+ supply curtailments, and the associated increase in production of oil, drove the global supply of hydrocarbons higher through the first quarter of 2020. As a result of both dynamics, prices for hydrocarbons declined 67% from peak prices within the quarter. In addition, while global gross domestic product (GDP) growth was impacted by COVID-19 during the first ~~half~~nine months of 2020, we expect GDP to continue to decline globally in the ~~third and~~ fourth ~~quarters~~quarter of 2020 and for at least the early part of 2021, as a result of the COVID-19 pandemic. As a result, we expect oil and gas related markets will continue to experience significant volatility in 2020 and 2021. Our goal through this downturn has been to remain disciplined in allocating capital and to focus on liquidity and cash preservation. We are taking the necessary actions to right-size the business for expected activity levels.

As a result of the impact of the COVID-19 outbreak, some of our feedstock suppliers have permanently or temporarily closed their businesses, limited our access to their businesses, or have experienced a decreased demand for services. As a result of the above, and due to ‘stay-at-home’ and other social distancing orders, as well as the decline in U.S. travel caused by COVID-19, we have seen a significant decline in the ~~amount~~volume of feedstocks (specifically used oil) that we have been able to collect, and therefore process through our facilities. A prolonged economic slowdown, period of social quarantine (imposed by the government or otherwise), or a prolonged period of decreased travel due to COVID-19 or the responses thereto, will likely have a material negative adverse impact on our ability to produce products, and consequently our revenues and results of operations.

The full extent of the impact of COVID-19 on our business and operations currently cannot be estimated and will depend on a number of factors including the scope and duration of the global pandemic.

Description of Business Activities:

We are an environmental services company that recycles industrial waste streams and off-specification commercial chemical products. Our primary focus is recycling used motor oil and other petroleum by-products. We are engaged in operations across the entire petroleum recycling value chain including collection, aggregation, transportation, storage, re-refinement, and sales of aggregated feedstock and re-refined products to end users. We operate in three divisions: Black Oil, Refining and Marketing, and Recovery.

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 ~~June~~September 30, 2020, we aggregated approximately ~~83.1~~81.4 million gallons of used motor oil and other petroleum by-product feedstocks and managed the re-refining of approximately ~~69.7~~69.8 million gallons of used motor oil with our proprietary vacuum gas oil ("VGO") and Base Oil processes.

Our Black Oil division collects and purchases used motor oil directly from third-party generators, aggregates used motor oil from an established network of local and regional collectors, and sells used motor oil to our customers for use as a feedstock or replacement fuel for industrial burners. We operate a refining facility that uses our proprietary Thermal Chemical Extraction Process (“TCEP”) and we also utilize third-party processing facilities. TCEP’s original purpose was to re-fine used oil into marine cutterstock; however, in the third quarter of fiscal 2015, that use ceased to be economically accretive, and instead, we operated

TCEP for the purposes of pre-treating our used motor oil feedstock prior to shipping to our facility in Marrero, Louisiana from the third quarter of fiscal 2015 to the third quarter of 2019. During the fourth quarter of 2019, the original purpose of TCEP once again became economically viable and at that time we switched to using TCEP to re-fine used oil into marine cutterstock; provided that with the recent decline in oil prices and challenges in obtaining feedstock, we switched back to using TCEP for the purposes of pre-treating our used motor oil feedstock prior to shipping to our facility in Marrero, Louisiana, beginning in the first quarter of 2020, and continuing through the filing date of this report.

We also acquired our Marrero, Louisiana facility, which facility re-refines used motor oil and also produces VGO and the Myrtle Grove re-refining complex in Belle Chasse, Louisiana (which is now owned by a special purpose entity which we own an approximate 85% interest of) in May 2014.

Our Refining and Marketing division aggregates and manages the re-refinement of used motor oil and other petroleum by-products and sells the re-refined products to end customers.

Our Recovery division includes a generator solutions company for the proper recovery and management of hydrocarbon streams as well as metals which includes transportation and marine salvage services throughout the Gulf Coast.

Black Oil Division

Our Black Oil division is engaged in operations across the entire used motor oil recycling value chain including collection, aggregation, transportation, storage, refinement, 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, and petrochemical manufacturing operations. We own a fleet of 41 collection vehicles, which routinely visit generators to collect and purchase used motor oil. We also aggregate used oil from a diverse network of approximately 50 suppliers who operate similar collection businesses to ours.

We manage the logistics of transport, storage and delivery of used oil to our customers. We own a fleet of 30 transportation trucks and more than 80 aboveground storage tanks with over 8.6 million gallons of storage capacity. These assets are used by both the Black Oil division and the Refining and Marketing division. In addition, we also utilize third parties for the transportation and storage of used oil feedstocks. Typically, we sell used oil to our customers in bulk to ensure efficient delivery by truck, rail, or barge. 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. Also, as discussed above under “Description of Business Activities”, from time to time, when market conditions warrant (i.e., when oil prices are sufficiently high), we have used our proprietary TCEP technology to re-refine used oil into marine fuel cutterstock. Due to the recent decline in oil prices and challenges in obtaining feedstock, since the first quarter of 2020, we have used TCEP solely to pre-treat our used motor oil feedstock prior to shipping to our facility in Marrero, Louisiana. In addition, at our Marrero, Louisiana facility, we produce a Vacuum Gas Oil (VGO) product that is sold to refineries as well as to the marine fuels market. At our Columbus, Ohio facility (Heartland Petroleum), we produce a base oil product that is sold to lubricant packagers and distributors.

Refining and Marketing Division

Our Refining and Marketing division is engaged in the aggregation of feedstock, re-refining it into higher value-end products, and selling these products to our customers, as well as related transportation and storage activities. We aggregate a diverse mix of feedstocks including used motor oil, petroleum distillates, transmix and other off-specification chemical products. These feedstock streams are purchased from pipeline operators, refineries, chemical processing facilities and third-party providers, and are also transferred from our Black Oil division. We have a toll-based processing agreement in place with KMTEX to re-refine feedstock streams, under our direction, into various end products that we specify. KMTEX uses industry standard processing technologies to re-refine our feedstocks into pygas, gasoline blendstock and marine fuel cutterstock. We sell all of our re-refined products directly to end-customers or to processing facilities for further refinement. In addition, we are distributing refined motor fuels such as gasoline, blended gasoline products and diesel used as engine fuels, to third party customers who typically resell these products to retailers and end consumers.

Recovery Division

The Company’s Recovery Segment includes a generator solutions company for the proper recovery and management of hydrocarbon streams, the sales and marketing of Group III base oils and other petroleum-based products, together with the recovery and processing of metals.

Thermal Chemical Extraction Process

We own the intellectual property for our patented TCEP. TCEP is a technology which utilizes thermal and chemical dynamics to extract impurities from used oil which increases the value of the feedstock. We intend to continue to develop our TCEP technology and design with the goal of producing additional re-refined products, including lubricating base oil.

TCEP differs from conventional re-refining technologies, such as vacuum distillation and hydrotreatment, by relying more heavily on chemical processes to remove impurities rather than temperature and pressure. Therefore, the capital requirements to build a TCEP plant are typically much less than a traditional re-refinery because large feed heaters, vacuum distillation columns, and a hydrotreating unit are not required. The end product currently produced by TCEP is used as fuel oil cutterstock. Conventional re-refineries produce lubricating base oils or product grades slightly lower than base oil that can be used as industrial fuels or transportation fuel blendstocks.

We currently estimate the cost to construct a new, fully-functional, commercial facility using our TCEP technology, with annual processing capacity of between 25 and 50 million gallons at another location would be approximately $10 - $15 million, which could fluctuate based on throughput capacity. The facility infrastructure would require additional capitalized expenditures which would depend on the location and site specifics of the facility. Our TCEP technology converts feedstock into a low sulfur marine fuel that can be sold into the new 0.5% low sulfur marine fuel specification mandated under International Maritime Organization (IMO) rules which went into effect on January 1, 2020. As described above, due to the recent decline in oil prices and challenges in obtaining feedstock, we switched back to using TCEP for the purposes of pre-treating our used motor oil feedstock prior to shipping to our facility in Marrero, Louisiana beginning in the first quarter of 2020. We have no current plans to construct any other TCEP facilities at this time.

Products and Services

We generate substantially all of our revenue from the sale of ~~six~~eight product categories. All of these products are commodities that are subject to various degrees of product quality and performance specifications.

~~Used Motor~~

Base Oil

~~Used motor~~

Base oil is an oil to which other oils or substances are added to produce a ~~petroleum-based or synthetic lubricant that contains impurities such as dirt, sand, water, and chemicals.~~lubricant. Typically the main substance in lubricants, base oils, are refined from crude oil.

~~Fuel Oil~~

Fuel oil is a distillate fuel which is typically blended with lower quality fuel oils. The distillation of used oil and other petroleum by-products creates a fuel with low viscosity, as well as low sulfur, ash, and heavy metal content, making it an ideal blending agent.

Pygas

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

~~Gasoline Blendstock~~

~~Gasoline blendstock includes Naphthas~~Industrial Fuel

Industrial fuel is a distillate fuel oil which is typically a blend of lower quality fuel oils. It can include diesel fuels and ~~various distillate products~~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 ~~or compounding into~~agent.

Distillates

Distillates are finished fuel products such as gasoline and diesel fuels.

Oil Collection Services

Oil collection services include the collection, handling, treatment and sales of used motor ~~gasoline. These components can~~oil and products which include ~~reformulated gasoline blendstock for oxygenate blending (RBOB) but exclude oxygenates (alcohols and ethers), butane, and pentanes plus. We~~used motor oil (such as oil filters) which are ~~not currently processing gasoline blendstocks as the processing margins are not currently economically feasible.~~collected from our customers.

Metals

~~Base Oil~~

~~An oil to which other oils or substances are added to produce a lubricant. Typically, the main substance in lubricants and base oils is refined from crude oil.~~

~~Scrap Metal(s)~~

~~Consists~~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.

Other re-refinery products

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

VGO/Marine fuel sales

VGO/Marine fuel sales relate to the sale of low sulfur fuel meeting the criteria for IMO 2020 compliant marine fuels.

The way that the product categories above fit into our three operating segments (1) Black Oil; (2) Refining and Marketing; and (3) Recovery, are indicated below:


	Black Oil(1)	Refining and Marketing(2)	Recovery(3)
Base oil	X		X
Pygas		X
Industrial fuel	X	X
Distillates		X
Oil collection services	X
Metals			X
Other re-refinery products	X		X
VGO/Marine fuel sales	X

(1) As discussed in greater detail above under “Black Oil Division”, the Black Oil segment consists primary 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; and (e) the sale of VGO (vacuum gas oil)/marine fuel.

(2) As discussed in greater detail above under “Refining and Marketing Division”, the Refining and Marketing segment consists primarily of the sale of pygas; industrial fuels, which are produced at a third-party facility (KMTEX); and distillates.

(3) As discussed in greater detail above under “Recovery Division”, 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.

RESULTS OF OPERATIONS

Description of Material Financial Line Items:

Revenues

We generate revenues from three existing operating divisions as follows:

BLACK OIL - Revenues from our Black Oil division are comprised primarily of product sales from our re-refineries and feedstock sales (used motor oil) which are purchased from generators of used motor oil such as oil change shops and garages, as well as a network of local and regional suppliers. Volumes are consolidated for efficient delivery and then sold to third-party re-refiners and fuel oil blenders for the export market. In addition, through used oil re-refining, we re-refine used oil into different commodity products. Through the operations at our Marrero, Louisiana facility, we produce a Vacuum Gas Oil (VGO) product from used oil re-refining which is then sold via barge to crude refineries to be utilized as an intermediate feedstock in the refining process. Through the operations at our Columbus, Ohio facility, we produce a base oil finished product which is then sold via truck or rail car to end users for blending, packaging and marketing of lubricants.

REFINING AND MARKETING - The Refining and Marketing division generates revenues relating to the sales of finished products. The Refining and Marketing division gathers 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.

RECOVERY - The Recovery division is a generator solutions company for the proper recovery and management of hydrocarbon streams. We own and operate a fleet of trucks and other vehicles used for shipping and handling equipment and scrap materials.

Our revenues are affected by changes in various commodity prices including crude oil, natural gas, #6 oil and metals.

Cost of Revenues

BLACK OIL - Cost of revenues for our Black Oil division are comprised primarily of feedstock purchases from a network of providers. Other cost of revenues include processing costs, transportation costs, purchasing and receiving costs, analytical assessments, brokerage fees and commissions, and surveying and storage costs.

REFINING AND MARKETING - The Refining and Marketing division incurs cost of revenues relating to the purchase of feedstock, purchasing and receiving costs, and inspection and processing of the feedstock into gasoline blendstock, pygas and fuel oil cutter by a third party. Cost of revenues also includes broker’s fees, inspection and transportation costs.

RECOVERY - The Recovery division incurs cost of revenues relating to the purchase of hydrocarbon products, purchasing and receiving costs, inspection, and transporting of metals and other salvage and materials. Cost of revenues also includes broker’s fees, inspection and transportation costs.

Our cost of revenues is affected by changes in various commodity indices, including crude oil, natural gas, #6 oil and metals. For example, if the price for crude oil increases, the cost of solvent additives used in the production of blended oil products, and fuel cost for transportation cost from third party providers will generally increase. Similarly, if the price of crude oil falls, these costs may also decline.

General and Administrative Expenses

Our general and administrative expenses consist primarily of salaries and other employee-related benefits for executive, administrative, legal, financial, and information technology personnel, as well as outsourced and professional services, rent, utilities, and related expenses at our headquarters, as well as certain taxes.

Depreciation and Amortization Expenses

Our depreciation and amortization expenses are primarily related to the property, plant and equipment and intangible assets acquired in connection with our Vertex Holdings, L.P. (formerly Vertex Energy, L.P.), a Texas limited partnership (“Holdings”), Omega Refining, LLC's (“Omega Refining”) and Warren Ohio Holdings Co., LLC, f/k/a Heartland Group Holdings, LLC (“Heartland”), Acadiana Recovery, LLC, Nickco Recycling, Inc., Ygriega Environmental Services, LLC, Specialty Environmental Services and Crystal Energy, LLC acquisitions, described in greater detail in the 2019 Annual Report and herein (as to Crystal).

Depreciation and amortization expense attributable to cost of revenues reflects the depreciation and amortization of the fixed assets at our refineries along with rolling stock at our collection branches.

Depreciation and amortization expense attributable to operating expenses reflects depreciation and amortization related to our corporate and administrative offices along with internet technology (IT) related items and intangibles.

Recent Events

Heads of Agreement

On January 10, 2020, Vertex Operating entered into a Heads of Agreement (the “Heads of Agreement”) with Bunker One (USA) Inc., which is owned by Bunker Holding, a Danish holding company (“Bunker One”). Pursuant to the Heads of Agreement, the Company and Bunker One agreed to form a joint decision-making body (the “JDMB”) to focus on strategic matters related to the overall cooperation of the parties and to establish rules and procedures for identifying and undertaking joint projects. The Heads of Agreement is described in greater detail in the Current Report on Form 8-K filed by the Company with the Securities and Exchange Commission on January 13, 2020.

JSMA

Also on January 10, 2020, Vertex Operating entered into a Joint Supply and Marketing Agreement (the “JSMA”), with Bunker One. The JSMA is effective as of May 1, 2020, and provides for Bunker One to acquire 100% of the production from the Company’s Marrero, Louisiana re-refining facility (which produces approximately 100,000 barrels per month of a bunker suitable fuel for offshore use and use as a marine vessel’s propulsion system (“Bunker Fuel”)) at the arithmetic mean of Platts #2 USGC Pipe and Platt’s ULSD USGC Waterborne on agreed pricing days less an agreed upon discount, adjusted every three months. The JSMA is described in greater detail in the Current Report on Form 8-K filed by the Company with the Securities and Exchange Commission on January 13, 2020.

Heartland Share Purchase, Subscription Agreement and Heartland Limited Liability Company Agreement

Our Heartland Share Purchase and Subscription Agreement and the Heartland Limited Liability Company Agreement are described in greater detail under “Part I” - “Item 1. Financial Statements” - “Note 14. Share Purchase and Subscription Agreements” - “Heartland Share Purchase and Subscription Agreement".

Administrative Services Agreement

Pursuant to an Administrative Services Agreement, entered into on the Heartland Closing Date, Heartland SPV engaged Vertex Operating and the Company to provide administrative/management services and day-to-day operational management services of Heartland SPV in connection with the collection, storage, transportation, transfer, refining, re-refining, distilling, aggregating, processing, blending, sale of used motor oil, used lubricants, wholesale lubricants, recycled fuel oil, or related products and services such as vacuum gas oil, base oil, and asphalt flux, in consideration for a monthly fee. The Administrative Services Agreement has a term continuing until the earlier of (a) the date terminated with the mutual consent of the parties; (b) a liquidation of Heartland SPV; (c) a Heartland Redemption (as ~~defined~~described in Note 14 ofto the unaudited notes to the consolidated financial ~~statements)~~statements included herein); (d) the determination of Heartland SPV to terminate following a change of control (as described in the Administrative Services Agreement) of Heartland SPV or the Company; or (e) written notice from the non-breaching party upon the occurrence of a breach which is not cured within the cure period set forth in the Administrative Services Agreement.

