10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2020

or

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

For the transition period from to

Commission File No. 0-15905

BLUE DOLPHIN ENERGY COMPANY

(Exact name of registrant as specified in its charter)

Delaware	73-1268729
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
801 Travis Street, Suite 2100, Houston, Texas	77002
(Address of principal executive offices)	(Zip Code)

713-568-4725

(Registrant’s telephone number, including area code)

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

Title of Each Class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	BDCO	OTCQX

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

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

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

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

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

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

Yes ☐ No ☒

Number of shares of common stock, par value $0.01 per share outstanding as of August 14, 2020: 12,693,514

Blue Dolphin Energy Company June 30, 2020

Table of Contents

TABLE OF CONTENTS

PART I.		7
ITEM 1.	FINANCIAL STATEMENTS	7
	Consolidated Balance Sheets (Unaudited)	7
	Consolidated Statements of Operations (Unaudited)	8
	Consolidated Statements of Cash Flows (Unaudited)	9
	Notes to Consolidated Financial Statements	10
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	35
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	51
ITEM 4.	CONTROLS AND PROCEDURES	51
PART II.		52
ITEM 1.	LEGAL PROCEEDINGS	52
ITEM 1A.	RISK FACTORS	53
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	54
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	54
ITEM 4.	MINE SAFETY DISCLOSURES	54
ITEM 5.	OTHER INFORMATION	54
ITEM 6.	EXHIBITS	54
SIGNATURES		55

Blue Dolphin Energy Company June 30, 2020

2

Glossary of Terms

Glossary of Terms

Throughout this Quarterly Report on Form 10-Q, we have used the following terms:

Affiliate. Refers, either individually or collectively, to certain related parties including Jonathan Carroll, Chairman and Chief Executive Officer of Blue Dolphin, and his affiliates (including C&C, Ingleside, and Lazarus Capital) and/or LEH and its affiliates (including Lazarus Midstream, LMT, and LTRI). Together, Jonathan Carroll and LEH own approximately 82% of Blue Dolphin’s Common Stock. AMT. Alternative Minimum Tax. Amended Pilot Line of Credit. Line of Credit Agreement dated May 3, 2019, between Pilot and NPS and subsequently amended on May 9, 2019 and May 10, 2019 and September 3, 2019, the last amendment being Amendment No. 1; original line of credit amount was $13.0 million. Amended and Restated Operating Agreement. Affiliate agreement dated April 1, 2020 between Blue Dolphin, LE, LRM, NPS, BDPL, BDPC, BDSC and LEH governing LEH’s operation and management of those companies’ assets. ARO. Asset retirement obligations. ASU. Accounting Standards Update. AGO. Atmospheric gas oil, which is the heaviest product boiled by a crude distillation tower operating at atmospheric pressure. This fraction ordinarily sells as distillate fuel oil, either in pure form or blended with cracked stocks. Certain ethylene plants, called heavy oil crackers, can take AGO as feedstock. bbl. Barrel; a unit of volume equal to 42 U.S. gallons. BDPC. Blue Dolphin Petroleum Company, a wholly owned subsidiary of Blue Dolphin. BDPL. Blue Dolphin Pipe Line Company, a wholly owned subsidiary of Blue Dolphin. BDSC. Blue Dolphin Services Co., a wholly owned subsidiary of Blue Dolphin. bpd. Barrel per day; a measure of the bbls of daily output produced in a refinery or transported through a pipeline. Board. Board of Directors of Blue Dolphin Energy Company. BOEM. Bureau of Ocean Energy Management. BSEE. Bureau of Safety and Environmental Enforcement. C&C. Carroll & Company Financial Holdings, L.P., an affiliate of Jonathan Carroll. Capacity utilization rate. A percentage measure that indicates the amount of available capacity that is being used in a refinery or transported through a pipeline. With respect to the crude distillation tower, the rate is calculated by dividing total refinery throughput or total refinery production on a bpd basis by the total capacity of the crude distillation tower (currently 15,000 bpd). CAA. Clean Air Act. CDC. Centers for Disease Control and Prevention. CERLA. Comprehensive Environmental Response, Compensation, and Liability Act of 1980. CIP. Construction in progress. COVID-19. An infectious disease first identified in 2019 in Wuhan, the capital of China's Hubei province; the disease has since spread globally, resulting in the ongoing 2019–2020 coronavirus pandemic. CWA. Clean Water Act. Common Stock. Blue Dolphin common stock, par value $0.01 per share. Blue Dolphin has 20,000,000 shares of Common Stock authorized. Complexity. A numerical score that denotes, for a given refinery, the extent, capability, and capital intensity of the refining processes downstream of the crude distillation tower. Refinery complexities range from the relatively simple crude distillation tower (“topping unit”), which has a complexity of 1.0, to the more complex deep conversion (“coking”) refineries, which have a complexity of 12.0. Condensate. Liquid hydrocarbons that are produced in conjunction with natural gas. Although condensate is sometimes like crude oil, it is usually lighter. Cost of goods sold. Reflects the cost of crude oil and condensate, fuel use, and chemicals. Crude distillation tower. A tall column-like vessel in which crude oil and condensate is heated and its vaporized components are distilled by means of distillation trays. This process turns crude oil and other inputs into intermediate and finished petroleum products. (Commonly referred to as a crude distillation unit or an atmospheric distillation unit; also referred to herein as the Nixon refinery.) Crude oil. A mixture of thousands of chemicals and compounds, primarily hydrocarbons. Crude oil quality is measured in terms of density (light to heavy) and sulfur content (sweet to sour). Crude oil must be broken down into its various components by distillation before these chemicals and compounds can be used as fuels or converted to more valuable products. Depropanizer unit. A distillation column that is used to isolate propane from a mixture containing butane and other heavy components. Distillates. The result of crude distillation and therefore any refined oil product. Distillate is more commonly used as an abbreviated form of middle distillate. There are mainly four (4) types of distillates: (i) very light oils or light distillates (such as naphtha), (ii) light oils or middle distillates (such as our jet fuel), (iii) medium oils, and (iv) heavy oils (such as our low-sulfur diesel and HOBM, reduced crude, and AGO). Distillation. The first step in the refining process whereby crude oil and condensate is heated at atmospheric pressure in the base of a distillation tower. As the temperature increases, the various compounds vaporize in succession at their various boiling points and then rise to prescribed levels within the tower per their densities, from lightest to heaviest. They then condense in distillation trays and are drawn off individually for further refining. Distillation is also used at other points in the refining process to remove impurities. Downtime. Scheduled and/or unscheduled periods in which the crude distillation tower is not operating. Downtime may occur for a variety of reasons, including bad weather, power failures, and preventive maintenance. EIA. Energy Information Administration. EPA. Environmental Protection Agency. Eagle Ford Shale. Ahydrocarbon-producing geological formation extending across South Texas from the Mexican border into East Texas. Exchange Act. Securities Exchange Act of 1934, as amended. FASB. Financial Accounting Standards Board. FDIC. Federal Deposit Insurance Corporation. Feedstocks. Crude oil and other hydrocarbons, such as condensate and/or intermediate products, that are used as basic input materials in a refining process. Feedstocks are transformed into one or more finished products. Finished petroleum products. Materials or products which have received the final increments of value through processing operations, and which are being held in inventory for delivery, sale, or use. Freeport facility. Encompasses processing units for: (i) crude oil and natural gas separation and dehydration, (ii) natural gas processing, treating, and redelivery, and (iii) vapor recovery; also includes two onshore pipelines and 162 acres of land in Freeport, Texas. GEL. GEL Tex Marketing, LLC, a Delaware limited liability company and an affiliate of Genesis Energy, LLC. GEL Final Arbitration Award. Damages and attorney fees and related expenses awarded to GEL by an arbitrator on August 11, 2017. GEL Interim Payments. Cash payments of $0.5 million at the end of each calendar month by the Lazarus Parties to GEL until the GEL Settlement Payment was made.