The Administrative Services Agreement also provides that in the event that Heartland SPV is unable to procure used motor-oil (“UMO”) through its ordinary course operations, subject to certain conditions, Vertex Operating and the Company are required to use their best efforts to sell (or cause an affiliate to sell) UMO to Heartland SPV, at the lesser of the (i) then-current market price for UMO sold in the same geography area and (ii) price paid by such entity for such UMO. Finally, the Administrative Services Agreement provides that in the event that the Heartland SPV is unable to procure vacuum gas oil (“VGO”) feedstock

through its ordinary course operations, subject to certain conditions, Vertex Operating and the Company are required to use their best efforts to sell (or cause an affiliate to sell) VGO to Heartland SPV, at the lesser of the (i) then-current market price for VGO sold in the same geographic area and (ii) price paid for such VGO.

Advisory Agreement

On the Heartland Closing Date, Heartland SPV entered into an Advisory Agreement with Tensile, pursuant to which Tensile agreed to provide advisory and consulting services to Heartland SPV and Heartland SPV agreed to reimburse and indemnify Tensile and its representatives, in connection therewith.

Crystal Energy, LLC

On June 1, 2020, the Company entered into and closed a Member Interest Purchase Agreement with Crystal Energy, LLC ("Crystal') pursuant to which the Company agreed to buy the outstanding membership interests of Crystal for aggregate cash consideration of $1,822,690. This resulted in the recognition of $1,939,364 in accounts receivable, $976,512 in inventory, $14,484 in other current assets, and $1,107,670 in current liabilities. Upon the closing of the acquisition, Crystal became a wholly-owned subsidiary of the Company.

Marrero Refinery Fire

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. As of October 26, 2020, the facility was back up and running and in the process of filing a claim with our insurance company. The Company believes that it maintains adequate insurance coverage.

RESULTS OF OPERATIONS FOR THE THREE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2020 COMPARED TO THE THREE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2019

Set forth below are our results of operations for the three months ended ~~June~~September 30, 2020 as compared to the same period in 2019.


	Three Months Ended September 30,				$ Change - Favorable (Unfavorable)		% Change - Favorable (Unfavorable)
	2020		2019
Revenues	$	37,383,632	$	37,799,259	$	(415,627)	(1)	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	31,186,684		32,372,316		1,185,632		4	%
Depreciation and amortization attributable to costs of revenues	1,313,162		1,359,629		46,467		3	%
Gross profit	4,883,786		4,067,314		816,472		20	%



Operating expenses:
Selling, general and administrative expenses	6,241,570		6,153,184		(88,386)		(1)	%
Depreciation and amortization attributable to operating expenses	482,869		455,953		(26,916)		(6)	%

Total operating expenses	6,724,439		6,609,137		(115,302)		(2)	%


Loss from operations	(1,840,653)		(2,541,823)		701,170		28	%

Other income (expense):



Other income	1		918,153		(918,152)		(100)	%
Gain (loss) on asset sales	(136,434)		—		(136,434)		(100)	%
Gain (loss) on change in value of derivative liability	256,587		1,290,792		(1,034,205)		(80)	%

Interest expense	(234,671)		(826,005)		591,334		72	%
Total other income (expense)	(114,517)		1,382,940		(1,497,457)		(108)	%

Loss before income tax	(1,955,170)		(1,158,883)		(796,287)		(69)	%

Income tax benefit (expense)	—		—		—		—	%

Net Loss	(1,955,170)		(1,158,883)		(796,287)		(69)	%
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest	480,215		(67,102)		547,317		816	%
Net loss attributable to Vertex Energy, Inc.	$	(2,435,385)	$	(1,091,781)	$	(1,343,604)	(123)	%

Three Months Ended June 30, $ Change - Favorable (Unfavorable) % Change - Favorable (Unfavorable)
2020 2019
Revenues $ 21,374,127
$ 43,657,292
$ (22,283,165 ) (51 )%
Cost of revenues (exclusive of depreciation and amortization shown separately below) 22,197,805
36,515,421
14,317,616
39 %
Gross profit (loss) (823,678 ) 7,141,871
(7,965,549 ) (112 )%

Selling, general and administrative expenses 6,030,560
6,028,859
(1,701 ) — %
Depreciation and amortization 1,713,461
1,780,890
67,429
4 %
Total operating expenses 7,744,021
7,809,749
65,728
1 %

Loss from operations (8,567,699 ) (667,878 ) (7,899,821 ) (1,183 )%

Other income (expense):
Interest income 20
1,918
(1,898 ) (99 )%
Gain on asset sales 12,344
29,150
(16,806 ) (58 )%
Gain (loss) on change in value of derivative liability (110,965 ) 746,017
(856,982 ) (115 )%
Interest expense (222,173 ) (738,972 ) 516,799
70 %
Total other income (expense) (320,774 ) 38,113
(358,887 ) (942 )%

Loss before income tax (8,888,473 ) (629,765 ) (8,258,708 ) (1,311 )%

Income tax benefit (expense) —
—
—
— %

Net Loss (8,888,473 ) (629,765 ) (8,258,708 ) (1,311 )%
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest 109,165
(202,329 ) 311,494
154 %
Net loss attributable to Vertex Energy, Inc. $ (8,997,638 ) $ (427,436 ) $ (8,570,202 ) (2,005 )%

Our revenues and cost of revenues are significantly impacted by fluctuations in commodity prices; increases in commodity prices typically result in increases in revenue and cost of ~~revenues.~~revenues (i.e., feedstock acquisition costs). Our gross profit is to a large extent a function of the market discount we are able to obtain in purchasing feedstock, as well as how efficiently management conducts operations. Additionally, we use hedging instruments to manage our exposure to underlying commodity ~~prices.~~

~~Total revenues decreased by 51%~~prices. During the three months ended September 30, 2020, we had a gain of $5 thousand in our hedging instruments as compare to a loss of $1.6 million for the three months ended ~~June~~September 30, 2019. We recognize our hedging activities from commodity derivatives in our cost of goods sold. During the three months ended September 30, 2020, compared to the same period in 2019, we saw a 10% decrease in the discount we were paying for feedstock into our refineries. In addition, we saw a 3% decrease in operating costs (inclusive of depreciation and amortization) on a per barrel basis for the third quarter of 2020 as compared to the same period in 2019.

Total revenues decreased by 1% for the three months ended September 30, 2020, compared to the same period in 2019, due primarily to lower commodity prices and decreased volumes at our ~~refineries~~refineries; offset by the $17 million of revenue generated in from our newly acquired Crystal opertations for the three months ended ~~June~~September 30, 2020, compared to the same period in 2019. Total volume ~~decreased 33%~~increased 1% during the three months ended ~~June~~September 30, 2020 compared to the same period in 2019. Volumes were impacted as a result of decreased availability of feedstocks, specifically used motor oil, in the overall marketplace which forced us

to ~~reduce~~have reduced production rates at each of our Heartland facility, as well as our Marrero facility. In addition, our Marrero facility was brought down for an extended turnaround during the three months ended June 30, 2020. Gross profit decreased by 112% for the three months ended June 30, 2020, compared to the three months ended June 30, 2019.facilities. This ~~decrease was largely a result of decreases in volumes at both our Heartland and Marrero facilities, along with lower commodity prices which had an impact on margins during the period.~~

We had a gross loss as a percentage of revenues of 3.9% for the three months ended June 30, 2020, compared to gross profit as a percentage of revenues of 16.4% for the three months ended June 30, 2019. The main reason for the decrease was largely due to ~~shelter in place orders in the locations in which we collect used motor oil as a result~~continued impacts of the ~~COVID-19 pandemic, which directly impacted the generation of used oil, and caused a dramatic reduction in volumes of feedstock available for use in our refineries.~~

Additionally, our per barrel margin decreased 117% for the three months ended June 30, 2020, relative to the three months ended June 30, 2019. This decrease was a result of the decreases in our product spreads related to sharp decreases in finished product prices and operating costs at our Gulf Coast operations, during the three months ended June 30, 2020, compared to the same period during 2019. The 39% decrease in cost of revenues for the three months ended June 30, 2020, compared to the three months ended June 30, 2019, is mainly a result of the lower production volumes at our Marrero facility during the period, as well as lower operating costs and commodity prices during the period.

~~Each of our segments’ income (loss) from operations during the three months ended June 30, 2020 and 2019 was as follows:~~

Three Months Ended
June 30,
$ Change - Favorable (Unfavorable) % Change - Favorable (Unfavorable)
Black Oil Segment 2020
2019
Total revenue $ 11,543,135
$ 37,907,811

$ (26,364,676 ) (70 )%
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 11,848,334

31,368,939

19,520,605
62 %
Gross profit (loss) (305,199 )
6,538,872

(6,844,071 ) (105 )%
Selling general and administrative expense 4,869,391
5,037,708
168,317
3 %
Depreciation and amortization 1,329,751
1,375,313
45,562
3 %
Income (loss) from operations $ (6,504,341 ) $ 125,851
$ (6,630,192 ) (5,268 )%

Refining and Marketing Segment

Total revenue $ 6,297,328
$ 3,277,402

$ 3,019,926
92 %
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 5,958,778
2,705,031

(3,253,747 ) (120 )%
Gross profit 338,550

572,371

(233,821 ) (41 )%
Selling general and administrative expense 578,027
459,600
(118,427 ) (26 )%
Depreciation and amortization 219,766
245,179
25,413
10 %
Loss from operations $ (459,243 ) $ (132,408 ) $ (326,835 ) (247 )%

Recovery Segment

Total revenue $ 3,533,664
$ 2,472,079

$ 1,061,585
43 %
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 4,390,693
2,441,451

(1,949,242 ) (80 )%
Gross profit (loss) (857,029 )
30,628

(887,657 ) (2,898 )%
Selling general and administrative expense 583,142
531,551
(51,591 ) (10 )%
Depreciation and amortization 163,944
160,398
(3,546 ) (2 )%
Loss from operations $ (1,604,115 ) $ (661,321 ) $ (942,794 ) (143 )%

~~Our Black Oil division's volume decreased approximately 45% during the three months ended June 30, 2020, compared to the same period in 2019. This decrease was largely due to~~ shelter in place orders in the locations in which we collect used motor oil as a result of the COVID-19 pandemic, which directly impacted the generation of used oil, which caused a ~~dramatic~~reduction in volumes of feedstock available for use in our refineries. The Company saw an increase in the volume of Group III base oil during the three months ended September 30, 2020. Gross profit increased by 20% for the three months ended September 30, 2020, compared to the three months ended September 30, 2019. This increase was largely a result of lower operating costs at our facilities relating to decreased transportation expenses, maintenance and contract labor, which had an impact on margins during the period, and the increases in volumes as noted above.

During the three months ended September 30, 2020, total cost of revenues (exclusive of depreciation and amortization) was $31,186,684, compared to $32,372,316 for the three months ended September 30, 2019, a decrease of $1,185,632 or 4% from the prior period. The main reason for the decrease was the result of a decline in commodity prices, which impacted our feedstock pricing and a decrease in overall operating costs at our refining facilities.

For the three months ended September 30, 2020, total depreciation and amortization expense attributable to cost of revenues was $1,313,162, compared to $1,359,629 for the three months ended September 30, 2019, a decrease of $46,417 mainly due to some of our assets becoming fully depreciated.

We had gross profit as a percentage of revenue of 13% for the three months ended September 30, 2020, compared to gross profit as a percentage of revenues of 10.7% for the three months ended September 30, 2019. The main reason for the improvement was the slight increase in volumes, along with decreases in operating expenses at our refineries during the period. In addition, the company was proactive in its risk management of commodity prices through the use of derivative instruments which resulted in a $1.6 million positive impact on gross margins when compared to the same period a year ago.

Additionally, our per barrel margin increased 19% for the three months ended September 30, 2020, relative to the three months ended September 30, 2019. Our per barrel margin is calculated by dividing the total volume of product sold (in bbls) by total gross profit for the applicable period ($4,883,786 for the 2020 period versus $4,067,314 for the 2019 period). This increase was a result of the improvements in our product spreads related to decreases in feedstock product prices and decreases in operating costs at our refining facilities, during the three months ended September 30, 2020, compared to the same period during 2019.

Overall, commodity prices were down for the three months ended September 30, 2020, compared to the same period in 2019. For example, the average posting (U.S. Gulfcoast Residual Fuel No. 6 3%) for the three months ended September 30, 2020, decreased $13.62 per barrel from a three-month average of $51.56 for the three months ended September 30, 2019 to $37.95 per barrel for the three months ended September 30, 2020. The average posting (U.S. Gulfcoast Unleaded 87 Waterborne) for the three months ended September 30, 2020 decreased $22.74 per barrel from a three-month average of $72.97 for the three months ended September 30, 2019 to $50.22 per barrel for the three months ended September 30, 2020.

We had a loss from operations of $1,840,653 for the three months ended September 30, 2020, compared to a loss from operations of $2,541,823 for the three months ended September 30, 2019, a decrease of $701,170 or 28% from the prior year’s three-month period. The decrease in loss from operations was due to the overall reduction in operating expenses at our facilities along with increases in charges throughout our collection operations. As market conditions change, the charges for our oil collection services will fluctuate.

We had interest expense of $234,671 for the three months ended September 30, 2020, compared to interest expense of $826,005 for the three months ended September 30, 2019, a decrease in interest expense of $591,334 or 72% from the prior period, due to having a lower balance owed under our line of credit and term loan along with a lower interest rate on the term debt outstanding during the three months ended September 30, 2020, compared to the prior year’s period. The Company received a total of $21.0 million from the Tensile transaction, of which approximately $9.0 million was used to pay down our debt obligations.

We had a $256,587 gain on change in value of derivative liability for the three months ended September 30, 2020, in connection with certain warrants granted in June 2015 and May 2016, as described in greater detail in "Note 9. Preferred Stock and Detachable Warrants" to the unaudited consolidated financial statements included herein under "Part I"-"Item 1 Financial Statements", compared to a gain on change in the value of our derivative liability of $1,290,792 in the prior year's period. This change was mainly due to the fluctuation in the market price of our common stock 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 other income of $1 for the three months ended September 30, 2020, compared to other income of $918,153 for the three months ended September 30, 2019. Other income for the three months ended September 30, 2019, was in connection with the Company receiving a payment of $ 907,500 related to the proceeds of an insurance settlement for a fire that had occurred at its used

oil re-refining plant located in Churchill County, Nevada, which we previously rented. The Company previously determined this loan was uncollectible and wrote it off.

We had a loss on asset sales of $136,434 for the three months ended September 30, 2020, in connection with sale of equipment compared to no gain or loss on asset sales in the prior year’s period.

We had a net loss of $1,955,170 for the three months ended September 30, 2020, compared to a net loss of $1,158,883 for the three months ended September 30, 2019, an increase in net loss of $796,287 or 69% from the prior period. The main reason for the increase in net loss for the three months ended September 30, 2020, compared to the three months ended September 30, 2019, was attributable to the decrease in gain in derivative liability for the three months ended September 30, 2020, which decreased to $256,587 for such period, compared to $1,290,792 for the period ended September 30, 2019, offset by the $816,472 increase in gross profit as discussed above.

Each of our segments’ income (loss) from operations during the three months ended September 30, 2020 and 2019 was as follows:


	Three Months Ended September 30,				$ Change - Favorable (Unfavorable)		% Change - Favorable (Unfavorable)
Black Oil Segment	2020		2019
Revenues	$	19,988,122	$	32,330,531	$	(12,342,409)	(38)	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	14,687,141		27,663,983		12,976,842		47	%
Depreciation and amortization attributable to costs of revenues	1,041,719		1,073,520		31,801		3	%

Gross profit	4,259,262		3,593,028		666,234		19	%
Selling general and administrative expense	4,899,956		5,040,772		140,816		3	%
Depreciation and amortization attributable to operating expenses	390,105		335,105		(55,000)		(16)	%

Loss from operations	$	(1,030,799)	$	(1,782,849)	$	752,050	42	%






Refining and Marketing Segment
Revenues	$	13,501,749	$	3,076,454	$	10,425,295	339	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	13,217,757		2,511,314		(10,706,443)		(426)	%
Depreciation and amortization attributable to costs of revenues	121,744		147,658		25,914		18	%
Gross profit	162,248		417,482		(255,234)		(61)	%
Selling general and administrative expense	696,611		494,781		(201,830)		(41)	%
Depreciation and amortization attributable to operating expenses	72,314		100,398		28,084		28	%
Loss from operations	$	(606,677)	$	(177,697)	$	(428,980)	(241)	%






Recovery Segment
Revenues	$	3,893,761	$	2,392,274	$	1,501,487	63	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	3,281,786		2,197,019		(1,084,767)		(49)	%
Depreciation and amortization attributable to costs of revenues	149,699		138,451		(11,248)		(8)	%
Gross profit	462,276		56,804		405,472		714	%
Selling general and administrative expense	645,003		617,631		(27,372)		(4)	%
Depreciation and amortization attributable to operating expenses	20,450		20,450		—		—	%
Loss from operations	$	(203,177)	$	(581,277)	$	378,100	65	%

Our Black Oil segment generated revenues of $19,988,122 for the three months ended September 30, 2020, with cost of revenues (exclusive of depreciation and amortization) of $14,687,141, and depreciation and amortization attributable to cost of revenues of $1,041,719. During the three months ended September 30, 2019, these revenues were $32,330,531 with cost of revenues (exclusive of depreciation and amortization) of $27,663,983 and depreciation and amortization attributable to cost of revenues of $1,073,520. Loss from operations improved for the three months ended September 30, 2020, compared to 2019, as a result of improvements in operating expenses through our various facilities as well as by diligent management of our street collections and pricing.

Our Black Oil segment's volume decreased approximately 6% during the three months ended September 30, 2020, compared to the same period in 2019. This decrease was largely due to continued impacts of the shelter in place orders in the locations in which we collect used motor oil as a result of the COVID-19 pandemic, which directly impacted the generation of used oil, which caused a reduction in volumes of feedstock available for use in our refineries. In addition, we ~~had a turn around at our Marrero facility~~were impacted in the Gulf Coast region by weather delays experienced from the various hurricanes in the region during the period. The Heartland facility experienced lower demands for finished products during the three months ended ~~June~~September 30, 2020 ~~than~~compared to the same period in 2019. Volumes collected through our H&H Oil, L.P. (“H&H Oil”)~~(based~~ (based in Houston, Austin and Corpus Christi, Texas) and Heartland (based in Ohio and West Virginia) collection facilities ~~decreased 21%~~increased 5% during the three months ended ~~June~~September 30, 2020, compared to the same

period in 2019. One of our key initiatives continues to be a focus on growing our own volumes of collected material and displacing the third-party oil processed in our facilities. We started to see improvements in our collection volumes at the end of the period.

~~Overall volumes of product sold decreased 33% for~~ During the three months ended ~~June~~September 30, 2020, ~~versus~~our Refining and Marketing cost of revenues (exclusive of depreciation and amortization) were $13,217,757, of which the processing costs for our Refining and Marketing business located at KMTEX were $328,225, and depreciation and amortization attributable to cost of revenues was $121,744. Revenues for the same period ~~in 2019.~~

~~Overall, commodity prices~~ were ~~down for~~$13,501,749. During the three months ended ~~June~~September 30, ~~2020, compared~~2019, our Refining and Marketing cost of revenues (exclusive of depreciation and amortization) were $2,511,314, which included the processing costs at KMTEX of $434,046, and depreciation and amortization attributable to cost of revenues was $147,658. Revenues for the same period in 2019. For example, the average posting (U.S. Gulfcoast Residual Fuel No. 6 3%) for the three months ended June 30, 2020 decreased $36.45 per barrel from a three month average of $61.15 for the three months ended June 30, 2019 to $24.71 per barrel for the three months ended June 30, 2020. The average posting (U.S. Gulfcoast Unleaded 87 Waterborne) for the three months ended June 30, 2020 decreased $43.18 per barrel from a three month average of $78.86 for the three months ended June 30, 2019 to $35.67 per barrel for the three months ended June 30, 2020.were $3,076,454.

Our Refining ~~division~~segment includes the business operations of our Refining and Marketing operations, as well as our newly acquired assets from Crystal. With the acquisition of the Crystal assets, we now operate as a wholesale distributer of motor fuels which include gasoline, blended gasoline and diesel. Revenues in the Refining division were up ~~92%~~339% during the three months ended ~~June~~September 30, 2020, as compared to the same period in 2019 mostly as a result of the added business line. Overall volume for the Refining and Marketing division decreased ~~18%~~21% during the three months ended ~~June~~September 30, 2020, as compared to the same period in 2019. This is a result of a focus on the production of higher quality finished products, which in turn has decreased the amount of volume being produced. In addition, volumes were slightly impacted as a result of 'stay-at-home' orders during the period. Our pygas volumes ~~increased 2%~~decreased 24% for the three months ended ~~June~~September 30, 2020, as compared to the same period in 2019. Our ~~gasoline blendstock and~~ fuel oil cutter volumes decreased ~~100%~~10% for the three months ended ~~June~~September 30, 2020, as compared to the same period in 2019, due to lower volumes of feedstock available from third party facilities in the ~~fact that we are no longer processing gasoline blendstocks in this division~~Gulf coast region as ~~the processing margins were no longer economically feasible. The lower margins were~~ a result of ~~decreases in available feedstock volumes.~~weather delays. We have also had to assess the volume of fuel oil cutterstocks that we manage due to enhanced quality of products being demanded in the marketplace.

Our Recovery segment generated revenues of $3,893,761 for the three months ended September 30, 2020, with cost of revenues (exclusive of depreciation and amortization) of $3,281,786, and depreciation and amortization attributable to cost of revenues of $149,699. During the three months ended September 30, 2019, these revenues were $2,392,274 with cost of revenues (exclusive of depreciation and amortization) of $2,197,019, and depreciation and amortization attributable to cost of revenues of $138,451. Income from operations increased for the three months ended September 30, 2020, compared to 2019, as a result of increased volumes attributable to our Recovery division and margins related thereto, through our various facilities.

Our Recovery ~~division~~segment includes the business operations of Vertex Recovery Management as well as our Group III base oil business. Vertex acts as Penthol C.V.~~’s (“Penthol’s”)~~ of the Netherlands aka Penthol ~~LLC~~LLC's (a Penthol subsidiary in the United States)'s (“Penthol’s”) exclusive agent to provide marketing, sales, and logistical duties of Group III base oil from the United Arab Emirates to the United States. Revenues for this division increased ~~43%~~63% as a result of an increase in volumes during the three months ended ~~June~~September 30, 2020, compared to the same period in 2019. Volumes were up in our metals division during the three months ended ~~June~~September 30, 2020, compared to the same period during 2019, due to certain one-time projects. This division periodically participates in project work that is not ongoing thus we expect to see fluctuations in revenue and gross profit from this division from period to period.

We had a loss from operations of $8,567,699 for the three months ended June 30, 2020, compared to a loss from operations of $667,878 for the three months ended June 30, 2019, an increase of $7,899,821 or 1,183% from the prior year’s three-month period. The increase in loss was due to the overall economic impact of the "stay-at-home" orders that were imposed as a result of the COVID-19 pandemic and the impact those had on the U.S. economy and the Company. We experienced a decrease in gross profit resulting from a decrease in production at our facilities as noted previously and decreased volumes across our business units during the period, as discussed above, all as a result of decreased supply of feedstocks and decreased demand for finished products, due to COVID-19.

We had interest expense of $222,173 for the three months ended June 30, 2020, compared to interest expense of $738,972 for the three months ended June 30, 2019, a decrease in interest expense of $516,799 or 70% from the prior period, due to having a lower balance owed under our line of credit and term loan along with a lower interest rate on the term debt outstanding during the three months ended June 30, 2020, compared to the prior year’s period. The Company received a total of $21.0 million from the Tensile transaction, of which approximately $9.0 million was used to pay down our debt obligations.

We had a $110,965 loss on change in value of derivative liability for the three months ended June 30, 2020, in connection with certain warrants granted in June 2015 and May 2016, as described in greater detail in "~~Note 9. Preferred Stock and Detachable Warrants" to the unaudited consolidated financial statements included herein under "Part I"-"Item 1 Financial Statements~~", compared to a gain on change in the value of our derivative liability of $746,017 in the prior year's period. This change was mainly due to the fluctuation in the market price of our common stock 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 of $8,888,473 for the three months ended June 30, 2020, compared to a net loss of $629,765 for the three months ended June 30, 2019, an increase in net loss of $8,258,708 or 1,311% from the prior period, which was a result of the factors described above. The majority of our net loss for the three months ended June 30, 2020, was attributable to the decrease in volumes sold throughout our business lines, and specifically around our Marrero facility.

~~During the three months ended June 30, 2020 and 2019, the processing costs for our Refining and Marketing division located at KMTEX were $419,818 and $474,134, respectively.~~

RESULTS OF OPERATIONS FOR THE ~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2020 COMPARED TO THE ~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2019

Set forth below are our results of operations for the ~~six~~nine months ended ~~June~~September 30, 2020 as compared to the same period in 2019.


	Nine Months Ended September 30,				$ Change - Favorable (Unfavorable)		% Change - Favorable (Unfavorable)
	2020		2019
Revenues	$	94,961,188	$	120,777,263	$	(25,816,075)	(21)	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	80,221,343		103,732,086		23,510,743		23	%
Depreciation and amortization attributable to costs of revenues	3,731,320		3,965,626		234,306		6	%
Gross Profit	11,008,525		13,079,551		(2,071,026)		(16)	%


Operating expenses:
Selling, general and administrative expenses	18,972,648		17,529,784		(1,442,864)		(8)	%
Depreciation and amortization attributable to operating expenses	1,412,719		1,367,859		(44,860)		(3)	%

Total operating expenses	20,385,367		18,897,643		(1,487,724)		(8)	%
Loss from operations	(9,376,842)		(5,818,092)		(3,558,750)		(61)	%





Other income (expense):
Other Income	101		920,071		(919,970)		(100)	%

Gain (loss) on sale of assets	(124,090)		31,443		(155,533)		(495)	%
Gain (loss) on change in value of derivative liability	1,844,369		331,715		1,512,654		456	%

Interest expense	(796,930)		(2,322,780)		1,525,850		66	%
Total other income (expense)	923,450		(1,039,551)		1,963,001		189	%

Loss before income taxes	(8,453,392)		(6,857,643)		(1,595,749)		(23)	%

Income tax (expense) benefit	—		—		—		—	%

Net loss	(8,453,392)		(6,857,643)		(1,595,749)		(23)	%
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest	190,771		(374,862)		565,633		151	%
Net loss attributable to Vertex Energy, Inc.	$	(8,644,163)	$	(6,482,781)	$	(2,161,382)	(33)	%

Six Months Ended June 30, $ Change - Favorable (Unfavorable) % Change - Favorable (Unfavorable)
2020 2019
Revenues $ 57,577,556
$ 82,978,004
$ (25,400,448 ) (31 )%
Cost of Revenues (exclusive of depreciation shown separately below) 49,034,659
71,359,770
22,325,111
31 %
Gross Profit 8,542,897
11,618,234
(3,075,337 ) (26 )%
Selling, general and administrative expenses 12,731,078
11,376,600
(1,354,478 ) (12 )%
Depreciation and amortization 3,348,008
3,517,903
169,895
5 %
Loss from operations (7,536,189 ) (3,276,269 ) (4,259,920 ) (130 )%
Interest Income 100
1,918
(1,818 ) (95 )%
Gain on sale of assets 12,344
31,443
(19,099 ) (61 )%
Gain (loss) on change in value of derivative liability 1,587,782
(959,077 ) 2,546,859
266 %
Interest expense (562,259 ) (1,496,775 ) 934,516
62 %
Total other income (expense) 1,037,967
(2,422,491 ) 3,460,458
143 %
Loss before income taxes (6,498,222 ) (5,698,760 ) (799,462 ) (14 )%
Income tax (expense) benefit —
—
—
— %
Net loss (6,498,222 ) (5,698,760 ) (799,462 ) (14 )%
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest (289,444 ) (307,760 ) 18,316
6 %
Net loss attributable to Vertex Energy, Inc. $ (6,208,778 ) $ (5,391,000 ) $ (817,778 ) (15 )%

~~Each of our segments’ gross profit (loss) during the six months ended June 30, 2020 and 2019 was as follows:~~

Six Months Ended June 30, $ Change - Favorable (Unfavorable) % Change - Favorable (Unfavorable)
Black Oil Segment 2020 2019
Total revenue $ 41,074,507
$ 70,722,998
$ (29,648,491 ) (42 )%
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 31,914,575
60,710,464
28,795,889
47 %
Gross profit 9,159,932
10,012,534
(852,602 ) (9 )%
Selling, general and administrative expense 10,280,614
9,459,534
(821,080 ) (9 )%
Depreciation and amortization 2,601,752
2,719,354
117,602
4 %
Loss from operations $ (3,722,434 ) $ (2,166,354 ) $ (1,556,080 ) (72 )%

Refining Segment

Total revenue $ 8,807,921
$ 6,136,023
$ 2,671,898
44 %
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 8,554,830
5,256,568
(3,298,262 ) (63 )%
Gross profit 253,091
879,455
(626,364 ) (71 )%
Selling, general and administrative expense 1,170,416
929,791
(240,625 ) (26 )%
Depreciation and amortization 425,932
485,086
59,154
12 %
Loss from operations $ (1,343,257 ) $ (535,422 ) $ (807,835 ) (151 )%

Recovery Segment
Total revenue $ 7,695,128
$ 6,118,983
$ 1,576,145
26 %
Total cost of revenue (exclusive of depreciation and amortization shown separately below) 8,565,254
5,392,738
(3,172,516 ) (59 )%
Gross profit (loss) (870,126 ) 726,245
(1,596,371 ) (220 )%
Selling, general and administrative expense 1,280,048
987,275
(292,773 ) (30 )%
Depreciation and amortization 320,324
313,463
(6,861 ) (2 )%
Loss from operations $ (2,470,498 ) $ (574,493 ) $ (1,896,005 ) (330 )%

Our revenues and cost of revenues are significantly impacted by fluctuations in commodity prices; increases in commodity prices typically result in increases in revenue and cost of ~~revenues.~~revenues (i.e., feedstock acquisition costs). Additionally, we use hedging instruments to manage our exposure to underlying commodity prices. During the nine months ended September 30, 2020, we had a gain of $4.4 million in our hedging instruments, which lowered our cost of goods sold. As demand for used oil feedstock increases, the prices we are required to pay for such feedstock typically increases as well – i.e., the discount pricing to non-used oil shrinks, which increases our acquisition costs. Our gross profit is to a large extent a function of the market discount we are able to obtain in purchasing feedstock, as well as how efficiently management conducts operations. ~~Additionally,~~As demand for used oil feedstock increases, the prices we ~~use hedging instruments~~are required to ~~manage~~pay for such feedstock typically increases as well – i.e., the discount pricing to non-used oil shrinks, which increases our ~~exposure to underlying commodity prices. During the three months ended June 30, 2020, we saw an offset to our feedstock in the amount of $4.4 million, which lowered our~~acquisition costs.

Our cost of ~~goods sold.~~revenues are a function of the ultimate price we are required to pay to acquire feedstocks, how efficient we are in acquiring such feedstocks (which relates to everything from how efficient our collection trucks are in their collection routes to how efficiently we operate our facilities), and the cost of turn-arounds and other maintenance at our facilities.

Total revenues decreased by ~~31%~~21% for the ~~six~~nine months ended ~~June~~September 30, 2020 compared to the same period in 2019, due primarily to lower commodity prices and decreased volumes at our refineries, ~~specifically our Marrero facility,~~ during the ~~six~~nine months ended ~~June~~September 30, 2020,

compared to the prior year's period. Total volume was down 8%5% during the ~~six~~nine months ended ~~June~~September 30, 2020, compared to the same period in 2019. ~~Gross profit decreased by 26%~~

During the nine months ended September 30, 2020, total cost of revenues (exclusive of depreciation and amortization) was $80,221,343, compared to $103,732,086 for the ~~six~~nine months ended ~~June~~September 30, ~~2020, compared to~~2019, a decrease of $23,510,743 or 23% from the ~~six months ended June 30, 2019. This~~prior period. The main reason for the decrease was the result of a decline in commodity prices, which impacted our ~~overall revenue decline due to decreases in finished product prices, and~~feedstock pricing, a decrease in volumes ~~at our Refining and Marketing division,~~throughout the business as well as recent efforts in reducing operating costs at our ~~Marrero facility.~~facilities.

Additionally, our per barrel margin decreased ~~20%~~11% for the ~~six~~nine months ended ~~June~~September 30, 2020, relative to the ~~six~~nine months ended ~~June~~September 30, 2019, due to lower volumes, along with decreases in commodity prices for the finished products we sell during the ~~six~~nine months ended ~~June~~September 30, 2020, compared to the same period during 2019. Our per barrel margin is calculated by dividing the total volume of product sold (in bbls) by total gross profit for the applicable period ($11,008,525 for the 2020 period versus $13,079,551 for the 2019 period). The ~~31%~~23% decrease in cost of revenues (exclusive of depreciation and amortization) for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to the ~~six~~nine months ended ~~June~~September 30, 2019, is mainly a result of the decrease in commodity prices, ~~and~~ lower volumes at our refining facilities during the ~~period.~~period and decreases in operating expenses at our facilities.