Blue Dolphin Energy Company June 30, 2020

3

Glossary of Terms

GEL Settlement. When all conditions of the GEL Settlement Agreement were met by the Lazarus Parties under the GEL Settlement Agreement, and whereby GEL and the Lazarus Parties agreed to mutually release all claims against each other and to file a stipulation of dismissal with prejudice in connection with arbitration proceedings between LE and GEL related to a contractual dispute involving a crude oil supply and throughput services agreement, each between LE and GEL dated August 12, 2011. GEL Settlement Agreement. Settlement Agreement dated July 20, 2018, between the Lazarus Parties and GEL outlining the terms and conditions for a settlement, including: (i) the GEL Settlement Payment by the GEL Settlement Date and (ii) GEL Interim Payments. GEL Settlement Date. The effective date of the GEL Settlement. GEL Settlement Payment. A lump sum cash payment of $10.0 million as paid by the Lazarus Parties to GEL under the GEL Settlement Agreement. Gross profit (deficit).Calculated as total revenue less cost of goods sold; reflected as a dollar ($) amount. HOBM. Heavy oil-based mud blendstock; see also “distillates.” HUBZone. Historically Underutilized Business Zones program established by the SBA to help small businesses in both urban and rural communities. IBLA. Interior Board of Land Appeals. INC. Incident of Noncompliance issued by BOEM and/or BSEE. Ingleside. Ingleside Crude, LLC, an affiliate of Jonathan Carroll. Intermediate petroleum products. A petroleum product that might require further processing before it is saleable to the ultimate consumer. This further processing might be done by the producer or by another processor. Thus, an intermediate petroleum product might be a final product for one company and an input for another company that will process it further. IRC Section 382. Title 26, Internal Revenue Code, Subtitle A – Income Taxes, Subchapter C – Corporate Distributions and Adjustments, Part V Carryovers, § 382. Limits NOL carryforwards and certain built-in losses following ownership change. IRS. Internal Revenue Service. Jet fuel. A high-quality kerosene product primarily used in aviation. Kerosene-type jet fuel (including Jet A and Jet A-1) has a carbon number distribution between 8 and 16 carbon atoms per molecule; wide-cut or naphtha-type jet fuel (including Jet B) has between 5 and 15 carbon atoms per molecule. Lazarus Capital. Lazarus Capital, LLC, an affiliate of Jonathan Carroll. Lazarus Midstream. Lazarus Midstream Partners, L.P., an affiliate of LEH. Lazarus Parties. Blue Dolphin, C&C, NPS,LE, LEH, and Jonathan Carroll. LE. Lazarus Energy, LLC, a wholly owned subsidiary of Blue Dolphin. LEH. Lazarus Energy Holdings, LLC, an affiliate of Jonathan Carroll and controlling shareholder of Blue Dolphin. LEH Operating Fee. A management fee paid to LEH under the Amended and Restated Operating Agreement; calculated as 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest, of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC; previously reflected within refinery operating expenses in our consolidated statements of operations. Leasehold interest. The interest of a lessee under an oil and gas lease. Light crude. A liquid petroleum that has a low density and flows freely at room temperature. It has a low viscosity, low specific gravity, and a high American Petroleum Institute gravity due to the presence of a high proportion of light hydrocarbon fractions. LMT. Lazarus Marine Terminal I, LLC, an affiliate of LEH. LRM. Lazarus Refining & Marketing, LLC, a wholly owned subsidiary of Blue Dolphin. LTRI. Lazarus Texas Refinery I, an affiliate of LEH. NAAQS. National Ambient Air Quality Standards.   Naphtha. A refined or partly refined light distillate fraction of crude oil. Blended further or mixed with other materials it can make high-grade motor gasoline or jet fuel. It is also a generic term applied to the lightest and most volatile petroleum fractions. Natural gas. A naturally occurring hydrocarbon gas mixture consisting primarily of methane, but commonly including varying amounts of other higher alkanes, and sometimes a small percentage of carbon dioxide, nitrogen, hydrogen sulfide, or helium. Nixon facility. Encompasses the 15,000-bpd crude distillation tower, petroleum storage tanks, loading and unloading facilities, and 56 acres of land in Nixon, Texas. Nixon refinery. The 15,000-bpd crude distillation tower and associated processing units in Nixon, Texas. NPS. Nixon Product Storage, LLC, a wholly owned subsidiary of Blue Dolphin. NOL. Net operating losses. NSR/PSD. New Source Review/Prevention of Significant Deterioration. OPA 90. Oil Pollution Act of 1990. Operating days. Represents the number of days in a period in which the crude distillation tower operated. Operating days is calculated by subtracting downtime in a period from calendar days in the same period. OPEC. Organization of Petroleum Exporting Countries. OSHA. Occupational Safety and Health Administration. OSRO. Oil Spill Response Organization. Other conversion costs. Represents the combination of direct labor costs and manufacturing overhead costs. These are the costs that are necessary to convert our raw materials into refined products. Other operating expenses. Represents costs associated with our natural gas processing, treating, and redelivery facility, as well as our pipeline assets and leasehold interests in oil and gas properties. PCAOB. Public Company Accounting Oversight Board. Petroleum. A naturally occurring flammable liquid consisting of a complex mixture of hydrocarbons of various molecular weights and other liquid organic compounds. The name petroleum covers both the naturally occurring unprocessed crude oils and petroleum products that are made up of refined crude oil. PHMSA. Pipeline and Hazardous Materials Safety Administration of the U.S. Department of Transportation. Pilot. Pilot Travel Centers LLC, a Delaware limited liability company. Preferred Stock. Blue Dolphin preferred stock, par value $0.10 per share. Blue Dolphin has 2,500,000 shares of Preferred Stock authorized and no shares of Preferred Stock issued and outstanding. Product slate. Represents type and quality of products produced. Propane. A by-product of natural gas processing and petroleum refining. Propane is one of a group of liquified petroleum gases. Others include butane, propylene, butadiene, butylene, isobutylene and mixtures thereof. Refined products. Hydrocarbon compounds, such as jet fuel and residual fuel, that are produced by a refinery. Refinery. Within the oil and gas industry, a refinery is an industrial processing plant where crude oil, condensate, and intermediate feeds are separated and transformed into petroleum products. Refining gross profit (deficit) per bbl. Calculated as refinery operations revenue less total cost of goods sold divided by the volume, in bbls, of refined products sold during the period; reflected as a dollar ($) amount per bbl. RCRA. Federal Resource Conservation and Recovery Act. RFS2. Second Renewable Fuels Standard. ROU. Right-of-use.

Blue Dolphin Energy Company June 30, 2020

4

Glossary of Terms

SEC. Securities and Exchange Commission. Securities Act. The Securities Act of 1933, as amended. Segment margin (deficit). For our refinery operations and tolling and terminaling business segments, represents net revenues (excluding intercompany fees and sales) attributable to the respective business segment less associated intercompany fees and sales less associated operation costs and expenses. SEMS. Safety and Environmental Management System. Sour crude. Crude oil containing sulfur content of more than 0.5%. Stabilizer unit. A distillation column intended to remove the lighter boiling compounds, such as butane or propane, from a product. Sweet crude. Crude oil containing sulfur content of less than 0.5%. Sulfur. Present at various levels of concentration in many hydrocarbon deposits, such as petroleum, coal, or natural gas. Also, produced as a by-product of removing sulfur-containing contaminants from natural gas and petroleum. Some of the most commonly used hydrocarbon deposits are categorized per their sulfur content, with lower sulfur fuels usually selling at a higher, or premium, price and higher sulfur fuels selling at a lower, or discounted, price. Topping unit. A type of petroleum refinery that engages in only the first step of the refining process -- crude distillation. A topping unit uses atmospheric distillation to separate crude oil and condensate into constituent petroleum products. A topping unit has a refinery complexity range of 1.0 to 2.0. Throughput. The volume processed through a unit or a refinery or transported through a pipeline.
Total refinery production. Refers to the volume processed as output through the crude distillation tower. Refinery production includes finished petroleum products, such as jet fuel, and intermediate petroleum products, such as naphtha, HOBM and AGO. TMT. Texas margins tax; a form of business tax imposed on an entity’s gross profit rather than on its net income. Turnaround. Scheduled large-scale maintenance activity wherein an entire process unit is taken offline for a week or more for comprehensive revamp and renewal. USACOE. U.S. Army Corps of Engineers. USDA. U.S. Department of Agriculture. U.S. GAAP. Accounting principles generally accepted in the United States of America. Veritex. Veritex Community Bank, successor in interest to Sovereign Bank by merger. WHO. World Health Organization. WSJ prime rate. A measure of the U.S. prime rate as defined by the Wall Street Journal. XBRL. eXtensible Business Reporting Language. Yield. The percentage of refined products that is produced from crude oil and other feedstocks.