~~Our Black Oil division's volume decreased approximately 23%~~Volumes in our street collections were down 2% for the nine months ended September 30, 2020, as compared to the same period in 2019, and we saw a 10% decrease in the discount we were paying for feedstock into our refineries during the ~~six~~period. In addition, we saw an 8% decrease in operating costs (inclusive of depreciation and amortization) on a per barrel basis for the nine months ended ~~June~~September 30, 2020, as compared to the same period in 2019. ~~This decrease~~The cost of the oil collected was ~~largely due~~down 10% and revenue was up 34% from the prior period. The reduction in collection costs is a function of route efficiencies and increased volumes of collections when compared to fixed costs across our collection operations, as well as aggressive price changes on the street. Overall, this provided an additional 15% of gross margin to the ~~overall economic impact of~~business or approximately $2 million, for the ~~'stay-at-home' orders that~~nine-month period ended September 30, 2020. These improvements were ~~imposed as~~

mostly a result of an improvement in logistic costs for the ~~COVID-19 pandemic. Volumes collected through~~period, as well as efficiencies in operations of our ~~H&H Oil~~refineries and ~~Heartland collection facilities decreased 6% during~~reductions in maintenance costs for the ~~six months ended June 30, 2020, compared to the same period in 2019.~~period. One of our key initiatives continues to be a focus on growing our own volumes of collected material and displacing the third-party oil processed in our facilities.

~~Overall volumes~~For the nine months ended September 30, 2020, total depreciation and amortization expense attributable to cost of ~~product sold~~revenues was ~~down 8%~~$3,731,320, compared to $3,965,626 for the ~~six~~three months ended ~~June~~September 30, 2019, a decrease of $234,306 mainly due to some of our assets becoming fully depreciated.

We had gross profit as a percentage of revenue of 11.6% for the nine months ended September 30, 2020, ~~versus~~compared to gross profit as a percentage of revenues of 10.8% for the nine months ended September 30, 2019. The main reason for the improvement was a combination of reduced operating costs along with reduced product pricing on a per barrel basis. In addition, the company was proactive in its risk management of commodity prices through the use of derivative instruments which resulted in a $4.4 million positive impact on gross margins when compared to the same period ~~in 2019. This is an important metric for us to track as it illustrates our reach into the market.~~a year ago.

In addition, commodity prices decreased approximately ~~42%~~35% for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to the same period in 2019. For example, the average posting (U.S. Gulfcoast No. 2 Waterbone) for the ~~six~~nine months ended ~~June~~September 30, 2020, decreased ~~$30.72~~$24.92 per barrel from a ~~six month~~nine-month average of ~~$77.25~~$58.35 for the ~~six~~nine months ended ~~June~~September 30, 2019, to ~~$46.53~~$33.43 per barrel for the ~~six~~nine months ended ~~June~~September 30, 2020.

Overall volume for the Refining and Marketing division decreased 13% during the six months ended June 30, 2020, as compared to the same period in 2019. Our fuel oil cutter volumes decreased 59% for the six months ended June 30, 2020, compared to the same period in 2019. Our pygas volumes increased 3% for the six months ended June 30, 2020, as compared to the same period in 2019. This division experienced a decrease in production of 100% for its gasoline blendstock for the six months ended June 30, 2020, compared to the same period in 2019, due to the fact that we are no longer processing gasoline blendstocks in this division as the processing margins were no longer economically feasible. The lower margins were a result of decreases in available feedstock volumes. We have also had to assess the volume of fuel oil cutterstocks that we manage due to enhanced quality of products being demanded in the marketplace.

Our Recovery division includes the business operations of Vertex Recovery Management. Revenues for this division increased 26% as a result of volumes compared to the same period in 2019. Volumes of petroleum products acquired in our Recovery business were up 25% during the six months ended June 30, 2020, compared to the same period during 2019. This division periodically participates in project work that is not ongoing thus we expect to see fluctuations in revenue and gross profit from this division from period to period.

We had selling, general, and administrative expenses of ~~$12,731,078~~$18,972,648 for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to ~~$11,376,600~~$17,529,784 of selling, general, and administrative expenses for the prior year's period, an increase of ~~$1,354,478~~$1,442,864 or ~~12%~~8%. This increase is primarily due to the additional selling, general and administrative expenses incurred during the period as a result of increased personnel costs, legal expenses, and insurance expenses related to expansion of trucks and facilities through organic growth, as well as increased accounting, legal and consulting expenses related to our Tensile transaction which closed in the first part of the ~~year.~~year, as disclosed in greater detail under “Part I” - “Item 1. Financial Statements” - “Note 14. Share Purchase and Subscription Agreements”.

We had a loss from operations of ~~$7,536,189~~$9,376,842 for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to a loss from operations of ~~$3,276,269~~$5,818,092 for the ~~six~~nine months ended ~~June~~September 30, 2019, an increase of ~~$4,259,920~~$3,558,750 or ~~130%~~61% from the prior year’s ~~six-month~~nine-month period. The ~~increase~~increase was mainly due to a decrease in overall ~~gross profit~~revenues for the ~~six~~nine months ended ~~June~~September 30, 2020, due to the reasons discussed above.

We had interest expense of ~~$562,259~~$796,930 for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to interest expense of ~~$1,496,775~~$2,322,780 for the ~~six~~nine months ended June 30, 2019, a decrease in interest expense of ~~$934,516~~$1,525,850 or ~~62%~~66%, due to a lower amount of

term debt outstanding during the ~~six~~nine months ended ~~June~~September 30, 2020, compared to the prior period. The Company received a total of $21.0 million from the Tensile transaction, of which approximately $9.0 million was used to pay down our debt obligations.

We had other income of $101 for the nine months ended September 30, 2020, compared to $920,071 for the nine months ended September 30, 2019, which was in connection with the Company receiving a payment of $907,500 related to the proceeds of an insurance settlement for a fire that had occurred at the used oil re-refining plant located in Churchill County, Nevada, which we previously rented. The Company previously determined this loan was uncollectible and wrote it off.

We had a ~~gain~~loss on the sale of assets of ~~$12,344~~$124,090 for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to a gain on the sale of assets of $31,443 for the ~~six~~nine months ended ~~June~~September 30, 2019.

We had a ~~$1,587,782~~$1,844,369 gain on change in value of derivative liability for the ~~six~~nine months ended ~~June~~September 30, 2020, in connection with certain warrants granted in June 2015 and May 2016, as described in greater detail in "Note 9. Preferred Stock and Detachable Warrants" to the unaudited consolidated financial statements included herein under "Part I"-"Item 1 Financial Statements", compared to a ~~loss~~gain on change in the value of our derivative liability of ~~$959,077~~$331,715 in the prior year's period. This change was mainly due to a fluctuation in the market price of our common stock.

We had a net loss of ~~$6,498,222~~$8,453,392 for the ~~six~~nine months ended ~~June~~September 30, 2020, compared to a net loss of ~~$5,698,760~~$6,857,643 for the ~~six~~nine months ended ~~June~~September 30, 2019, an increase in net loss of ~~$799,462~~$1,595,749 or ~~14%~~23% from the prior period due to the reasons described above. The majority of our net loss for the ~~six~~nine months ended ~~June~~September 30, 2020, was attributable to the decline in market conditions and commodity prices.

~~During~~Each of our segments’ income (loss) from operations during the ~~six~~nine months ended ~~June~~September 30, 2020 and 2019 was as follows:


	Nine Months Ended September 30,				$ Change - Favorable (Unfavorable)		% Change - Favorable (Unfavorable)
Black Oil Segment	2020		2019
Revenues	$	61,062,628	$	103,053,529	$	(41,990,901)	(41)	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	46,601,716		88,374,446		41,772,730		47	%
Depreciation and amortization attributable to costs of revenues	2,960,699		3,122,664		161,965		5	%
Gross profit	11,500,213		11,556,419		(56,206)		*%

Selling, general and administrative expense	15,180,569		14,500,306		(680,263)		(5)	%
Depreciation and amortization attributable to operating expenses	1,072,877		1,005,315		(67,562)		(7)	%

Loss from operations	$	(4,753,233)	$	(3,949,202)	$	(804,031)	(20)	%






Refining Segment
Revenues	$	22,309,670	$	9,212,477	$	13,097,193	142	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	21,772,587		7,767,882		(14,004,705)		(180)	%
Depreciation and amortization attributable to costs of revenues	341,498		431,948		90,450		21	%
Gross profit	195,585		1,012,647		(817,062)		(81)	%
Selling, general and administrative expense	1,867,027		1,424,572		(442,455)		(31)%
Depreciation and amortization attributable to operating expenses	278,492		301,194		22,702		8%
Loss from operations	$	(1,949,934)	$	(713,119)	$	(1,236,815)	(173)%






Recovery Segment
Revenues	$	11,588,890	$	8,511,257	$	3,077,633	36%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	11,847,040		7,589,758		(4,257,282)		(56)%
Depreciation and amortization attributable to costs of revenues	429,123		411,014		(18,109)		(4)%
Gross profit (loss)	(687,273)		510,485		(1,197,758)		(235)%
Selling, general and administrative expense	1,925,052		1,604,906		(320,146)		(20)%
Depreciation and amortization attributable to operating expenses	61,350		61,350		—		—%
Loss from operations	$	(2,673,675)	$	(1,155,771)	$	(1,517,904)	(131)%

* Less than 1%.

Our Black Oil segment generated revenues of $61,062,628 for the nine months ended September 30, 2020, with cost of revenues (exclusive of depreciation and amortization) of $46,601,716, and depreciation and amortization attributable to cost of revenues of $2,960,699. During the nine months ended September 30, 2019, these revenues were $103,053,529 with cost of revenues (exclusive of depreciation and amortization) of $88,374,446, and depreciation and amortization attributable to cost of revenues of $3,122,664 Income from operations decreased for the nine months ended September 30, 2020, compared to 2019, as a result of lower volumes of processed products at the refineries, and other facilities, as well as an overall decrease in margins throughout the business as a result of lower commodity pricing, offset by decreased operating expenses through our various facilities, along with diligent management of our street collections and pricing.

Our Black Oil segment's volume decreased approximately 18% during the nine months ended September 30, 2020, compared to the same period in 2019. This decrease was largely due to the overall economic impact of the 'stay-at-home' orders that were imposed as a result of the COVID-19 pandemic. Volumes collected through our H&H Oil and Heartland collection facilities decreased 2% during the nine months ended September 30, 2020, compared to the same period in 2019. One of our key initiatives

continues to be a focus on growing our own volumes of collected material and displacing the third-party oil processed in our facilities.

Our Refining segment includes the business operations of our Refining and Marketing operations, as well as our newly acquired assets from Crystal. With the acquisition of the Crystal assets, we now operate as a wholesale distributer of motor fuels which include gasoline, blended gasoline and diesel. During the nine months ended September 30, 2020, our Refining and Marketing cost of revenues (exclusive of depreciation and amortization) were $21,772,587, of which the processing costs for our Refining and Marketing ~~division~~business located at KMTEX were ~~$873,825~~$1,202,050, and ~~$985,179, respectively.~~depreciation and amortization attributable to cost of revenues of $341,498. Revenues for the same period were $22,309,670. During the nine months ended September 30, 2019, our Refining and Marketing cost of revenues (exclusive of depreciation and amortization) were $7,767,882, which included the processing costs at KMTEX of $1,419,225, and depreciation and amortization attributable to cost of revenues of $431,948 .Revenues for the same period were $9,212,477.

Overall volume for the Refining and Marketing division decreased 16% during the nine months ended September 30, 2020, as compared to the same period in 2019. Our fuel oil cutter volumes decreased 46% for the nine months ended September 30, 2020, compared to the same period in 2019. Our pygas volumes decreased 6% for the nine months ended September 30, 2020, as compared to the same period in 2019. The lower margins were a result of decreases in available feedstock volumes. We experienced a large decrease in volumes being received from third party facilities as a result of COVID-19 as well as recent weather delays as a result of the hurricanes in the Gulf which caused some of these facilities to shut-down operations for short periods of time. We have also had to assess the volume of fuel oil cutterstocks that we manage due to enhanced quality of products being demanded in the marketplace.

Our Recovery segment generated revenues of $11,588,890 for the nine months ended September 30, 2020, with cost of revenues (exclusive of depreciation and amortization) of $11,847,040, and depreciation and amortization attributable to cost of revenues of $429,123. During the nine months ended September 30, 2019, these revenues were $8,511,257 with cost of revenues (exclusive of depreciation and amortization) of $7,589,758, and depreciation and amortization attributable to cost of revenues of $411,014. Income from operations decreased for the nine months ended September 30, 2020, compared to 2019, as a result of increased operating expenses through our various facilities.

Our Recovery segment includes the business operations of Vertex Recovery Management as well as our Group III base oil business. Vertex acts as Penthol’s exclusive agent to provide marketing, sales, and logistical duties of Group III base oil from the United Arab Emirates to the United States. Revenues for this division increased 36% as a result of increased volumes compared to the same period in 2019. Volumes of petroleum products acquired in our Recovery business were up 20% during the nine months ended September 30, 2020, compared to the same period during 2019. This segment periodically participates in project work that is not ongoing, thus we expect to see fluctuations in revenue and income before income taxes from period to period. These projects are typically bid related and can take time to line out and get started; however, we believe these are very good projects for the Company and we anticipate more in the upcoming periods.

The Company purchases product/feedstock from third-party collectors as well as internally collected product using its fleet of trucks.Our long-term goal is to collect as much of our product/feedstock as possible as this helps to improve margins and ultimately net income of the Company. The more product/feedstock we can collect with our own fleet and displace third-party purchases improves the overall profitability of the Company through cost reductions, as our internally collected product/feedstock is generally cheaper than product/feedstock we have to purchase from third-parties. In general, the more product/feedstock we are required to acquire from third-parties, the lower our margins. While the breakdown between internally sourced and third-party sourced product/feedstock has no effect on revenue (which is a function of fluctuating product spreads), it does have an effect on cost of revenues, and therefore our profit before corporate selling, general and administrative expenses. Specifically, a higher number of third-party sourced product/feedstock generally results in increases to costs of revenues. Inventories are also affected to a limited extent by collection and production values – the more product we collect, the greater our inventories of product/feedstock, at least until such product/feedstock is processed into end-products. The inventory levels of our end-products are determined based on supply and demand, and how quickly such products can be transported, and not typically dependent on the amount of products/feedstock we source internally or externally.

The following table sets forth the high and low spot prices during the ~~six~~nine months ended ~~June~~September 30, 2020, for our key benchmarks.


2020
Benchmark	High		Date	Low		Date
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon)	$	1.95	January 3	$	0.42	April 27
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon)	$	1.75	January 3	$	0.40	March 23
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel)	$	47.34	January 29	$	12.00	April 21
NYMEX Crude oil (dollars per barrel)	$	63.27	January 6	$	(37.63)	April 20
Reported in Platt's US Marketscan (Gulf Coast)

2020
Benchmark High Date Low Date
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon) $ 1.95
January 3 $ 0.42
April 27
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon) $ 1.75
January 3 $ 0.40
March 23
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel) $ 47.34
January 29 $ 12.00
April 21
NYMEX Crude oil (dollars per barrel) $ 63.27
January 6 $ (37.63 ) April 20
Reported in Platt's US Marketscan (Gulf Coast)

The following table sets forth the high and low spot prices during the ~~six~~nine months ended ~~June~~September 30, 2019, for our key benchmarks.


2019
Benchmark	High		Date	Low		Date
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon)	$	2.01	September 16	$	1.53	January 2
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon)	$	2.08	April 10	$	1.31	January 2
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel)	$	68.54	April 25	$	49.82	January 2
NYMEX Crude oil (dollars per barrel)	$	66.30	April 23	$	46.54	January 2
Reported in Platt's US Marketscan (Gulf Coast)

2019
Benchmark High Date Low Date
U.S. Gulfcoast No. 2 Waterborne (dollars per gallon) $ 2.05
April 23 $ 1.53
January 2
U.S. Gulfcoast Unleaded 87 Waterborne (dollars per gallon) $ 2.08
April 10 $ 1.31
January 2
U.S. Gulfcoast Residual Fuel No. 6 3% (dollars per barrel) $ 68.54
April 25 $ 49.82
January 2
NYMEX Crude oil (dollars per barrel) $ 66.30
April 23 $ 46.54
January 2
Reported in Platt's US Marketscan (Gulf Coast)

We saw an extreme drop in March and April of 2020, in each of the benchmark commodities we track compared to the same period in 2019. The extreme drop in market prices was a result of COVID-19, which led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world imposed regulations in response to efforts to control the spread of COVID-19, such as 'shelter-in-place' orders, quarantines, executive orders and similar restrictions. As a result, the global economy has been marked by significant slowdown and uncertainty, which has led to a precipitous decline in oil prices in response to demand concerns, further exacerbated by the price war among members of the Organization of Petroleum Exporting Countries (“OPEC”) and other non-OPEC producer nations (collectively with OPEC members, “OPEC+”) during the first quarter of 2020 and global storage considerations. Moving ~~forward in~~towards the end of 2020 and into 2021, we anticipate that our results of operations will continue to be significantly impacted by the price of, and demand for oil, COVID-19 and the global response thereto.