Blue Dolphin Energy Company June 30, 2020

5

Important Information Regarding Forward Looking Statements

Important Information Regarding Forward-Looking Statements

This report (including information incorporated by reference) contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act, including, but not limited to, those under “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.” All statements other than statements of historical fact, including without limitation statements regarding expectations regarding revenue, cash flows, capital expenditures, and other financial items, our business strategy, goals and expectations concerning our market position, future operations and profitability, are forward-looking statements. Forward-looking statements may be identified by use of the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will,” “would” and similar terms and phrases. Although we believe our assumptions concerning future events are reasonable, several risks, uncertainties, and other factors could cause actual results and trends to differ materially from those projected, including but not limited to:

Business and Industry

● 

Our going concern status.

● 

Inadequate liquidity to sustain operations due to defaults under our secured loan agreements, margin deterioration, and historic net losses and working capital deficits.

● 

Substantial debt in current liabilities, which is currently in default.

● 

Ability to regain compliance with the terms of our outstanding indebtedness.

● 

Increased costs of capital or a reduction in the availability of credit.

● 

Affiliate common stock ownership and transactions that could cause conflicts of interest.

● 

Operational hazards inherent in refining and natural gas processing operations and in transporting and storing crude oil and condensate and refined products.

● 

Geographic concentration of our assets and customers in West Texas, creating significant exposure to regional economy risks and other conditions.

● 

Competition from companies having greater financial and other resources.

● 

Federal, state, and local environmental, economic, health and safety, energy and other policies and regulations, including those related to climate change, and any changes therein, and any legal and regulatory investigations, delays in obtaining necessary approvals and permits, compliance costs or other factors beyond our control.

● 

Environmental laws and regulations that could require us to make substantial capital expenditures to remain in compliance or remediate current or future contamination that could give rise to material liabilities.

● 

Changes in insurance markets impacting costs and the level and types of coverage available.

● 

NOL carryforwards to offset future taxable income for U.S. federal income tax purposes that are subject to limitation.

● 

Direct or indirect effects on our business resulting from actual or threatened terrorist or activist incidents, cyber-security breaches, or acts of war.

● 

The effects of public health threats, pandemics and epidemics, such as the ongoing outbreak of COVID-19, and the adverse impacts thereof on our business, financial condition, results of operations, and liquidity, including, but not limited to, our growth, operating costs, supply chain, labor availability, logistical capabilities, customer demand for our products, industry demand generally, crude oil supply, margins, production and throughput capacity, utilization, inventory value, cash position, taxes, the price of our securities and trading markets with respect thereto, our ability to access capital markets, and the global economy and financial markets generally.

Refinery and Tolling and Terminaling Operations

● 

Timing and extent of changes in commodity prices and demand for refined products.

● 

Availability and costs of crude oil and other feedstocks.

● 

Price volatility of fuel and utility services to operate the Nixon facility.

● 

Disruptions due to equipment interruption or failure at the Nixon facility.

● 

Changes in our cash flow from operations and working capital requirements, shortfalls of which Affiliates may not fund.

● 

Ability to regain compliance with the terms of our outstanding indebtedness.

● 

Key personnel loss, labor relations, and workplace safety.

● 

Loss of market share by and a material change in profitability of our key customers.

● 

Contract cancellation, non-renewal, or failure to perform by those in our supply and distribution chains, and the ability to replace such contracts and/or customers.

● 

Changes in the cost or availability of third-party vessels, pipelines, trucks, and other means of delivering and transporting crude oil and condensate, feedstocks, and refined products.

● 

Sourcing of a substantial amount, if not all, of our crude oil and condensate from the Eagle Ford Shale.

● 

Geographic concentration of our refining operations and customers within the Eagle Ford Shale.

● 

Weather conditions, hurricanes or other natural disasters affecting operations by us or our key customers or the areas in which our customers operate.

● 

The effect, impact, potential duration, or other implications of the ongoing outbreak of COVID-19 and global crude oil production levels, and any expectations we may have with respect thereto.

Pipeline and Facilities and Oil and Gas Assets

● 

Assessment of civil penalties by BOEM for our failure to satisfy orders to provide additional financial assurance (supplemental pipeline bonds) within the time period prescribed.

● 

Assessment of civil penalties by BSEE for our failure to decommission pipeline and platform assets, as well as complete structural platform surveys, within the time periods prescribed.

Common Stock

● 

Decline in stock price due to share sales by Affiliates.

● 

Issuance of additional shares of Common Stock and Preferred Stock, which significantly dilute the equity ownership of current holders.

See also the risk factors described in greater detail under “Item 1A.” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 and our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020 as filed with the SEC. All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to revise or update any forward-looking statements as a result of new information, future events, or otherwise.

Unless the context otherwise requires, references in this report to “Blue Dolphin,” “we,” “us,” “our,” or “ours” refer to Blue Dolphin Energy Company, one or more of its consolidated subsidiaries, or all of them taken as a whole.

Blue Dolphin Energy Company June 30, 2020

6

Financial Statements

PART I

ITEM 1. 

FINANCIAL STATEMENTS

Consolidated Balance Sheets (Unaudited)

	June 30,	December 31,
	2020	2019
	(in thousands except share amounts)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$4	$72
Restricted cash	49	49
Accounts receivable, net	138	446
Accounts receivable, related party	-	1,364
Prepaid expenses and other current assets	1,912	2,276
Deposits	224	158
Inventory	3,558	1,645
Refundable federal income tax	100	65
Total current assets	5,985	6,075
LONG-TERM ASSETS
Total property and equipment, net	63,601	63,893
Operating lease right-of-use assets	576	649
Restricted cash, noncurrent	547	547
Surety bonds	230	230
Deferred tax assets, net	-	50
Total long-term assets	64,954	65,369
TOTAL ASSETS	$70,939	$71,444
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES
Long-term debt less unamortized debt issue costs, current portion (in default)	$33,612	$33,836
Line of credit payable less unamortized debt issue costs (in default)	10,470	11,464
Long-term debt, related party, current portion (in default)	12,573	6,001
Interest payable (in default)	4,824	3,814
Interest payable, related party (in default)	2,494	2,174
Accounts payable	2,985	1,877
Accounts payable, related party	149	149
Current portion of lease liabilities	313	251
Asset retirement obligations, current portion	2,436	2,565
Accrued expenses and other current liabilities	2,775	3,333
Total current liabilities	72,631	65,464
LONG-TERM LIABILITIES
Long-term lease liabilities, net of current	470	564
Deferred revenues	1,748	1,930
Total long-term liabilities	2,218	2,494
TOTAL LIABILITIES	74,849	67,958
Commitments and contingencies (Note 16)
STOCKHOLDERS' EQUITY (DEFICIT)
Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 and 12,327,365
shares issued at June 30, 2020 and December 31, 2019, respectively)	127	123
Additional paid-in capital	38,457	38,275
Accumulated deficit	(42,494)	(34,912)
TOTAL STOCKHOLDERS' EQUITY (DEFICIT)	(3,910)	3,486
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)	$70,939	$71,444

The accompanying notes are an integral part of these consolidated financial statements.

Blue Dolphin Energy Company June 30, 2020

7

Financial Statements

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
	(in thousands, except share and per-share amounts)
REVENUE FROM OPERATIONS
Refinery operations	$17,359	$77,257	$78,256	$145,115
Tolling and terminaling	1,110	1,088	2,213	2,157
Total revenue from operations	18,469	78,345	80,469	147,272
COST OF GOODS SOLD
Crude oil, fuel use, and chemicals	16,783	76,364	76,503	139,551
Other conversion costs	2,893	2,192	5,261	4,521
Total cost of goods sold	19,676	78,556	81,764	144,072
Gross profit (deficit)	(1,207)	(211)	(1,295)	3,200
COST OF OPERATIONS
LEH operating fee	190	183	337	333
Other operating expenses	47	56	106	113
General and administrative expenses	531	579	1,175	1,249
Depletion, depreciation and amortization	669	633	1,302	1,223
Total cost of operations	1,437	1,451	2,920	2,918
Income (loss) from operations	(2,644)	(1,662)	(4,215)	282
OTHER INCOME (EXPENSE)
Easement, interest and other income	80	1	100	1
Interest and other expense	(1,678)	(1,638)	(3,452)	(2,835)
Total other expense	(1,598)	(1,637)	(3,352)	(2,834)
Loss before income taxes	(4,242)	(3,299)	(7,567)	(2,552)
Income tax expense	-	-	(15)	-
Net loss	$(4,242)	$(3,299)	$(7,582)	$(2,552)
Loss per common share:
Basic	$(0.34)	$(0.30)	$(0.61)	$(0.23)
Diluted	$(0.34)	$(0.30)	$(0.61)	$(0.23)
Weighted average number of common shares outstanding:
Basic	12,580,853	10,975,514	12,454,109	10,975,514
Diluted	12,580,853	10,975,514	12,454,109	10,975,514

The accompanying notes are an integral part of these consolidated financial statements.

Blue Dolphin Energy Company June 30, 2020

8

Financial Statements

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2020	2019
OPERATING ACTIVITIES
Net loss	$(7,582)	$(2,552)
Adjustments to reconcile net loss to net cash
used in operating activities:
Depletion, depreciation and amortization	1,302	1,223
Deferred income tax	15	-
Amortization of debt issue costs	284	189
Guaranty fees paid in kind	305	-
Deferred revenues and expenses	(182)	-
Gain on issuance of shares	(80)	-
Changes in operating assets and liabilities
Accounts receivable	308	209
Accounts receivable, related party	1,364	(492)
Prepaid expenses and other current assets	364	503
Deposits and other assets	(66)	-
Inventory	(1,913)	(287)
Accrued arbitration award	-	(11,600)
Accounts payable, accrued expenses and other liabilities	1,807	1,211
Accounts payable, related party	-	302
Net cash used in operating activities	(4,074)	(11,294)
INVESTING ACTIVITIES
Capital expenditures	(908)	(494)
Net cash used in investing activities	(908)	(494)
FINANCING ACTIVITIES
Proceeds from line of credit	-	12,402
Payments on debt	(1,501)	(541)
Net activity on related-party debt	6,415	229
Net cash provided by financing activities	4,914	12,090
Net change in cash, cash equivalents, and restricted cash	(68)	302

CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD 668 1,665

CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD	$600	$1,967
Supplemental Information:
Non-cash investing and financing activities:
Financing of capital expenditures via accounts payable and finance leases	$-	$86
Issuance of shares to extinguish debt	$120	$-
Conversion of related-party notes to common stock	$148	$-
Line of credit closing costs included in principal balance	$-	$398
Interest paid	$1,608	$1,174
Income taxes paid	$-	$-

The accompanying notes are an integral part of these consolidated financial statements.

Blue Dolphin Energy Company June 30, 2020

9

Notes to Consolidated Financial Statements

Notes to Consolidated Financial Statements

(1) 

Organization

Overview

Blue Dolphin is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operate a light sweet-crude, 15,000-bpd crude distillation tower with more than 1.2 million bbls of petroleum storage tank capacity in Nixon, Texas. Blue Dolphin was formed in 1986 as a Delaware corporation and is traded on the OTCQX under the ticker symbol “BDCO”. Blue Dolphin has 20.0 million shares of Common Stock and 2.5 million shares of Preferred Stock authorized. There are approximately 12.7 million shares of Common Stock and no shares of Preferred Stock issued and outstanding.

Our assets are primarily organized in two segments: refinery operations (owned by LE) and tolling and terminaling services (owned by LRM and NPS). Subsidiaries that are reflected in corporate and other include BDPL (inactive pipeline and facilities assets), BDPC (inactive leasehold interests in oil and gas wells), and BDSC (administrative services). See “Note (4)” to our consolidated financial statements for more information about our business segments.

Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours,” refer to Blue Dolphin, one or more of its consolidated subsidiaries or all of them taken as a whole.

Affiliates

Affiliates control approximately 82% of the voting power of our Common Stock. An Affiliate operates and manages all Blue Dolphin properties and funds working capital requirements during periods of working capital deficits, and an Affiliate is a significant customer of our refined products. Blue Dolphin and certain of its subsidiaries are currently parties to a variety of agreements with Affiliates. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and arrangements and working capital deficits.

Going Concern

Management has determined that certain factors raise substantial doubt about our ability to continue as a going concern. These factors include the following:

Defaults Under Secured Loan Agreements with Third Parties. Defaults under our secured loan agreements with third parties include loan agreements with Veritex in the original aggregate principal amount of $35.0 million, which are guaranteed 100% by the USDA, and a line of credit agreement with Pilot in the original principal amount of $13.0 million. Certain of our related-party debt is also in default. See “Note (3)” of our consolidated financial statements for disclosures related to related-party debt.

Veritex Loan Agreements. In September 2017, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex regarding events of default under our secured loan agreements, including, but not limited to, the occurrence of the GEL Final Arbitration Award, associated material adverse effect conditions, failure by LE to replenish a $1.0 million payment reserve account, and the occurrence of events of default under our other secured loan agreements with Veritex. Further, Veritex informed obligors that it would consider a final confirmation of the GEL Final Arbitration Award to be a material event of default under the loan agreements. Veritex did not accelerate or call due our secured loan agreements considering then ongoing settlement discussions between GEL and the Lazarus Parties. Instead, Veritex expressly reserved all its rights, privileges and remedies related to events of default.

In April 2019, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex that the bank agreed to waive certain covenant defaults and forbear from enforcing its remedies under our secured loan agreements subject to: (i) the agreement and concurrence of the USDA and (ii) the replenishment of the payment reserve account on or before August 31, 2019. Following the GEL Settlement, the associated mutual releases became effective and GEL filed the stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and the obligors were still in default under our secured loan agreements with Veritex.

In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

At June 30, 2020, LE and LRM were in violation of the debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants under our secured loan agreements with Veritex. As a result, the debt associated with these loans was classified within current portion of long-term debt on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

Blue Dolphin Energy Company June 30, 2020

10

Notes to Consolidated Financial Statements

We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Veritex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. Defaults under our secured loan agreements with Veritex permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. Any exercise by Veritex of its rights and remedies under our secured loan agreements would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. Further, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

Amended Pilot Line of Credit. On May 4, 2020, Pilot sent NPS, as borrower, and LRM, LEH, LE and Blue Dolphin, each a guarantor and collectively guarantors, a notice demanding the immediate payment of the unpaid principal amount and all interest accrued and unpaid, and all other amounts owing or payable (the “Obligations”) under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, the Obligations began to accrue interest at a rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor of paying the past due Obligations constituted an event of default. Pilot expressly retained and reserved all its rights and remedies available to it at any time, including without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity. Any exercise by Pilot of its rights and remedies under the Amended Pilot Line of Credit would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations.

On June 1, 2020, Pilot notified borrower and guarantors by letter of its intent to apply as a setoff Pilot’s payment obligations owing to or for the credit or the account of borrower under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May, 2019, between borrower and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between the borrower and Pilot, against the Obligations. As of the date of the letter, the amount of such setoff was approximately $0.2 million. The setoff was only in partial satisfaction of the Obligations and Pilot expressly retained and reserved all its rights and remedies available to it at any time, including, without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity.