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. 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.

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 have 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.

Liquidity and Capital Resources

The success of our current business operations has become dependent on repairs and maintenance to our facilities and our ability to make routine capital expenditures, as well as 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, 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 ~~$125,250,538~~$125,153,280 as of ~~June~~September 30, 2020, compared to $120,759,919 at December 31, 2019. The increase was mainly due to the generation of additional liquidity from the closing of the Tensile transaction relating to Heartland SPV as discussed above, during the ~~six~~nine months ended ~~June~~September 30, 2020.

We had total current liabilities of ~~$21,492,029~~$23,391,460 as of ~~June~~September 30, 2020, compared to $24,797,299 at December 31, 2019. We had total liabilities of ~~$59,151,607~~$61,069,930 as of ~~June~~September 30, 2020, compared to total liabilities of $69,511,546 as of December 31, 2019. The decrease in current liabilities and total liabilities was mainly in connection with the generation of additional liquidity from the closing of the Heartland SPV transaction during the ~~six~~nine months ended ~~June~~September 30, ~~2020.~~2020, and the reduction of debt associated therewith.

We had working capital of ~~$11,837,472~~$9,534,250 as of ~~June~~September 30, 2020, compared to working capital of $2,609,609 as of December 31, 2019. The increase in working capital from December 31, 2019 to ~~June~~September 30, 2020 is mainly due to the generation of additional liquidity from the closing of the Heartland SPV transaction during the ~~six~~nine months ended ~~June~~September 30, 2020.

The Company received a total of $21.0 million from the Tensile transaction, of which approximately $9.0 million was used to pay down our debt obligations, approximately $7.0 million is included in cash as of ~~June~~September 30, 2020, and the remaining balance was used to fund operations.

Our future operating cash flows will vary based on a number of factors, many of which are beyond our control, including 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 capital expenditures related to new TCEP facilities in the future (provided that none are currently planned).

Given the ongoing COVID-19 pandemic, challenging market conditions and recent market events resulting in industry-wide spending cuts, we continue to remain focused on maintaining a strong balance sheet and adequate liquidity. Over the near term, we plan to reduce, defer or cancel certain planned capital expenditures and reduce our overall cost structures commensurate with our expected level of activities. We believe that our cash on hand, internally generated cash flows and availability under the Revolving Credit Facility will be sufficient to fund our operations and service our debt in the near term. 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. Current global and market conditions have increased the potential for that difficulty.

The Company's outstanding debt facilities as of ~~June~~September 30, 2020 and December 31, 2019 are summarized as follows:


Creditor	Loan Type	Origination Date	Maturity Date	Loan Amount		Balance on June 30, 2020		Balance on December 31, 2019			Creditor	Loan Type	Origination Date	Maturity Date	Loan Amount		Balance on September 30, 2020		Balance on December 31, 2019
Encina Business Credit, LLC	Term Loan	February 1, 2017	February 1, 2022	$	20,000,000	$	5,883,000	$	13,333,000		Encina Business Credit, LLC	Term Loan	February 1, 2017	February 1, 2022	$	20,000,000	$	5,658,000	$	13,333,000
Encina Business Credit SPV, LLC	Revolving Note	February 1, 2017	February 1, 2022	$	10,000,000	—		3,276,230			Encina Business Credit SPV, LLC	Revolving Note	February 1, 2017	February 1, 2022	$	10,000,000	—		3,276,230
Encina Business Credit, LLC											Encina Business Credit, LLC	Capex Loan	August 7, 2020	February 1, 2022	$	2,000,000	1,250,617		—
Wells Fargo Equipment Lease-Ohio	Finance Lease	April-May, 2019	April-May, 2024	$	621,000	494,573		551,260			Wells Fargo Equipment Lease-Ohio	Finance Lease	April-May, 2019	April-May, 2024	$	621,000	465,678		551,260
AVT Equipment Lease-Ohio	Finance Lease	April 2, 2020	April 2, 2023	$	337,155	313,272		—			AVT Equipment Lease-Ohio	Finance Lease	April 2, 2020	April 2, 2023	$	337,155	410,928		—
AVT Equipment Lease-HH	Finance Lease	May 22, 2020	May 22, 2023	$	551,609	520,191		—			AVT Equipment Lease-HH	Finance Lease	May 22, 2020	May 22, 2023	$	551,609	485,745		—
John Deere Note	Note	May 27, 2020	June 24, 2024	$	152,643	149,613		—			John Deere Note	Note	May 27, 2020	June 24, 2024	$	152,643	140,487		—
Tetra Capital Lease	Finance Lease	May, 2018	May, 2022	$	419,690	218,896		264,014			Tetra Capital Lease	Finance Lease	May, 2018	May, 2022	$	419,690	195,761		264,014
Well Fargo Equipment Lease-VRM LA	Finance Lease	March, 2018	March, 2021	$	30,408	7,135		12,341			Well Fargo Equipment Lease-VRM LA	Finance Lease	March, 2018	March, 2021	$	30,408	4,485		12,341
Texas Citizens Bank	PPP Loan	May 5, 2020	April 28, 2022	$	4,222,000	4,222,000		—			Texas Citizens Bank	PPP Loan	May 5, 2020	April 28, 2022	$	4,222,000	4,222,000		—
Various institutions	Insurance premiums financed	Various	< 1 year	$	2,902,428	—		1,165,172			Various institutions	Insurance premiums financed	Various	< 1 year	$	2,902,428	1,893,668		1,165,172
Total						11,808,680		18,602,017			Total						14,727,369		18,602,017
Deferred finance costs, net						—		(47,826		)
Deferred finance costs											Deferred finance costs						—		(47,826)
Total, net of deferred finance costs						$	11,808,680	$	18,554,191		Total, net of deferred finance costs						$	14,727,369	$	18,554,191

Future contractual maturities of notes payable are summarized as follows:


Creditor	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter		Creditor	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter
Encina Business Credit, LLC	$	900,000	$	4,983,000	$	—	$	—	$	—	$	—	Encina Business Credit, LLC	$	900,000	$	4,758,000	$	—	$	—	$	—	$	—
Encina Business Credit SPV, LLC	—		—		—		—		—		—		Encina Business Credit SPV, LLC	—		—		—		—		—		—
Encina Business Credit, LLC													Encina Business Credit, LLC	158,966		1,091,651		—		—		—		—
John Deere Note	36,845		37,759		38,695		36,313		—		—		John Deere Note	37,071		37,991		38,934		26,491		—		—
Well Fargo Equipment Lease- Ohio	117,834		124,039		130,574		122,127		—		—		Well Fargo Equipment Lease- Ohio	119,356		125,643		132,261		88,418		—		—
AVT Equipment Lease-Ohio	88,689		96,512		128,071		—		—		—		AVT Equipment Lease-Ohio	124,308		135,272		151,348		—		—		—
AVT Equipment Lease-HH	142,258		154,805		223,128		—		—		—		AVT Equipment Lease-HH	145,296		158,111		182,338		—		—		—
Tetra Capital Lease	94,920		123,976		—		—		—		—		Tetra Capital Lease	96,530		99,231		—		—		—		—
Well Fargo Equipment Lease- VRM LA	7,135		—		—		—		—		—		Well Fargo Equipment Lease- VRM LA	4,485		—		—		—		—		—
Texas Citizens Bank	1,877,461		2,344,539		—		—		—		—		Texas Citizens Bank	1,877,461		2,344,539		—		—		—		—
Various institutions	—		—		—		—		—		—		Various institutions	1,893,668		—		—		—		—		—
Totals	$	3,265,142	$	7,864,630	$	520,468	$	158,440	$	—	$	—	Totals	$	5,357,141	$	8,750,438	$	504,881	$	114,909	$	—	$	—

Need for additional funding

Our re-refining business will require significant capital to design and construct any new facilities. The facility infrastructure would be an additional capitalized expenditure to these process costs and would depend on the location and site specifics of the facility.

Additionally, as part of our ongoing efforts to maintain a capital structure that is closely aligned with what we believe to be the potential of our business and goals for future growth, which is subject to cyclical changes in commodity prices, we will be exploring additional sources of external liquidity. The receptiveness of the capital markets to an offering of debt or equities cannot be assured and may be negatively impacted by, among other things, debt maturities, current market conditions, and potential stockholder dilution. The sale of additional securities, if undertaken by us and if accomplished, may result in dilution to our shareholders. However, such future financing may not be available in amounts or on terms acceptable to us, or at all.

In addition to the above, we may also seek to acquire additional businesses or assets. In addition, the Company could consider selling assets if a more strategic acquisition presents itself. Finally, in the event we deem such transaction in our best interest, we may enter into a business combination or similar transaction in the future.

We will also need additional capital in the future to redeem our Series B Preferred Stock and Series B1 Preferred Stock, which had a required redemption date of June 24, 2020, provided that, as discussed below under “Risk Factors” - “We do not anticipate redeeming our Series B and B1 Preferred Stock in the near future.”, we are not contractually, or legally, able to redeem such stock and do not anticipate having sufficient cash on hand to complete such redemption in the near term. Because such preferred stock was not redeemed on June 24, 2020, the preferred stock accrues a 10% per annum dividend (payable in-kind at the option of the Company), until such preferred stock is redeemed or converted into common stock.

There is currently only a limited market for our common stock, and as such, we anticipate that such market will be illiquid, sporadic and 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; and~~


~~(4)~~	~~the number of shares in our public float.~~

(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; and

(4)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, at present, we have a limited number of shares in our public float, and as a result, there could be extreme fluctuations in the price of our common stock.

We believe that our stock prices (bid, ask and closing prices) may not relate to the actual value of our company, and may not reflect the actual value 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, industry information, and those business valuation methods commonly used to value private companies.

Cash flows for the ~~six~~nine months ended ~~June~~September 30, 2020 compared to the ~~six~~nine months ended ~~June~~September 30, 2019:


	Nine Months Ended September 30,
	2020		2019
Beginning cash, cash equivalents and restricted cash	$	4,199,825	$	2,849,831
Net cash provided by (used in):
Operating activities	1,351,184		(3,058,106)
Investing activities	(6,005,620)		(3,200,700)
Financing activities	16,107,716		5,812,788
Net increase (decrease) in cash, cash equivalents and restricted cash	11,453,280		(446,018)
Ending cash, cash equivalents and restricted cash	$	15,653,105	$	2,403,813

Six Months Ended June 30,
2020 2019
Beginning cash, cash equivalents and restricted cash $ 4,199,825
$ 2,849,831
Net cash provided by (used in):
Operating activities 3,712,167
543,971
Investing activities (3,375,454 ) (2,332,753 )
Financing activities 13,317,899
(462,823 )
Net increase (decrease) in cash, cash equivalents and restricted cash 13,654,612
(2,251,605 )
Ending cash, cash equivalents and restricted cash $ 17,854,437
$ 598,226

Net cash provided by operating activities was ~~$3,712,167~~$1,351,184 for the ~~six~~nine months ended ~~June~~September 30, 2020, as compared to net cash ~~provided by~~used in operating activities of ~~$543,971~~$3,058,106 during the corresponding period in 2019. Our primary sources of liquidity are cash flows from our operations and the availability to borrow funds under our credit and loan facilities. The primary reason for the increase in cash provided by operating activities for the ~~six~~nine month period ended ~~June~~September 30, 2020, compared to the same period in 2019, was the fluctuation in market and commodity prices during the ~~six~~nine months ended ~~June~~September 30, 2020, ~~, $4,986,003~~a decrease of ~~decrease~~$4,952,388 in accounts receivable ~~$3,711,239 of decrease~~and $3,939,674 in inventory, and ~~$4,781,183~~$5,484,734 of net cash settlements on commodity derivatives.

Investing activities used cash of ~~$3,375,454~~$6,005,620 for the ~~six~~nine months ended ~~June~~September 30, 2020, as compared to having used ~~$2,332,753~~$3,200,700 of cash during the corresponding period in 2019, due mainly to the purchase of fixed assets and the acquisition of Crystal.

Financing activities provided cash of ~~$13,317,899~~$16,107,716 for the ~~six~~nine months ended ~~June~~September 30, 2020, as compared to ~~using~~providing cash of ~~$462,823~~$5,812,788 during the corresponding period in 2019. Financing activities for the ~~six~~nine months ended ~~June~~September 30, 2020 were comprised of contributions from the Tensile transaction of $21.0 million, offset by approximately ~~$8.6~~$9.7 million used to pay down our long-term debt,~~$4.2~~ $4.2 million of proceeds from our PPP ~~note,~~loan (described in greater detail under “Note 6. Line of Credit and Long-Term Debt” to the unaudited financial statements included herein, under “Loan Agreements”), and $3.3 million of payments on our line of credit. Financing activities for the ~~six~~nine months ended ~~June~~September 30, 2019 were comprised of note proceeds of approximately ~~$0.2~~$2.8 million, offset by approximately ~~$1.5~~$3.5 million used to pay down our long-term debt, and ~~$1.2~~$1.5 million of proceeds on our line of credit.

More information regarding our outstanding line of credits, promissory notes and long-term debt can be found under “Note 6. Line of Credit and Long-Term 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, goodwill, intangible assets, long-lived assets valuation, and legal matters. Actual results may differ from these estimates. (See “Part I” - “Item 1. Financial Statements” - “Note 1. Basis of Presentation and Nature of Operations” to the financial statements included herein).

Impairment of long-lived assets

The Company evaluates the carrying value and recoverability of its long-lived assets when circumstances warrant such evaluation by applying the provisions of the FASB ASC regarding long-lived assets. It requires that long-lived assets be 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 at ~~June~~September 30, 2020.

Leases

In February 2016, the FASB issued Accounting Standards Update No. 2016-02 (ASU 2016-02), Leases (Topic 842). ASU 2016-02 requires companies to recognize lease assets and lease liabilities on the balance sheet and disclose key information about leasing arrangements. We adopted ASU No. 2016-02, Leases (Topic 842) effective January 1, 2019 and ~~will not recast comparative periods in transition to the new standard. In addition, we~~ elected certain practical expedients which permit us to not reassess whether existing contracts are or contain leases, to not reassess the lease classification of any existing leases, to not reassess initial direct costs for any existing leases, and to not separate lease and nonlease components for all classes of underlying assets. We also made an accounting policy election to keep leases with an initial term of 12 months or less off of the balance sheet for all classes of underlying assets. Adoption of the new standard resulted in an increase in the Company’s assets and liabilities of approximately $37.8 million. The ASU did not have an impact on our consolidated results of operations or cash flows. Additional information and disclosures required by this new standard are contained in “Part I” - “Item 1. Financial Statements” - "Note 13. Leases".

Preferred Stock Classification

A mandatorily redeemable financial instrument shall be classified as a liability unless the redemption is required to occur only upon the liquidation or termination of the reporting entity. A financial instrument issued in the form of shares is mandatorily redeemable if it embodies an unconditional obligation requiring the issuer to redeem the instrument by transferring its assets at a specified or determinable date (or dates) or upon an event certain to occur. A financial instrument that embodies a conditional obligation to redeem the instrument by transferring assets upon an event not certain to occur becomes mandatorily redeemable-and, therefore, becomes a liability-if that event occurs, the condition is resolved, or the event becomes certain to occur. The Series B Preferred Stock requires the Company to redeem such preferred stock on the fifth anniversary of the issuance of the Series B Preferred Stock and the Series B1 Preferred Stock requires the Company to redeem such preferred stock on the same date as the Series B Preferred Stock, in the event such redemptions are allowed pursuant to the Company’s senior credit facilities and applicable law. SEC reporting requirements provide that any possible redemption outside of the control of the Company requires the preferred stock to be classified outside of permanent equity.