The borrower and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue to work with the borrower to settle the Obligations. Borrower and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. Our ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. In the event we are unsuccessful in such endeavors, we may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

See “Note (10)” and “Note (11)” to our consolidated financial statements for additional information related to defaults under our secured loan agreements with Veritex and Pilot and their potential effects on our business, financial condition, and results of operations.

Margin Deterioration and Volatility. Steps taken to address the ongoing COVID-19 pandemic globally and nationally and the actions of members of the OPEC and other producer countries with respect to oil production and pricing significantly impacted supply and demand in global oil and gas markets, causing oil prices to decline sharply, as well as other changes to the economic outlook in the near term. Such subsequent developments included, but are not limited to, government-imposed temporary business closures and voluntary shelter-at-home directives as well as developments in production discussions between global oil producers, and the effect thereof. Oil prices as well as demand are expected to continue to be volatile as a result of the near-term over-supply and the ongoing COVID-19 pandemic as changes in oil inventories, industry demand and global and national economic performance are reported, and we cannot predict when prices and demand will improve and stabilize. We are currently unable to estimate the impact these events will have on our future financial position and results of operations. However, we expect margins will likely remain weak for the remainder of 2020 until global demand begins to recover. Accordingly, we can provide no assurances that these events will not have a material adverse effect on our financial position or results of operations.

Blue Dolphin Energy Company June 30, 2020

11

Notes to Consolidated Financial Statements

Net Losses and Working Capital Deficits.

Net Losses. Net loss for the three months ended June 30, 2020 was $4.2 million, or a loss of $0.34 per share, compared to a net loss of $3.3 million, or a loss of $0.30 per share, for the three months ended June 30, 2019. The increase in net loss was the result of less favorable margins per bbl and lower sales volume during the three months ended June 30, 2020 compared to the same period in 2019. Net loss for the six months ended June 30, 2020 was $7.6 million, or a loss of $0.61 per share, compared to a net loss of $2.6 million, or a loss of $0.23 per share, for the six months ended June 30, 2019. The significant increase in net loss was the result of less favorable margins per bbl and lower sales volume during the six-month period ended June 30, 2020 compared to the same period a year earlier.

Working Capital Deficits. We had a working capital deficit of $66.6 million and $59.4 million at June 30, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $20.5 million and $19.6 million at June 30, 2020 and December 31, 2019, respectively. We had cash and cash equivalents and restricted cash (current portion) of less than $0.01 million and $0.05 million, respectively, at June 30, 2020. Comparatively, we had cash and cash equivalents and restricted cash (current portion) of $0.07 million and $0.05 million, respectively, at December 31, 2019.

Operating Risks

Successful execution of our business strategy depends on several key factors, including, having adequate working capital to meet operational needs and regulatory requirements, maintaining safe and reliable operations at the Nixon facility, meeting contractual obligations, and having favorable margins on refined products. As discussed under “Note (1) – Going Concern” above and throughout this report, we are currently unable to estimate the impact the ongoing COVID-19 pandemic will have on our future financial position and results of operations. Our business was deemed as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. Management has taken and continues to take all prudent steps, however, there can be no assurance that our business strategy will be successful, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. Further, if Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

(2) 

Principles of Consolidation and Significant Accounting Policies

Basis of Presentation

The accompanying unaudited consolidated financial statements, which include Blue Dolphin and its subsidiaries, have been prepared in accordance with GAAP for interim consolidated financial information pursuant to the rules and regulations of the SEC under Article 10 of Regulation S-X and the instructions to Form 10-Q. Accordingly, certain information and footnote disclosures normally included in our audited financial statements have been condensed or omitted pursuant to the SEC’s rules and regulations. Significant intercompany transactions have been eliminated in the consolidation. In management’s opinion, all adjustments considered necessary for a fair presentation have been included, disclosures are adequate, and the presented information is not misleading.

The consolidated balance sheet as of December 31, 2019 was derived from the audited financial statements at that date. The accompanying consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 as filed with the SEC. Operating results for the three and six months ended June 30, 2020 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2020, or for any other period. As discussed further below within this “Note (2) – Use of Estimates,” the ongoing COVID-19 pandemic has resulted in significant economic disruption globally. This disruption became more acute in the latter half of March 2020; therefore, our operating results for the three and six months ended June 30, 2020 do not fully reflect the impact this disruption has had, and will likely continue to have, on us.

Significant Accounting Policies

The summary of significant accounting policies of Blue Dolphin is presented to assist in understanding our consolidated financial statements. Our consolidated financial statements and accompanying notes are representations of management, who is responsible for their integrity and objectivity. These accounting policies conform to GAAP and have been consistently applied in the preparation of our consolidated financial statements.

Use of Estimates. The ongoing COVID-19 pandemic and certain developments in the global oil markets have impacted and continue to impact our business. Our business was designated as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable to predict the ultimate economic impact of COVID-19 on our business.

Blue Dolphin Energy Company June 30, 2020

12

Notes to Consolidated Financial Statements

The nature of our business requires that we make estimates and assumptions in accordance with U.S. GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenue and expenses during the reporting period. The ongoing COVID-19 pandemic has impacted these estimates and assumptions and will continue to do so.

We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of COVID-19 as of June 30, 2020 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.

Cash and Cash Equivalents. Cash and cash equivalents represent liquid investments with an original maturity of three months or less. Cash balances are maintained in depository and overnight investment accounts with financial institutions that, at times, may exceed insured deposit limits. We monitor the financial condition of the financial institutions and have experienced no losses associated with these accounts.

Restricted Cash. Restricted cash, current portion primarily represents a payment reserve account held by Veritex as security for payments under a loan agreement. Restricted cash, noncurrent represents funds held in the Veritex disbursement account for payment of construction related expenses to complete building new petroleum storage tanks.

Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable are presented net of any necessary allowance(s) for doubtful accounts. Receivables are recorded at the invoiced amount and generally do not bear interest. An allowance for doubtful accounts is established, when necessary, based on prior experience and other factors which, in management's judgment, deserve consideration in estimating bad debts.  Management assesses collectability of the customer’s account based on current aging status, collection history, and financial condition.  Based on a review of these factors, management establishes or adjusts the allowance for specific customers and the entire accounts receivable portfolio.  We had an allowance for doubtful accounts of $0.1 million at both June 30, 2020 and December 31, 2019.

Inventory. Inventory primarily consists of refined products, crude oil and condensate, and chemicals. Inventory is valued at lower of cost or net realizable value with cost determined by the average cost method, and net realizable value determined based on estimated selling prices less associated delivery costs. If the net realizable value of our refined products inventory declines to an amount less than our average cost, we record a write-down of inventory and an associated adjustment to cost of goods sold. See “Note (7)” to our consolidated financial statements for additional disclosures related to inventory.

Property and Equipment.

Refinery and Facilities. We plan to continue making improvements to the crude distillation tower based on operational needs and technological advances. Additions to refinery and facilities assets are capitalized, and expenditures for repairs and maintenance are expensed as incurred. We record refinery and facilities at cost less any adjustments for depreciation or impairment. Adjustment of the asset and the related accumulated depreciation accounts are made for the refinery and facilities asset’s retirement and disposal, with the resulting gain or loss included in the consolidated statements of operations. For financial reporting purposes, depreciation of refinery and facilities assets is computed using the straight-line method using an estimated useful life of 25 years beginning when the refinery and facilities assets are placed in service. We did not record any impairment of our refinery and facilities assets for the periods presented.

Pipelines and Facilities. Our pipelines and facilities are recorded at cost less any adjustments for depreciation or impairment. Depreciation is computed using the straight-line method over estimated useful lives ranging from 10 to 22 years. In accordance with FASB ASC guidance we performed periodic impairment testing of our pipeline and facilities assets in 2016. Upon completion of testing, our pipeline assets were fully impaired at December 31, 2016. All pipeline transportation services to third parties have ceased, existing third-party wells along our pipeline corridor have been permanently abandoned, and no new third-party wells are being drilled near our pipelines. We plan to decommission the offshore pipelines and platform assets in the third quarter of 2020.

Oil and Gas Properties. Our oil and gas properties are accounted for using the full-cost method of accounting, whereby all costs associated with acquisition, exploration and development of oil and gas properties, including directly related internal costs, are capitalized on a cost center basis.  Amortization of such costs and estimated future development costs are determined using the unit-of-production method. All leases associated with our oil and gas properties have expired, and our oil and gas properties were fully impaired in 2011.

CIP. CIP expenditures, including capitalized interest, relate to construction and refurbishment activities and equipment for the Nixon facility. These expenditures are capitalized as incurred. Depreciation begins once the asset is placed in service. See “Note (8)” to our consolidated financial statements for additional disclosures related to our refinery and facilities assets, oil and gas properties, pipelines and facilities assets, and CIP.

Blue Dolphin Energy Company June 30, 2020

13

Notes to Consolidated Financial Statements

Leases. We evaluate if a contract is or contains a lease at inception of the contract. If we determine that a contract is or contains a lease, we recognize ROU asset and lease liability at the commencement date of the lease based on the present value of lease payments over the lease term. The present value of the lease payments is determined by using the implicit rate when readily determinable. If not determinable, we use the incremental borrowing rate to discount lease payments to present value. Lease terms include options to extend or terminate the lease when it is reasonably certain that we will exercise those options.

We recognize ROU assets and lease liabilities for leasing arrangements with terms greater than one year. We account for lease and non-lease components in a contract as a single lease component for all classes of underlying assets. We allocate the consideration in these contracts based on pricing information contained in the lease.

Expense for an operating lease is recognized as a single lease cost on a straight-line basis over the lease term and is reflected in the appropriate income statement line item based on the leased asset’s function. Amortization expense of a finance lease ROU asset is recognized on a straight-line basis over the lesser of the useful life of the leased asset or the lease term. However, if the lease transfers ownership of the finance lease ROU asset to us at the end of the lease term, the finance lease ROU asset is amortized over the useful life of the leased asset. Amortization expense is reflected in ‘depreciation and amortization expense.’ Interest expense is incurred based on the carrying value of the lease liability and is reflected in ‘interest and other expense.’

Revenue Recognition.

Refinery Operations Revenue. Revenue from the sale of refined products is recognized when the product is sold to the customer in fulfillment of performance obligations. Each load of refined product is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are met when control is transferred to the customer. Control is transferred to the customer when the product has been lifted or, in cases where the product is not lifted immediately (bill and hold arrangements), when the product is added to the customer’s bulk inventory as stored at the Nixon facility.

We consider a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the refined product, the transfer of significant risks and rewards, our rights to payment, and transfer of legal title. In each case, the term between the sale and when payment is due is not significant. Transportation, shipping, and handling costs incurred are included in cost of goods sold. Excise and other taxes that are collected from customers and remitted to governmental authorities are not included in revenue.

Tolling and Terminaling Revenue. Tolling and terminaling revenue represents fees pursuant to: (i) tank storage agreements, whereby a customer agrees to pay a certain fee per tank based on tank size over a period of time for the storage of products and (ii) tolling agreements, whereby a customer agrees to pay a certain fee per gallon or barrel for throughput volumes moving through the naphtha stabilizer unit and a fixed monthly reservation fee for use of the naphtha stabilizer unit.

We typically satisfy performance obligations for tolling and terminaling operations with the passage of time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the term of the agreement. We allocate the transaction price to the single performance obligation that exists under the agreement, and we recognize revenue in the amount for which we have a right to invoice. Generally, payment terms do not exceed 30 days.

Revenue from tank storage customers may, from time to time, include fees for ancillary services, such as in-tank and tank-to-tank blending. These services are considered optional to the customer, and the price we charge for such services is not included in the fixed cost under the customer’s tank storage agreement. Ancillary services are considered a separate performance obligation by us under the tank storage agreement. The performance obligation is satisfied when the requested service has been performed in the applicable period.

Deferred Revenue. We record deferred revenue when cash payments are received or due in advance of our performance. An increase in the deferred revenue balance reflects cash payments received or due in advance of satisfying our performance obligations, offset by recognized revenue that was included in the deferred revenue balance at the beginning of the period. Deferred revenue represents a liability as of the balance sheet date related to a revenue producing activity for which revenue has not yet been recognized. We record deferred revenue when we receive consideration under a contract before achieving certain criteria that must be met for revenue to be recognized in conformity with GAAP.

Income Taxes. Deferred income taxes are determined based on the differences between the financial reporting and tax basis of assets and liabilities, as well as operating losses and tax credit carryforwards using currently enacted tax rates and laws in effect for the year in which the differences are expected to reverse. We record a valuation allowance against deferred income tax assets if it is more likely than not that those assets will not be realized. The provision for income taxes comprises our current tax liability and change in deferred income tax assets and liabilities.

Blue Dolphin Energy Company June 30, 2020

14

Notes to Consolidated Financial Statements

Significant judgment is required in evaluating uncertain tax positions and determining its provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to determine the realizability of deferred tax assets. We consider whether it is more likely than not that a portion or all the deferred tax assets will be realized, which is dependent upon the generation of future taxable income prior to the expiration of any NOL carryforwards. When we determine that it is more likely than not that a tax benefit will not be realized, a valuation allowance is recorded to reduce deferred tax assets. A significant piece of objective negative evidence evaluated was cumulative losses incurred over the three-year period ended June 30, 2020. Such objective evidence limits the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of June 30, 2020 and December 31, 2019. We expect to recover deferred tax assets related to AMT credit carryforwards. In addition, we have NOL carryforwards that remain available for future use.

The benefit of an uncertain tax position is recognized in the financial statements if it meets a minimum recognition threshold. A determination is first made as to whether it is more likely than not that the income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If the income tax position is expected to meet the more-likely-than-not criteria, the benefit recorded in the financial statements equals the largest amount that is greater than 50% likely to be realized upon its ultimate settlement. At June 30, 2020 and December 31, 2019, there were no uncertain tax positions for which a reserve or liability was necessary. See “Note (14)” to our consolidated financial statements for more information related to income taxes.

Impairment or Disposal of Long-Lived Assets. We periodically evaluate our long-lived assets for impairment. Additionally, we evaluate our long-lived assets when events or circumstances indicate that the carrying value of these assets may not be recoverable. The carrying value is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset or group of assets is recognized. Significant management judgment is required in the forecasting of future operating results that are used in the preparation of projected cash flows and, should different conditions prevail or judgments be made, material impairment charges could be necessary. The GEL Final Arbitration Award represented a significant adverse change that could have affected the value of certain of our long-lived assets, and management performed potential impairment testing of our refinery and facilities assets in 2019 and 2018. Upon completion of each testing, no impairment was deemed necessary. In addition, the market volatility of crude oil prices as a result of the ongoing COVID-19 pandemic could have affected the value of certain of our long-lived assets, and management performed impairment testing of our refinery and facilities assets at June 30, 2020. No impairment was deemed necessary based upon June 30, 2020 testing, and we did not record any impairment of our refinery and facilities assets for the periods presented.

Asset Retirement Obligations. We record a liability for the discounted fair value of an ARO in the period incurred, and we also capitalize the corresponding cost by increasing the carrying amount of the related long-lived asset. The liability is accreted towards its future value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

We have concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Further, we believe that these assets have indeterminate lives because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.

We recorded an ARO liability related to future asset retirement costs associated with dismantling, relocating, or disposing of our offshore platform, pipeline systems, and related onshore facilities, as well as for plugging and abandoning wells and restoring land and sea-beds. Cost estimates for each of our assets were developed based upon regulatory requirements, structural makeup, water depth, reservoir characteristics, reservoir depth, equipment demand, current retirement procedures, and construction and engineering consultations. Estimating future costs are difficult and require management to make judgments that are subject to future revisions based upon numerous factors, including changing technology, political, and regulatory environments. We review our assumptions and estimates of future abandonment costs on an annual basis. See “Note (12)” to our consolidated financial statements for additional information related to AROs.