Redeemable Noncontrolling Interest

As more fully described in "Note 14. Share Purchase and Subscription Agreements", the Company is party to put/call option agreements with the holder of MG SPV’s and Heartland SPV's non-controlling interests. The put options permit 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. Per the agreements, the cash purchase price for such redeemed Class B Units (MG SPV) and Class A Units (Heartland SPV) is the greater of (y) the fair market value of such units (without discount for illiquidity, minority status or otherwise) as determined by a qualified third party agreed to in writing by a majority of the holders seeking an MG SPV Redemption and Heartland SPV Redemption and Vertex Operating (provided that Vertex Operating still owns Class A Units (as to MG SPV) or Class B Units (as to Heartland SPV) on such date, as applicable) and (z) the original per-unit price for such Class B Units/Class A Units plus any unpaid Class A/Class B preference. The preference is defined as the greater of (A) the aggregate unpaid “Class B/Class A Yield” (equal to an annual return of 22.5% per annum) and (B) an amount equal to fifty percent (50%) of the aggregate capital invested by the Class B/Class A Unit holders. The agreements also permit the Company to acquire the non-controlling interest from the holders thereof upon certain events. 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 has classified the MG SPV and Heartland SPV non-controlling interests between the liabilities and equity sections of the accompanying ~~June~~September 30, 2020 and December 31, 2019 consolidated balance sheets (provided that the Heartland SPV interest was not outstanding until January 2020). 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 will 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 will become redeemable. The Company has 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 income in the consolidated financial statements. Rather, such adjustments are treated as equity transactions.

Variable Interest Entities

The Company ~~accounts for the~~has investments ~~it makes~~ in certain legal entities in which equity investors do not have (1) sufficient equity at risk for the legal entity to finance its activities without additional subordinated financial support, (2) as a group, (the holders of the equity investment at risk), do not have either the power, through voting or similar rights, to direct the activities of the legal entity that most significantly impacts the entity’s economic performance, or (3) the obligation to absorb the expected losses of the legal entity or the right to receive expected residual returns of the legal entity. These certain legal entities are referred to as “variable interest entities” or “VIEs.”

significantly affect the VIE’s economic performance and the obligation to absorb the losses of, or right to receive benefits from, the VIE that could be potentially significant to the VIE. On a quarterly basis, the Company reassesses whether it has a controlling financial interest in any investments it has in these certain legal entities.

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.

Item 3. Quantitative and Qualitative Disclosures about Market 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 LIBOR or Prime as the base rate.

At ~~June~~September 30, 2020, the Company had approximately ~~$5.8~~$6.9 million of variable-rate term debt outstanding. At this borrowing level, a hypothetical relative increase of 10% in interest rates would have an unfavorable but insignificant impact on the Company’s pre-tax earnings and cash flows. The primary interest rate exposure on variable-rate debt is based on the LIBOR rate ~~(1.17%~~(1.55% at ~~June~~September 30, 2020) plus 6.50% per year.

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.

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 ~~June~~September 30, 2020, 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, 2019 (as described in greater detail in our annual report on Form 10-K for the year ended December 31, 2019), 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 Weakness

We believe the remedial measures described in Part II, ~~“Item~~“Item 9A, Controls and ~~Procedures”~~Procedures” in our Annual Report on Form 10-K for the year ended December 31, 2019, and others that may be implemented, will remediate this material weakness. However, this material weakness 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. We expect this to occur by the end of fiscal 2020.

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. There were no changes in our internal control over financial reporting that occurred during the period covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. As a result of the COVID-19 pandemic, certain employees of the Company began working remotely in March 2020 but these changes to the working environment did not have a material effect on the Company’s internal control over financial reporting. We will continue to monitor the impact of COVID-19 on 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 3. Concentrations, Significant Customers, 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

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, 2019, filed with the Commission on March 4, 2020 (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 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, 2019, under “Risk Factors”, ~~and~~which risk factors from the Form 10-K are incorporated by reference in this Item 1A. Risk Factors, subject to updates to such risk factors as provided below, 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.

The risk factor entitled “The price of oil and fluctuations in oil prices may have a negative effect on our results of operations.” from the Form 10-K is replaced and superseded by the following:

The price of oil and fluctuations in oil prices may have a negative effect on our results of operations.

The majority of our operations are associated with collecting used oil, re-refining or otherwise processing a portion of such used oil and then selling both such re-refined/processed oil and the excess feedstock oil which we do not currently have the capacity to re-refine, to other customers. The prices at which we sell our re-refined/processed oil and extra feedstock are affected by changes in the reported spot market prices of oil. If applicable rates increase or decrease, we typically will charge a higher or lower corresponding price for our re-refined/processed oil and excess feedstock. The price at which we sell our re-refined/processed oil and excess feedstock is affected by changes in certain indices measuring changes in the price of heavy fuel oil, with increases and decreases in the indices typically translating into a higher or lower price for our re-refined/processed oil and excess feedstock. The cost to collect used oil, including the amounts we pay to obtain a portion of our used oil and therefore ability to collect necessary volumes as well as the fuel costs of our oil collection fleet, typically also increases or decreases when the relevant indices increase or decrease. However, even though the prices we can charge for our re-refined/processed oil and excess feedstock and the costs to collect and re-refine/processed used oil typically increase and decrease together, there is no assurance that when our costs to collect and re-refine/process used oil increase we will be able to increase the prices we charge for our re-refined/processed oil excess feedstock to cover such increased costs, or that our costs to collect and re-refine/process used oil will decline when the prices we can charge for re-refined/processed oil declines. These risks are exacerbated when there are rapid fluctuations in these oil indices and when there is lower pricing due to decreased demand, which have both occurred recently as a result of the economic uncertainty caused by the COVID-19 outbreak. These risks are also greater when there is an increased supply of oil from the Organization of the Petroleum Exporting Countries (OPEC), which has also recently occurred.

In addition to the above, the value of re-refined and processed used oil is usually greater the more expensive oil is. As the price of oil decreases so does the spread between re-refined/processed used oil and refined oil and extremely low oil prices, such as those which we are currently experiencing, customers will often be willing to pay the slightly higher cost of refined oil rather than paying for re-refined/processed oil. Furthermore, as the price of oil decreases, the price we can charge for re-refined/processed oil decreases, and while in general the cost of our feedstocks decreases, the prices required to process such feedstock and operate our plans remain fixed. As such, in the event the price of oil remains low and we are not able to increase the prices we charge for re-refined/processed oil, our margins will likely decrease and it may not become economically feasible to continue to operate our facilities. In the event that were to occur, we may be forced to shut down our facilities.

The occurrence of any of the events described above could have a material adverse effect on our results of operations and could in turn cause the value of our securities to decline.

The risk factor entitled “Our TCEP only makes commercial sense when the market price for oil is high.”, from the Form 10-K is replaced and superseded by the following:

Our TCEP only makes commercial sense when the market price for oil is high.

From the third quarter of 2015 to the fourth quarter of 2019, we utilized TCEP to pre-treat our used motor oil feedstocks prior to shipping to our facility in Marrero, Louisiana; however, from the fourth quarter of 2019 to the first quarter of 2020, we once again used TCEP for the purpose of producing finished cutterstock. Starting in the first quarter of 2020, with

declining oil prices, such use of TCEP for its originally intended purpose became non-economical. When oil prices are low (such as they are now) we anticipate using TCEP only to pre-treat our used motor oil feedstocks prior to shipping them to our facility in Marrero, Louisiana, versus for its original intended purpose, producing finished cutterstock. This is because when oil prices are low, the

fixed costs of TCEP are greater than the price we can charge for re-refined oil we can create using such technology. If oil prices continue to remain low in the future it may be inefficient to operate TCEP to re-refine oil, which may have a negative effect on our cash flows and results of operations. Since the first quarter of 2020, we have used TCEP solely to pre-treat our used motor oil feedstocks prior to shipping to our facility in Marrero, Louisiana.

The risk factor entitled “Worsening economic conditions and trends and downturns in the business cycles of the industries we serve and which provide services to us would impact our business and operating results.”, from the Form 10-K is replaced and superseded by the following:

Worsening economic conditions and trends and downturns in the business cycles of the industries we serve and which provide services to us would 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. 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 may also be 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. Additionally, as a result of the impact of the COVID-19 outbreak, some of our feedstock suppliers have permanently or temporarily closed their businesses, limited our access to their businesses, and/or have experienced a decreased demand for services. As a result of the above, and due to ‘stay-at-home’ and other social distancing orders, as well as the decline in U.S. travel caused by COVID-19, we have seen a significant decline in the volume of feedstocks (specifically used oil) that we have been able to collect, and therefore process through our facilities. Any similar decline in the price of oil and/or the economy in general, including those which we are currently experiencing, will likely create a further decrease in the supply of feedstock, prevent us from maintaining our required levels of output and/or force us to seek additional suppliers of feedstock, who may charge more than our current suppliers, and therefore adversely affect our results of operations. We anticipate the above being exacerbated by the further ~~the~~ uncertainty regarding the COVID-19 ~~outbreak continues.~~outbreak.A prolonged economic slowdown, period of social quarantine (imposed by the government or otherwise), or a prolonged period of decreased travel due to COVID-19 or the responses thereto, will likely continue to have a material negative adverse impact on our ability to produce products, and consequently our revenues and results of operations.

The risk factor entitled “Disruptions in the supply of feedstock and/or increases in the cost of feedstock could have an adverse effect on our business.”, from the Form 10-K is replaced and superseded by the following:

Disruptions in the supply of feedstock and/or increases in the cost of feedstock could have an adverse effect on our business.

We depend on the continuing availability of raw materials, including feedstock, to remain in production. Additionally, we depend on the price of such raw materials, including feedstock being reasonable to us in relation to the prices we are able to receive for our final products. As a result of the impact of the COVID-19 outbreak, some of our feedstock suppliers have permanently or temporarily closed their businesses, limited our access to their businesses, and/or have experienced a decreased demand for services. As a result of the above, and due to ‘stay-at-home’ and other social distancing orders, as well as the decline in U.S. travel caused by COVID-19, we have seen a significant decline in the volume of feedstocks (specifically used oil) that we have been able to collect, and therefore process through our facilities. A ~~serious~~continued disruption in supply of feedstock, such as we are currently experiencing, or significant increases in the prices of feedstock, could significantly reduce the availability of raw materials at our plants and which are available to be processed by our third-party processors. Additionally, increases in production costs could have a material adverse effect on our business, results of operations and financial condition.

The risk factor entitled “Our reliance on small business customers causes us to be subject to the trends and downturns that impact small businesses, which could adversely affect our business.”, from the Form 10-K is replaced and superseded by the following:

Our reliance on small business customers causes us to be subject to the trends and downturns that impact small businesses, which could adversely affect our business.

Our feedstock customer base is primarily composed of small businesses in the vehicle repair and manufacturing industries. The high concentration of our feedstock customers that are small businesses exposes us to significant risk. Small businesses start, close, relocate, and are acquired and sold frequently. Small businesses have also been more significantly affected by decreased demand caused by COVID-19, the reduction in vehicle miles driven, and therefore, the reduction in the demand for oil change and vehicle repair services, as a result of ‘work-from-home’ mandates and recommendations and the overall decline in economic activity caused by COVID-19 and the efforts to curtail the spread of the virus. In addition, small businesses are often impacted more significantly by economic recessions when compared to larger businesses. As a result, we must continually identify new feedstock customers and expand our business with existing feedstock customers in order to sustain our growth and feedstock supply. If we experience a rise in levels of customer turnover, it may have a negative impact on the profitability of our business. We have also seen that our suppliers have been significantly impacted, both in their ability to operate, and the amount of feedstock they produce, due to the governmental responses to COVID-19 including stay-at-home orders and the reduced demand for their services relating thereto.

In the event these decreases in feedstock continue, it will have a material adverse effect on our year-over-year results of operations, our ability to generate higher quality products for sale, the amount of feedstocks we are required to purchase from third parties, the demand for such third-party feedstocks, and therefore the price we are required to pay for such third party feedstocks, the amount of feedstock we have available for use in finished products, and consequently, our net income.

The risk factor entitled “The covenants in our credit and loan agreements restrict our ability to operate our business and might lead to a default under our credit agreements.”, from the Form 10-K is replaced and superseded by the following:

The covenants in our credit and loan agreements restrict our ability to operate our business and might lead to a default under our credit agreements.

Our debt agreements limit, among other things, our ability to:

•incur or guarantee additional indebtedness;

•create liens;

•make payments to junior creditors;

•make investments;

•sell material assets;

•affect fundamental changes in our structure;

•make certain acquisitions;

•sell interests in our subsidiaries;

•consolidate or merge with or into other companies or transfer all or substantially all of our assets;

•redeem or repurchase shares of our stock, including our outstanding Series B and B1 Preferred Stock; and

•engage in transactions with affiliates.

Our credit agreements contain customary representations, warranties and requirements for the Company to indemnify the lenders and their affiliates. Our credit agreements also include various covenants (positive and negative) binding upon the Company, including, prohibiting us from undertaking acquisitions or dispositions unless they meet the criteria set forth in such credit agreements, not incurring any capital expenditures in amount exceeding $3 million in any fiscal year that the credit agreements are in place, and requiring us to maintain at least $2.0 million of borrowing availability under our revolving credit agreement at any time.

As a result of these 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. Our credit and loan agreements require, and our future credit facilities and loan agreements may require, us to maintain certain financial ratios and satisfy certain other financial condition tests. Our ability to meet these financial ratios and tests can be affected by events beyond our control, and we may not be able to meet those tests. The breach of any of these covenants could result in a default under our credit agreements or future credit facilities. Upon the occurrence of an event of default, the lenders could elect to declare all amounts outstanding under such credit agreements, including accrued interest or other obligations, to be immediately due and payable. If amounts outstanding under such credit agreements were to be accelerated, our assets might not be sufficient to repay in full that indebtedness and our other indebtedness.

Our credit agreements and loan agreements also contain cross-default and cross-acceleration provisions. Under these provisions, a default or acceleration under one instrument governing our debt may 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.

The risk factor entitled “We do not anticipate redeeming our Series B and B1 Preferred Stock on June 24, 2020, notwithstanding the fact that our Series B and B1 Preferred Stock is required to be redeemed on June 24, 2020, subject to the terms of the Certificate of Designations of such Preferred Stock and applicable law, and the dividend rate of such Preferred Stock increases to 10% per annum in the event the Company is unable to complete such redemptions.”, from the Form 10-K is replaced and superseded by the following:

We do not anticipate redeeming our Series B and B1 Preferred Stock in the near future.

We were required to redeem any non-converted shares of (a) Series B Preferred Stock, which remained outstanding on June 24, 2020, at the rate of $3.10 per share (or ~~$12.4~~$12.7 million in aggregate as of the date of this filing); and (b) Series B1 Preferred Stock, which remained outstanding on June 24, 2020, at the rate of $1.56 per share (or ~~$11.3~~$11.5 million in aggregate as of the date of this filing), subject to the terms of the certificate of designations of such Series B and B1 Preferred Stock and applicable law. The certificate of designations of the Series B and B1 Preferred Stock provide that the mandatory redemption date of the Series B and B1 Preferred Stock is automatically extended in the event that the terms of the Company’s senior credit facility (i.e., the Credit Agreements), prohibit the redemption of such Series B and B1 Preferred Stock and because the Credit Agreements prohibit such redemption, the redemption date of the Series B and B1 Preferred Stock has automatically been extended past June 24, 2020, until such date, if ever, as the Company’s senior credit facilities (and any facilities which replace or refinance the Credit Agreements) no longer prohibit such redemptions. Effective on June 24, 2020, the dividend rate of such Series B and B1 Preferred Stock ~~the dividend rate of such preferred stock~~ increased to 10% per annum. Notwithstanding the dividend rate increase, because the interest is payable in-kind (or in registered shares of common stock, if allowed under the applicable certificate of designation of the preferred stock, at the option of the Company), the increase in dividend rate and the additional shares of Series B and B1 Preferred Stock and/or common stock due to the holders of such Series B and B1 Preferred Stock in connection therewith, may cause significant dilution to existing shareholders.

Notwithstanding the above, pursuant to the Nevada Revised Statutes, no redemption of the Series B or B1 Preferred Stock is allowed unless such redemption would not result in the Company (i) having less (a) assets than its (b) total liabilities plus the liquidation rights of any preferred stock or other preferred right holders and/or (ii) being unable to pay its debts as they become due after such redemption. Furthermore, the Series B and B1 Preferred Stock designations currently only provide for an ‘all or nothing’ type redemption, and as such, regardless of the compliance of the redemptions of the Series B and B1 Preferred Stock with the terms of the Company’s senior credit agreements, the Company anticipates being legally unable to redeem the Series B and B1 Preferred Stock due to the requirements of Nevada law and the ‘all or nothing’ requirement of such preferred stock until such time as the Company has sufficient cash on hand to pay the entire liquidation preference of the Series B and B1 Preferred Stock ($~~23.6~~24.3 million) and has sufficient cash left over to pay its debts as they become due.