Computation of Earnings Per Share. We present basic and diluted EPS. Basic EPS excludes dilution and is computed by dividing net income available to common stockholders by the weighted-average number of shares of common stock outstanding for the period. Diluted EPS is computed by dividing net income available to common stockholders by the diluted weighted average number of common shares outstanding, which includes the potential dilution that could occur if securities or other contracts to issue shares of common stock were converted to common stock that then shared in the earnings of the entity. The number of shares related to restricted stock included in diluted EPS is based on the “Treasury Stock Method.” We do not have issued options, warrants, or similar instruments. See “Note (15)” to our consolidated financial statements for additional information related to EPS.

Blue Dolphin Energy Company June 30, 2020

15

Notes to Consolidated Financial Statements

New Pronouncements Adopted. The FASB issues an ASU to communicate changes to the FASB ASC, including changes to non-authoritative SEC content. Recently adopted ASUs include:

Codification Updates to SEC Sections. In July 2019, FASB issued ASU 2019-07, Codification Updates to SEC Sections, which amended certain SEC sections or paragraphs within the FASB ASC. The amendments were made pursuant to SEC Final Rule Releases No. 33-10532, Disclosure Update and Simplification, and Nos. 33-10231 and 33-10442, Investment Company Reporting Modernization, and Miscellaneous Updates (SEC Update). The SEC Final Rule Releases, which required improvements to the XBRL taxonomy, were made to improve, update, and simplify SEC regulations on financial reporting and disclosure. For public companies, the amendments in ASU 2019-07 were effective upon issuance. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

Consolidation. In October 2018, FASB issued ASU 2018-17,Consolidation (Topic 810). This ASU provided targeted improvements to related-party guidance for variable interest entities. Indirect interests held through related parties in common control arrangements are considered on a proportional basis for determining whether fees paid to decision makers and service providers are variable interests. For entities other than private companies, the amendments in ASU 2018-17 were effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

New Pronouncements Issued, Not Yet Effective.

Income Taxes. In March 2018, FASB issued ASU 2018-05,Income Taxes (Topic 740). This guidance amends SEC paragraphs in ASC 740, Income Taxes, to reflect Staff Accounting Bulletin No. 118, which provides guidance for companies that are not able to complete their accounting for the income tax effects of the Tax Cuts and Jobs Act in the period of enactment.  This guidance also includes amendments to the XBRL taxonomy.  For public business entities, the amendments in ASU 2018-05 are effective for fiscal years ending after December 15, 2020. Early adoption is permitted.  We do not expect adoption of this guidance to have a significant impact on our consolidated financial statements.

Other new pronouncements issued but not yet effective are not expected to have a material impact on our financial position, results of operations, or liquidity.

Remainder of Page Intentionally Left Blank

Blue Dolphin Energy Company June 30, 2020

16

Notes to Consolidated Financial Statements

(3) 

Related-Party Transactions

Working Capital

Currently, we depend on Affiliates for financing when revenue from operations and borrowings under bank facilities are insufficient to meet our liquidity and working capital needs. Such borrowings are reflected in our consolidated balance sheets in accounts payable, related party, and/or long-term debt, related party.

Affiliate Agreements/Transactions

Blue Dolphin and certain of its subsidiaries are party to several agreements with Affiliates. Management believes that these related-party transactions were consummated on terms equivalent to those that prevail in arm's-length transactions. Related-party transactions consist of the following:

Agreement/Transaction	Parties	Type	Effective Date	Interest Rate	Key Terms
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LE	Debt	04/01/2017	2.00%	Tied to payoff of LE $25 million Veritex loan; payments 50% cash, 50% Common Stock
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LRM	Debt	04/01/2017	2.00%	Tied to payoff of LRM $10 million Veritex loan; payments 50% cash, 50% Common Stock
Refinery Equipment Purchase	LTRI - LE	Operations	07/01/2019	---	LE purchase of two (2) refurbished heat exchangers for $0.08 million each
Dock Tolling Agreement	LMT - LE	Operations	05/24/2016	---	5-year term cancellable by either party any time; LE paid flat reservation fee for tolling volumes up to 84,000 gallons per day; excess tolling volumes subject to increased per gallon rate; terminated 07/01/2019
Jet Fuel Sales Agreement	LEH - LE	Operations	04/01/2020	---	1-year term expiring earliest to occur of 03/31/2021 plus 30-day carryover or delivery of maximum jet fuel quantity; LEH bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification
March Carroll Note (in default)	Jonathan Carroll – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; matured 01/01/2019; interest still accruing
March Ingleside Note (in default)	Ingleside – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to Ingleside under previous Amended and Restated Tank Lease Agreement; matured 01/01/2019; interest still accruing
June LEH Note (in default)	LEH – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; reflects amounts owed to Jonathan Carroll under guaranty fee agreements; matured 01/01/2019; interest still accruing
Office Sub-Lease Agreement	LEH - BDSC	Operations	01/01/2018	---	68-month term expiring 08/31/2023; office lease Houston, Texas; includes 6-month rent abatement period; rent approximately $0.02 million per month
Amended and Restated Operating Agreement	LEH – Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC	Debt	04/01/2020	---	3-year term; expires 04/01/2023 or notice by either party at any time of material breach or 90 days Board notice; LEH receives management fee of 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest, of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC
Loan and Security Agreement (in default)	LEH - BDPL	Debt	08/15/2016	16.00%	2-year term; $4.0 million principal amount; $0.5 million annual payment; proceeds used for working capital; no financial maintenance covenants; secured by certain BDPL property

(1) 

On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note.

Blue Dolphin Energy Company June 30, 2020

17

Notes to Consolidated Financial Statements

Related-Party Financial Impact

Consolidated Balance Sheets.

Accounts receivable, related party. Accounts receivable, related party totaled $0 and $1.4 million at June 30, 2020 and December 31, 2019, respectively. At December 31, 2019, accounts receivable, related party represented amounts owed from LEH for the sale of jet fuel under the Jet Fuel Sales Agreement.  Amounts are settled under normal business terms.  Amounts outstanding relating to the Jet Fuel Sales Agreement can vary significantly period to period based on the timing of the related sales and payments received.  See below for the total amount owed to LEH under the June LEH Note and the BDPL Loan Agreement.

Accounts payable, related party. Accounts payable, related party to LTRI related to the purchase of refinery equipment totaled $0.2 million at both June 30, 2020 and December 31, 2019.

Long-term debt, related party, current portion (in default) and accrued interest payable, related party.

	June 30,	December 31,
	2020	2019
	(in thousands)
LEH
June LEH Note (in default)	$6,336	$-
BDPL Loan Agreement	6,494	6,174
LEH Total	12,830	6,174
Ingleside
March Ingleside Note (in default)	1,039	1,004
Jonathan Carroll
March Carroll Note (in default)	1,198	997
	15,067	8,175
Less: Long-term debt, related party, current portion, in default	(12,573)	(6,001)
Less: Accrued interest payable, related party (in default)	(2,494)	(2,174)
	$-	$-

Consolidated Statements of Operations.

Total revenue from operations.

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
Refinery operations
LEH	$4,587	24.8%	$24,173	30.2%	$22,302	27.7%	$44,982	30.2%
Third-Parties	12,772	69.2%	53,084	68.3%	55,954	69.5%	100,133	68.3%
Tolling and terminaling
Third-Parties	1,110	6.0%	1,088	1.5%	2,213	2.8%	2,157	1.5%
	$18,469	100.0%	$78,345	100.0%	$80,469	100.0%	$147,272	100.0%

Interest expense.