Due to the above, the holders of the Series B and B1 Preferred Stock may be forced to hold such Series B and B1 Preferred Stock indefinitely and the Company may never be in a position to contractually or legally redeem the Series B and B1

Preferred Stock. The only rights of the holders of the Series B and B1 Preferred Stock in the event the Company is unable to redeem such preferred stock due to the reasons above would be to continue to hold such preferred stock (with dividends accruing at 10% per annum), sell such preferred stock in private transactions, or convert such preferred stock into common stock pursuant to the terms thereof.

Finally, notwithstanding the prohibitions on redemptions described above, the Company does not currently have the funds required to redeem such Series B and B1 Preferred Stock (i.e., an aggregate of ~~$23.6~~$24.2 million), and does not anticipate having such funds in the near term, if at all. Consequently, the Company does not anticipate redeeming the Series B and B1 Preferred Stock at any time in the foreseeable future.

The risk factor entitled “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.”, from the Form 10-K is replaced and superseded by the following:

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, and those operated by third parties on which we rely, including, but not limited to KMTEX, 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, 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. In the event any of our facilities or those of third parties on which we rely are offline for an extended period, 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. As of October 26, 2020, the facility was back up and running and in the process of filing a claim with our insurance company. The Company believes that it maintains adequate insurance coverage.

The following are new risk factors which supplement the risk factors included in the Form 10-K:

Epidemics, including the recent outbreak of the COVID-19 coronavirus, and other crises have, and will in the future, negatively impact our business and results of operations.

Our revenues and cost of revenues are significantly impacted by fluctuations in commodity prices; decreases in commodity prices typically result in decreases in revenue and cost of revenues. Our ~~gross profit~~revenue is to a large extent a function of the market discount we are able to obtain in purchasing feedstock, as well as how efficiently management conducts operations. Additionally, our sales volumes, and as a result, our results of operations and cash flows, significantly depend on the U.S. and to a lesser extent, worldwide demand for oil and used oil. As a result, pandemics, epidemics, and public health crises, which effect the U.S. and the world as a whole, and which result in travel disruptions, reductions in shipping and therefore declines in the need for oil and used oil, will harm our business and cause our operating results to suffer. For example, beginning in December 2019 and continuing through the date of this filing, the outbreak of the COVID-19 coronavirus has resulted in decreased production in China and other

countries around the world, as well as decreased demand for products and materials in general, and has consequently led to a decrease in global shipping. Furthermore, risks associated with the potential spread of the new strain of coronavirus has resulted in additional declines in shipping volumes with ships from oil tankers to container lines being turned away from ports, or held in quarantine, due to the fear of spreading the virus. The shipping segment has suffered even more as factories have been shut down across the world and travel restrictions have been put in place to control the spread of the coronavirus outbreak. It is anticipated that the diminished demand for transported goods as a result of such slowdown and shutdowns will continue to weigh on the shipping industry for months ahead.

Similarly, the recent 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, have significantly reduced the demand for, and price of oil (which ~~recently~~ reached all-time ~~lows)~~lows earlier this year) and concurrent

therewith, the slowdown in the U.S. economy caused by stay-at-home and similar orders, has reduced the amount of feedstock being produced and as a result, our ability to obtain feedstocks, and produce finished products, which has had a material adverse effect on our year-over-year results of operations.

We are continuing to experience reductions to, and interruptions in, our ability to obtain and transport feedstock and in the demand for our finished products.

A public health pandemic, including COVID-19, poses the risk that the Company or its affiliates, employees, suppliers, customers and others may be prevented from conducting business activities for an indefinite period of time, including as a result of shutdowns, travel restrictions and other actions that may be requested or mandated by governmental authorities. Such actions may prevent the Company from accessing or operating its facilities, delivering products or continuing to obtain feedstocks. While a substantial portion of the Company’s businesses has been classified as an essential business in jurisdictions in which facility closures have been mandated, the Company can give no assurance that this will not change in the future or that the Company’s businesses will be classified as essential in each of the jurisdictions in which it operates.

It is also possible that the current outbreak or continued spread of COVID-19 will cause a global recession.

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. Current global and market conditions have increased the potential for that difficulty.

Additionally, certain of the Company’s employees have been working from home, either to avoid the risk of catching the COVID-19 coronavirus, or due to stay-at-home orders issued by local governments where they live or work, and as a result, productivity may drop, which could impact revenues and profitability.

While the overall impact of the COVID-19 coronavirus on our results of operations at this point is uncertain, we anticipate that the factors discussed above and others, will have a negative effect on our results of operations for the ~~third~~fourth quarter of 2020 and into the ~~2020~~2021 year, ~~and beyond,~~ depending on how long the global slowdown associated with the virus and its after effects last. Any one or more of the events described above could cause the value of our securities to decline in value.

We are not in compliance with the minimum bid price requirement of the Nasdaq Capital Market.

On April 22, 2020, we received written notice (the “Notification Letter”) from the Listing Qualifications Department of The NASDAQ Stock Market LLC (“Nasdaq”) notifying us that we were not in compliance with the minimum bid price requirements set forth in Nasdaq Listing Rule 5550(a)(2) for continued listing on The Nasdaq Capital Market. Nasdaq Listing Rule 5550(a)(2) requires listed securities to maintain a minimum bid price of $1.00 per share, and Listing Rule 5810(c)(3)(A) provides that a failure to meet the minimum bid price requirement exists if the deficiency continues for a period of thirty (30) consecutive business days. Based on the closing bid price of the Company’s common stock for the thirty (30) consecutive business days prior to the date of the Notification Letter, the Company no longer meets the minimum bid price requirement.

However, given the unprecedented turmoil in U.S. and world financial markets over the last few ~~weeks,~~months, Nasdaq has determined to toll the compliance periods for the bid price and market value of publicly held shares requirements through June 30, 2020. The Notification Letter does not impact the Company’s listing on The Nasdaq Capital Market at this time. The Notification Letter states that the Company has 180 calendar days (beginning after the end of the tolling period, which ends on July 1, 2020), or until December 28, 2020, to regain compliance with Nasdaq Listing Rule 5550(a)(2). To regain compliance, the bid price of the Company’s common stock must have a closing bid price of at least $1.00 per share for a minimum of 10 consecutive business days. If the Company does not regain compliance by December 28, 2020, an additional 180 days may be granted to regain compliance, so long as the Company meets The Nasdaq Capital Market initial listing criteria (except for the bid price requirement)

and notifies Nasdaq in writing of its intention to cure the deficiency during the second compliance period by effecting a reverse stock split, if necessary. If the Company does not qualify for the second compliance period or fails to regain compliance during the second 180-day period, the Company’s common stock will be subject to delisting, at which point the Company would have an opportunity to appeal the delisting determination to a Hearings Panel.

The Company intends to monitor the closing bid price of its common stock and may, if appropriate, consider implementing available options to regain compliance with the minimum bid price requirement under the Nasdaq Listing Rules. Management remains vigilant with the Company’s business strategy and is continuing to take steps to increase liquidity.

In the event we are delisted from the Nasdaq Capital Market, stockholders may have a difficult time getting a quote for the sale or purchase of our stock, the sale or purchase of our stock would likely be made more difficult and the trading volume

and liquidity of our stock could decline. Delisting from the Nasdaq Capital Market could also result in negative publicity and could also make it more difficult for us to raise additional capital. The absence of such a listing may adversely affect the acceptance of our common stock as currency or the value accorded by other parties. Further, if we are delisted, we would also incur additional costs under state blue sky laws in connection with any sales of our securities. These requirements could severely limit the market liquidity of our common stock and the ability of our stockholders to sell our common stock in the secondary market. If our common stock is delisted by Nasdaq, our common stock may be eligible to trade on an over-the-counter quotation system, such as the OTCQB market, where an investor may find it more difficult to sell our stock or obtain accurate quotations as to the market value of our common stock. In the event our common stock is delisted from the Nasdaq Capital Market, we may not be able to list our common stock on another national securities exchange or obtain quotation on an over-the counter quotation system.

We may not qualify for forgiveness of our PPP Loan. We face risks associated with such PPP Loan.

On May 5, 2020, we received a $4.222 million loan (the “PPP Loan”) from Texas Citizens Bank, NA (the “PPP Lender”), pursuant to the Paycheck Protection Program (the “PPP”) under the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”). The PPP Loan is evidenced by a promissory note (the “PPP Note”), dated effective April 28, 2020, issued by the Company to the PPP Lender. The PPP Note is unsecured, matures on April 28, 2022, and bears interest at a rate of 1.00% per annum, payable monthly commencing on November 15, 2020, following an initial deferral period as specified under the PPP. The PPP Note may be prepaid at any time prior to maturity with no prepayment penalties. Proceeds from the PPP Loan will be available to the Company to fund designated expenses, including certain payroll costs, rent, utilities and other permitted expenses, in accordance with the PPP. Under the terms of the PPP, up to the entire amount of principal and accrued interest may be forgiven to the extent loan proceeds are used for qualifying expenses as described in the CARES Act and applicable implementing guidance issued by the U.S. Small Business Administration under the PPP (including that up to ~~75%~~60% of such PPP Loan funds are used for payroll). The Company intends to use the entire PPP Loan amount for designated qualifying expenses and to apply for forgiveness of the respective PPP Loan in accordance with the terms of the PPP. Notwithstanding that, the Company may not qualify for forgiveness of the PPP Loan in whole or part and may be required to repay such PPP Loan in full. With respect to any portion of the PPP Loan that is not forgiven, the PPP Loan will be subject to customary provisions for a loan of this type, including customary events of default relating to, among other things, payment defaults, breaches of the provisions of the PPP Note and cross-defaults on any other loan with the PPP Lender or other creditors. In the event the PPP Loan is not forgiven, the debt service payments on such loan may negatively affect our ability to grow our operations, service other debt and/or pay our expenses as they come due. Furthermore, any default under the PPP Loan may require us to pay a significant amount of our available cash and/or cash flow to service such debt, which could have a material adverse effect on our operations. Any failure of the PPP Loan to be forgiven pursuant to its terms, and/or our requirement to repay the PPP Loan in whole or part, could cause the value our common stock to decline in value. Separately, we face risks associated with the fact that the Treasury Department and a House oversight subcommittee has recently requested that certain large public companies return prior PPP Loans which have been obtained by such public companies and Treasury Secretary Steven Mnuchin has warned that public companies receiving loans over $2 million would be audited and could have potential criminal liability if their certifications (required to obtain such loans) were untrue. As a result, we could face penalties in connection with the PPP Loan and/or negative reactions from the public associated with our PPP Loan, either of which could cause the value of our common stock to decline in value.

Item 2. Recent Sales of Unregistered Securities

There have been no sales of unregistered securities during the quarter ended ~~June~~September 30, 2020 and from the period from ~~April~~July 1, 2020 to the filing date of this report, which have not previously been disclosed in the ~~Company's Annual Report on Form 10-K for the year ended December 31, 2019, the~~ Company’s Quarterly Report on Form 10-Q for the quarter ended ~~March 31,~~June 30, 2020, ~~or a Current Report on Form 8-K,~~ except as set forth below:

For the period from ~~April~~July 1, 2020 to ~~June~~September 30, 2020, a total of approximately ~~$188,837~~$310,220 of dividends accrued on our outstanding Series B Preferred Stock and for the period from ~~April~~July 1, 2020 to ~~June~~September 30, 2020, a total of approximately ~~$171,380~~$281,557 of dividends accrued on our outstanding Series B1 Preferred Stock. We chose to pay such dividends in-kind by way of the issuance of ~~60,915~~100,071 restricted shares of Series B Preferred Stock pro rata to each of the then holders of our Series B Preferred Stock in ~~July~~October 2020 and the issuance of ~~109,859~~180,485 restricted shares of Series B1 Preferred Stock pro rata to each of the then holders of our Series B1 Preferred Stock in ~~July~~October 2020. The maximum number of shares of common stock issuable upon conversion of the ~~60,915~~100,071 shares of Series B Preferred Stock issued in lieu of ~~June~~September 30, 2020 dividends, if converted in full, would total ~~60,915~~100,071 shares of common stock and the maximum number of shares of common stock issuable upon conversion of the ~~109,859~~180,485 shares of Series B1 Preferred Stock issued in lieu of ~~June~~September 30, 2020 dividends, if converted in full, would total ~~109,859~~180,485 shares of common stock.

As the issuance of the Series B Preferred Stock and Series B1 Preferred Stock in-kind in satisfaction of the dividends did not involve a “sale” of securities under Section 2(a)(3) of the Securities Act, we believe that no registration of such securities, or exemption from registration for such securities, was required under the Securities Act. Notwithstanding the above, to the extent such shares are deemed “sold or offered”, we claim an exemption from registration pursuant to Section 4(a)(2) and/or Rule 506 of Regulation D of the Securities Act, since the transaction did not involve a public offering, the recipients were “accredited investors”, and acquired the securities for investment only and not with a view towards, or for resale in connection with, the public sale or distribution thereof. The securities are subject to transfer restrictions, and the certificates evidencing the securities contain an appropriate legend stating that such securities have not been registered under the Securities Act and may not be offered or sold absent registration or pursuant to an exemption therefrom. The securities were not registered under the Securities Act and such securities may not be offered or sold in the United States absent registration or an exemption from registration under the Securities Act and any applicable state securities laws.

As a result of the issuances described above, there are 419,859 outstanding shares of Series A Convertible Preferred Stock issued and outstanding as of the date of this Report, and the maximum number of shares of common stock which may be issued, if such shares were converted in full, totals 419,859 shares of common stock; ~~4,002,619~~4,102,690 outstanding shares of Series B Convertible Preferred Stock issued and outstanding as of the date of this Report, and the maximum number of shares of common stock which may be issued, if such shares were converted in full, totals ~~4,002,619~~4,102,690 shares of common stock; and ~~7,219,164~~7,399,649 outstanding shares of Series B1 Convertible Preferred Stock issued and outstanding as of the date of this Report, and the maximum number of shares of common stock which may be issued, if such shares were converted in full, totals ~~7,219,164~~7,399,649 shares of common stock.

Use of Proceeds ~~From~~from Sale of Registered Securities

None.

Issuer Purchases of Equity Securities

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information.

~~On August 7, 2020, the Company and Vertex Operating entered into a Fifth Amendment to Credit Agreement with EBC (the “Fifth Amendment”), which amended the EBC Credit Agreement. Pursuant to the Fifth Amendment, EBC agreed to provide the Company up to a $2 million term loan to be used for capital expenditures (the “CapEx Loan”), which amounts may be requested~~

from time to time by the Company, provided that not more than four advances of such amount may be requested, with each advance being not less than $500,000 (in multiples of $100,000). The amendment also provided that any prepayments of the EBC Credit Agreement would first be applied to the term loan and then to the CapEx Loan. The CapEx Loan bears interest at the rate of LIBOR (1.17% at June 30, 2020) plus 7%, or to the extent that LIBOR is not available, the highest of the prime rate and the Federal Funds Rate plus 0.50%, in each case, plus 6%. We are required to repay the CapEx Loan in monthly installments of 1/48^th of the amount borrowed, each month that the CapEx Loan is outstanding, through maturity. The Fifth Amendment also included provisions providing for either the prime rate or Federal Funds Rate, plus 0.50%, to apply as the interest rate of loans made under the EBC Credit Agreement, in the event LIBOR is unavailable or unable to be used for such interest rate calculations. The obligation of EBC to fund the CapEx Loan is subject to customary conditions and requirements set forth in the Fifth Amendment, including the requirement that the Company have maintained daily availability under the ABL Credit Agreement greater than $1 million for the last thirty days, and that such availability would remain over $1 million, on a pro forma basis with such new loan. We are also required to provide the agent for the EBC Credit Agreement, a first priority security interest in the rolling stock collection assets or other assets acquired with the CapEx Loan.

None.

Item 6. Exhibits

See the Exhibit Index following the signature page to this Quarterly Report on Form 10-Q for a list of exhibits filed or furnished with this report, which Exhibit Index is incorporated herein by reference.

~~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.~~

EXHIBIT INDEX

Incorporated by Reference

Exhibit Number

Description of Exhibit

Filed or Furnished Herewith

Form

Exhibit

Filing Date/Period End Date

File No.

2.1(+)

Share Purchase and Subscription Agreement dated January 17, 2020, by and among HPRM LLC, Vertex Energy Operating LLC, Tensile-Heartland Acquisition Corporation, and solely for the purposes of Section 9.1, Vertex Energy, Inc.

8-K

2.1

1/24/2020

001-11476

10.1

Joint Supply and Marketing Agreement dated January 10, 2020, by and between Bunker One (USA) Inc. and Vertex Energy Operating, LLC

8-K

10.1

1/13/2020

001-11476

10.2

Limited Liability Company Agreement of HPRM LLC dated January 17, 2020

8-K

10.2

2/13/2020

001-11476

10.3

Fourth Amendment to Credit Agreement, by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, Encina Business Credit, LLC as Agent and the Lenders party thereto, dated April 24, 2020

8-K

10.1

4/24/2020

001-11476

10.4

Fourth Amendment to ABL Credit Agreement, by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, Encina Business Credit, LLC as Agent and the Lenders party thereto, dated April 24, 2020

8-K

10.2

4/24/2020

001-11476

10.5

Vertex Energy, Inc. 2019 Equity Incentive Plan

8-K

10.1

11/1/2019

001-11476

10.6

Vertex Energy, Inc. 2020 Equity Incentive Plan

8-K

10.2

2/23/2020

001-11476

10.7

Form of 2019 Equity Incentive Plan Stock Option Agreement

8-K

10.3

2/23/2020

001-11476

10.8

Fifth Amendment To Credit Agreement dated August 7, 2020 by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, the other borrowers signatory thereto, Encina Business Credit, LLC, as agent, and the lenders signatory thereto

10-Q

10.8

8/11/2020

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**

99.1

Glossary of Selected Terms

10-K

99.1

12/31/2012

001-11476

101.INS

XBRL Instance Document

101.SCH

XBRL Taxonomy Extension Schema Document

101.CAL

XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF

XBRL Taxonomy Extension Definition Linkbase Document

101.LAB

XBRL Taxonomy Extension Label Linkbase Document



	~~VERTEX ENERGY, INC.~~

~~Date: August 10, 2020~~	~~By: /s/ Benjamin P. Cowart~~
	~~Benjamin P. Cowart~~
	~~Chief Executive Officer~~
	~~(Principal Executive Officer)~~


~~Date: August 10, 2020~~	~~By: /s/ Chris Carlson~~
	~~Chris Carlson~~
	~~Chief Financial Officer~~
	~~(Principal Financial/Accounting Officer)~~

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

2.1(+)

Share Purchase and Subscription Agreement dated January 17, 2020, by and among HPRM LLC, Vertex Energy Operating LLC, Tensile-Heartland Acquisition Corporation, and solely for the purposes of Section 9.1, Vertex Energy, Inc.
8-K 2.1
1/24/2020 001-11476
10.1

Joint Supply and Marketing Agreement dated January 10, 2020, by and between Bunker One (USA) Inc. and Vertex Energy Operating, LLC
8-K 10.1
1/13/2020 001-11476
10.2

Limited Liability Company Agreement of HPRM LLC dated January 17, 2020
8-K 10.2
2/13/2020 001-11476
10.3

Fourth Amendment to Credit Agreement, by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, Encina Business Credit, LLC as Agent and the Lenders party thereto, dated April 24, 2020
8-K 10.1
4/24/2020 001-11476
10.4

Fourth Amendment to ABL Credit Agreement, by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, Encina Business Credit, LLC as Agent and the Lenders party thereto, dated April 24, 2020
8-K 10.2
4/24/2020 001-11476
10.5

Vertex Energy, Inc. 2019 Equity Incentive Plan
8-K 10.1
11/1/2019 001-11476
10.6

Vertex Energy, Inc. 2020 Equity Incentive Plan
8-K 10.2
2/23/2020 001-11476
10.7

Form of 2019 Equity Incentive Plan Stock Option Agreement
8-K 10.3
2/23/2020 001-11476
10.8*

Fifth Amendment To Credit Agreement dated August 7, 2020 by and among Vertex Energy, Inc., Vertex Energy Operating, LLC, the other borrowers signatory thereto, Encina Business Credit, LLC, as agent, and the lenders signatory thereto
X
31.1

Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act*
X
31.2

Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act*
X
32.1

Certification of Principal Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act**
X
32.2

Certification of Principal Accounting Officer Pursuant to Section 906 of the Sarbanes-Oxley Act**
X
99.1

Glossary of Selected Terms
10-K 99.1
12/31/2012 001-11476
101.INS XBRL Instance Document X
101.SCH XBRL Taxonomy Extension Schema Document X
101.CAL XBRL Taxonomy Extension Calculation Linkbase Document X
101.DEF XBRL Taxonomy Extension Definition Linkbase Document X

~~101.LAB~~101.PRE

~~XBRL Taxonomy Extension Label Linkbase Document~~

~~101.PRE~~

XBRL Taxonomy Extension Presentation Linkbase Document

* Filed herewith.

** Furnished herewith.

+ Certain schedules and exhibits have been omitted pursuant to Item 601(b)(2) 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 9, 2020			By: /s/ Benjamin P. Cowart
			Benjamin P. Cowart
			Chief Executive Officer
			(Principal Executive Officer)


Date: November 9, 2020			By: /s/ Chris Carlson
			Chris Carlson
			Chief Financial Officer
			(Principal Financial/Accounting Officer)



	June 30, 2020			December 31, 2019
ASSETS
Current assets
Cash and cash equivalents	$	17,754,312		$	4,099,655
Restricted cash	100,125			100,170
Accounts receivable, net	9,163,208			12,138,078
Federal income tax receivable	—			68,606
Inventory	3,812,752			6,547,479
Prepaid expenses and other current assets	2,499,104			4,452,920
Total current assets	33,329,501			27,406,908

Noncurrent assets
Fixed assets, at cost	70,977,927			69,469,548
Less accumulated depreciation	(26,992,136		)	(24,708,151		)
Fixed assets, net	43,985,791			44,761,397
Finance lease right-of-use assets	1,613,661			851,570
Operating lease right-of use assets	34,739,105			35,586,885
Intangible assets, net	10,363,179			11,243,800
Deferred income taxes	—			68,605
Other assets	1,219,301			840,754
TOTAL ASSETS	$	125,250,538		$	120,759,919



	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
Revenues	$	21,374,127		$	43,657,292		$	57,577,556		$	82,978,004
Cost of revenues (exclusive of depreciation and amortization shown separately below)	22,197,805			36,515,421			49,034,659			71,359,770
Gross profit (loss)	(823,678		)	7,141,871			8,542,897			11,618,234

Operating expenses:
Selling, general and administrative expenses	6,030,560			6,028,859			12,731,078			11,376,600
Depreciation and amortization	1,713,461			1,780,890			3,348,008			3,517,903
Total operating expenses	7,744,021			7,809,749			16,079,086			14,894,503
Loss from operations	(8,567,699		)	(667,878		)	(7,536,189		)	(3,276,269		)
Other income (expense):
Other income	20			1,918			100			1,918
Gain on sale of assets	12,344			29,150			12,344			31,443
Gain (loss) on change in value of derivative warrant liability	(110,965		)	746,017			1,587,782			(959,077		)
Interest expense	(222,173		)	(738,972		)	(562,259		)	(1,496,775		)
Total other income (expense)	(320,774		)	38,113			1,037,967			(2,422,491		)
Loss before income tax	(8,888,473		)	(629,765		)	(6,498,222		)	(5,698,760		)
Income tax benefit (expense)	—			—			—			—
Net loss	(8,888,473		)	(629,765		)	(6,498,222		)	(5,698,760		)
Net income (loss) attributable to non-controlling interest and redeemable non-controlling interest	109,165			(202,329		)	(289,444		)	(307,760		)
Net loss attributable to Vertex Energy, Inc.	(8,997,638		)	(427,436		)	(6,208,778		)	(5,391,000		)

Accretion of redeemable noncontrolling interest to redemption value	(1,381,889		)	—			(12,348,238		)	—
Accretion of discount on Series B and B1 Preferred Stock	(539,235		)	(532,925		)	(1,471,238		)	(1,093,600		)
Dividends on Series B and B1 Preferred Stock	(360,217		)	(412,875		)	(704,716		)	(819,670		)
Net loss available to common shareholders	$	(11,278,979	)	$	(1,373,236	)	$	(20,732,970	)	$	(7,304,270	)
Loss per common share
Basic	$	(0.25	)	$	(0.03	)	$	(0.46	)	$	(0.18	)
Diluted	$	(0.25	)	$	(0.03	)	$	(0.46	)	$	(0.18	)
Shares used in computing earnings per share
Basic	45,554,841			40,294,870			45,463,600			40,245,671
Diluted	45,554,841			40,294,870			45,463,600			40,245,671



Six Months Ended June 30, 2019
	Common Stock			Series A Preferred			Series C Preferred
	Shares	$0.001 Par		Shares	$0.001 Par		Shares	$0.001 Par		Additional Paid-In Capital		Retained Earnings			Non-controlling Interest			Total Equity
Balance on January 1, 2019	40,174,821	$	40,175	419,859	$	420	—	$	—	$	75,131,122	$	(47,800,886	)	$	1,438,213		$	28,809,044
Share based compensation expense	—	—		—	—		—	—		143,063		—			—			143,063
Conversion of Series B1 Preferred stock to common	96,160	96		—	—		—	—		149,914		—			—			150,010
Dividends on Series B and B1	—	—		—	—		—	—		—		(406,795		)	—			(406,795		)
Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(560,675		)	—			(560,675		)
Net loss	—	—		—	—		—	—		—		(4,963,564		)	(105,431		)	(5,068,995		)
Balance on March 31, 2019	40,270,981	$	40,271	419,859	$	420	—	$	—	$	75,424,099	$	(53,731,920	)	$	1,332,782		$	23,065,652
Exercise of options to common	75,925	76		—	—		—	—		4,424		—			—			4,500
Share based compensation expense	—	—		—	—		—	—		171,002		—			—			171,002
Distribution to noncontrolling	—	—		—	—		—	—		—		—			(285,534		)	(285,534		)
Dividends on Series B and B1	—	—		—	—		—	—		—		(412,875		)	—			(412,875		)
Accretion of discount on Series B and B1	—	—		—	—		—	—		—		(532,925		)	—			(532,925		)
Net income	—	—		—	—		—	—		—		(427,436		)	(202,329		)	(629,765		)
Balance on June 30, 2019	40,346,906	$	40,347	419,859	$	420	—	$	—	$	75,599,525	$	(55,105,156	)	$	844,919		$	21,380,055



	Six Months Ended
	June 30, 2020			June 30, 2019
Cash flows from operating activities
Net loss	$	(6,498,222	)	$	(5,698,760	)
Adjustments to reconcile net loss to cash provided by operating activities
Stock based compensation expense	319,809			314,065
Depreciation and amortization	3,348,008			3,517,903
Gain on sale of assets	(12,344		)	(31,443		)
Contingent consideration reduction	—			(15,564		)
Bad debt and reduction in allowance for bad debt	65,443			(360,926		)
(Decrease) increase in fair value of derivative warrant liability	(1,587,782		)	959,077
(Gain) loss on commodity derivative contracts	(4,484,798		)	1,069,778
Net cash settlements on commodity derivatives	4,781,183			(967,708		)
Amortization of debt discount and deferred costs	47,826			286,954
Changes in operating assets and liabilities
Accounts receivable	4,986,003			(2,111,591		)
Inventory	3,711,239			2,338,814
Prepaid expenses	1,834,361			1,948,771
Accounts payable	(269,740		)	(518,050		)
Accrued expenses	(2,150,272		)	(187,349		)
Other assets	(378,547		)	—
Net cash provided by operating activities	3,712,167			543,971
Cash flows from investing activities
Acquisition	(1,822,690		)	—
Internally developed software	(49,229		)	—
Purchase of fixed assets	(1,526,379		)	(2,419,599		)
Proceeds from sale of fixed assets	22,844			86,846
Net cash used in investing activities	(3,375,454		)	(2,332,753		)
Cash flows from financing activities
Payments on finance leases	(162,312		)	(61,638		)
Proceeds from exercise of stock options	—			4,500
Distribution VRM LA	—			(285,534		)
Contributions received from redeemable noncontrolling interest	21,000,000			—
Line of credit (payments) proceeds, net	(3,276,230		)	1,235,251
Proceeds from note payable (includes proceeds from PPP note)	4,374,643			187,501
Payments on note payable	(8,618,202		)	(1,542,903		)
Net cash provided by (used in) financing activities	13,317,899			(462,823		)
Net change in cash, cash equivalents and restricted cash	13,654,612			(2,251,605		)
Cash, cash equivalents, and restricted cash at beginning of the period	4,199,825			2,849,831
Cash, cash equivalents, and restricted cash at end of period	$	17,854,437		$	598,226



SUPPLEMENTAL INFORMATION
Cash paid for interest	$	562,259	$	1,221,363
Cash paid for taxes	$	—	$	—
NON-CASH INVESTING AND FINANCING TRANSACTIONS
Conversion of Series B1 Preferred Stock into common stock	$	3,368,474	$	150,010
Accretion of discount on Series B and B1 Preferred Stock	$	1,471,238	$	1,093,600
Dividends-in-kind accrued on Series B and B1 Preferred Stock	$	704,716	$	819,670
Equipment acquired under finance leases	$	888,764	$	621,000
Initial adjustment of carrying amount redeemable noncontrolling interest	$	9,091,068	$	—
Accretion of redeemable noncontrolling interest to redemption value	$	12,348,238	$	—



	June 30, 2020		June 30, 2019
Cash and cash equivalents	$	17,754,312	$	498,219
Restricted cash	100,125		100,007
Cash and cash equivalents and restricted cash as shown in the consolidated statements of cash flows	$	17,854,437	$	598,226



	Six Months Ended June 30, 2020		Six Months Ended June 30, 2019
	% of Revenues	% of Receivables	% of Revenues	% of Receivables
Customer 1	38%	7%	31%	20%
Customer 2	12%	16%	7%	14%
Customer 3	3%	—%	11%	8%
Customer 4	2%	2%	4%	10%
Customer 5	—%	—%	17%	—%



	Three Months Ended June 30, 2019
	Black Oil		Refining & Marketing		Recovery		Total
Primary Geographical Markets
Northern United States	$	9,880,565	$	—	$	—	$	9,880,565
Southern United States	28,027,246		3,277,402		2,472,079		33,776,727
	$	37,907,811	$	3,277,402	$	2,472,079	$	43,657,292
Sources of Revenue
Petroleum products	$	37,907,811	$	3,277,402	$	642,596	$	41,827,809
Metals	—		—		1,829,483		1,829,483
Total revenues	$	37,907,811	$	3,277,402	$	2,472,079	$	43,657,292



As of June 30, 2020
Contract Type	Contract Period	Weighted Average Strike Price (Barrels)		Remaining Volume (Barrels)	Fair Value

Futures	Jun. 2020- Oct. 2020	$	50.57	108,000	(538,297		)
					$	(538,297	)



	June 30, 2020
Cash and cash equivalents	$	8,407,926
Accounts receivable, net	3,031,746
Inventory	457,119
Prepaid expense and other current assets	439,702
Total current assets	12,336,493

Fixed assets, net	5,719,408
Finance lease right-of-use assets	1,050,973
Operating lease right-of-use assets	437,716
Intangible assets, net	1,190,080
Other assets	108,643
Total assets	$	20,843,313

Accounts payable	$	1,247,601
Accrued expenses	288,694
Finance lease liability-current	301,443
Operating lease liability-current	285,837
Total current liabilities	2,123,575

Finance lease liability-long term	725,298
Operating lease liability-long term	151,879
Total liabilities	$	3,000,752



	Three Months Ended June 30,						$ Change - Favorable (Unfavorable)			% Change - Favorable (Unfavorable)
Black Oil Segment	2020			2019			$ Change - Favorable (Unfavorable)			% Change - Favorable (Unfavorable)
Total revenue	$	11,543,135		$	37,907,811		$	(26,364,676	)	(70	)%
Total cost of revenue (exclusive of depreciation and amortization shown separately below)	11,848,334			31,368,939			19,520,605			62	%
Gross profit (loss)	(305,199		)	6,538,872			(6,844,071		)	(105	)%
Selling general and administrative expense	4,869,391			5,037,708			168,317			3	%
Depreciation and amortization	1,329,751			1,375,313			45,562			3	%
Income (loss) from operations	$	(6,504,341	)	$	125,851		$	(6,630,192	)	(5,268	)%

Refining and Marketing Segment
Total revenue	$	6,297,328		$	3,277,402		$	3,019,926		92	%
Total cost of revenue (exclusive of depreciation and amortization shown separately below)	5,958,778			2,705,031			(3,253,747		)	(120	)%
Gross profit	338,550			572,371			(233,821		)	(41	)%
Selling general and administrative expense	578,027			459,600			(118,427		)	(26	)%
Depreciation and amortization	219,766			245,179			25,413			10	%
Loss from operations	$	(459,243	)	$	(132,408	)	$	(326,835	)	(247	)%

Recovery Segment
Total revenue	$	3,533,664		$	2,472,079		$	1,061,585		43	%
Total cost of revenue (exclusive of depreciation and amortization shown separately below)	4,390,693			2,441,451			(1,949,242		)	(80	)%
Gross profit (loss)	(857,029		)	30,628			(887,657		)	(2,898	)%
Selling general and administrative expense	583,142			531,551			(51,591		)	(10	)%
Depreciation and amortization	163,944			160,398			(3,546		)	(2	)%
Loss from operations	$	(1,604,115	)	$	(661,321	)	$	(942,794	)	(143	)%