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
	(in thousands)
Jonathan Carroll
Guaranty Fee Agreements
First Term Loan Due 2034	$108	$111	$216	$223
Second Term Loan Due 2034	44	46	89	92
March Carroll Note (in default)	20	28	43	53
LEH
BDPL Loan Agreement (in default)	160	160	320	320
June LEH Note (in default)	117	16	142	23
Ingleside
March Ingleside Note (in default)	15	26	35	52
	$464	$387	$845	$763

Blue Dolphin Energy Company June 30, 2020

18

Notes to Consolidated Financial Statements

 

Other. Fees associated with the Dock Tolling Agreement with LMT totaled $0 and $0.2 million for the three months ended June 30, 2020 and 2019, respectively. Fees associated with the Dock Tolling Agreement with LMT totaled $0 and $0.4 million for the six months ended June 30, 2020 and 2019, respectively.

Lease payments received under the office sub-lease agreement with LEH totaled approximately $0.01 million for both three-month periods ended June 30, 2020 and 2019. Lease payments received under the office sub-lease agreement with LEH totaled approximately $0.02 million for both six-month periods ended June 30, 2020 and 2019.

The LEH operating fee was flat, totaling approximately $0.2 million for both three-month periods ended June 30, 2020 and 2019. The LEH operating fee was also relatively flat, totaling approximately $0.3 million for both six-month periods ended June 30, 2020 and 2019.

(4) 

Revenue and Segment Information

We have two reportable business segments: (i) refinery operations and (ii) tolling and terminaling. Refinery operations relate to the refining and marketing of petroleum products at our 15,000-bpd crude distillation tower. Tolling and terminaling operations relate to tolling and storage terminaling services under third-party lease agreements. Both operations are conducted at the Nixon facility. Corporate and other includes BDSC, BDPL and BDPC.

Revenue from Contracts with Customers

Disaggregation of Revenue. Revenue is presented in the table below under “Segment Information” disaggregated by business segment because this is the level of disaggregation that management has determined to be beneficial to users of our financial statements.

Receivables from Contracts with Customers. Our receivables from contracts with customers are presented as receivables, net on our consolidated balance sheets.

Contract Liabilities. Our contract liabilities from contracts with customers are included in accrued expenses and presented in “Note (9)” to our consolidated financial statements.

Remaining Performance Obligations. Most of our contracts with customers are spot contracts and therefore have no remaining performance obligations.

Remainder of Page Intentionally Left Blank

Blue Dolphin Energy Company June 30, 2020

19

Notes to Consolidated Financial Statements

Segment Information. Business segment information for the periods indicated (and as of the dates indicated) was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
	(in thousands)
Net revenue (excluding intercompany fees and sales)
Refinery operations	$17,359	$77,257	$78,256	$145,115
Tolling and terminaling	1,110	1,088	2,213	2,157
Total net revenue	18,469	78,345	80,469	147,272
Intercompany fees and sales
Refinery operations	(406)	(653)	(1,023)	(1,259)
Tolling and terminaling	406	653	1,023	1,259
Total intercompany fees	-	-	-	-
Operation costs and expenses(1)
Refinery operations	(19,418)	(78,376)	(81,251)	(143,528)
Tolling and terminaling	(258)	(363)	(513)	(727)
Corporate and other	(47)	(56)	(106)	(113)
Total operation costs and expenses	(19,723)	(78,795)	(81,870)	(144,368)
Segment contribution margin (deficit)
Refinery operations	(2,465)	(1,772)	(4,018)	328
Tolling and terminaling	1,258	1,378	2,723	2,689
Corporate and other	(47)	(56)	(106)	(113)
Total segment contribution margin (deficit)	(1,254)	(450)	(1,401)	2,904
General and administrative expenses(2)
Refinery operations	(327)	(274)	(631)	(606)
Tolling and terminaling	(68)	(62)	(136)	(105)
Corporate and other	(326)	(243)	(745)	(688)
Total general and administrative expenses	(721)	(579)	(1,512)	(1,399)
Depreciation and amortization
Refinery operations	(294)	(483)	(582)	(948)
Tolling and terminaling	(324)	(99)	(618)	(198)
Corporate and other	(51)	(51)	(102)	(77)
Total depreciation and amortization	(669)	(633)	(1,302)	(1,223)
Interest and other non-operating expenses, net
Refinery operations	(751)	(823)	(1,492)	(1,606)
Tolling and terminaling	(616)	(579)	(1,386)	(775)
Corporate and other	(231)	(235)	(474)	(453)
Total interest and other non-operating expenses, net	(1,598)	(1,637)	(3,352)	(2,834)
Income (loss) before income taxes
Refinery operations	(3,837)	(3,352)	(6,723)	(2,832)
Tolling and terminaling	250	638	583	1,611
Corporate and other	(655)	(585)	(1,427)	(1,331)
Total loss before income taxes	(4,242)	(3,299)	(7,567)	(2,552)
Income tax expense	-	-	(15)	-
Net loss	$(4,242)	$(3,299)	$(7,582)	$(2,552)

(1) 

Operation costs include cost of goods sold. Also, operation costs within: (a) tolling and terminaling includes terminal operating expenses and an allocation of other costs (e.g. insurance and maintenance) and (b) corporate and other includes expenses related to BDSC, BDPC and BDPL.

(2) 

General and administrative expenses within refinery operations include the LEH operating fee.

Blue Dolphin Energy Company June 30, 2020

20

Notes to Consolidated Financial Statements

	Six Months Ended
	June 30,
	2020	2019
	(in thousands)
Capital expenditures
Refinery operations	$292	$411
Tolling and terminaling	616	83
Corporate and other	-	-
Total capital expenditures	$908	$494

	June 30,	December 31,
	2020	2019
	(in thousands)
Identifiable assets
Refinery operations	$50,341	$51,317
Tolling and terminaling	18,750	18,401
Corporate and other	1,848	1,726
Total identifiable assets	$70,939	$71,444

(5) 

Concentration of Risk

Bank Accounts

Financial instruments that potentially subject us to concentrations of risk consist primarily of cash, trade receivables and payables. We maintain cash balances at financial institutions in Houston, Texas. The FDIC insures certain financial products up to a maximum of $250,000 per depositor. At both June 30, 2020 and December 31, 2019, we had cash balances (including restricted cash) that exceeded the FDIC insurance limit per depositor of approximately $0.3 million.

Key Supplier

Operation of the Nixon refinery depends on our ability to purchase adequate amounts of crude oil and condensate. We have a long-term crude supply agreement in place with Pilot. Under the initial term of the crude supply agreement, Pilot will sell us approximately 24.8 million net bbls of crude oil. Thereafter, the crude supply agreement will continue on a one-year evergreen basis. Effective March 1, 2020, Pilot assigned its rights, title, interest, and obligations in the crude supply agreement to Tartan Oil LLC, a Pilot affiliate. Either party may terminate the crude supply agreement by providing the other party 60 days prior written notice.

Pilot also stores crude oil at the Nixon facility under two terminal services agreements. Under the terminal services agreements, Pilot stores crude oil at the Nixon facility at a specified rate per bbl of the storage tank’s shell capacity. Although the initial term of the terminal services agreement expired April 30, 2020, the agreement renewed on a one-year evergreen basis. Either party may terminate the terminal services agreement by providing the other party 60 days prior written notice. However, the terminal services agreement will automatically terminate upon expiration or termination of the crude supply agreement. During the second quarter of 2020, Pilot applied as a setoff Pilot’s payment obligations owed to us under the terminal services agreements between us and Pilot. The setoff was in partial satisfaction of our obligations to Pilot under the Amended Pilot Line of Credit. As of June 1, 2020, the amount of such setoff was approximately $0.2 million. See ‘going concern’ within “Note (1)” to our consolidated financial statements for additional disclosures related to defaults in our debt obligations.

Our financial health could be materially and adversely affected by defaults in our secured loan agreements, margin deterioration and volatility, historic net losses and working capital deficits, as well as termination of the crude supply agreement or terminal services agreement with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, a sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations.

Significant Customers

We routinely assess the financial strength of our customers and have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.

	Number Significant Customers	% Total Revenue from Operations	Portion of Accounts Receivable at Date Indicated
Three Months Ended June 30, 2020	3	69%	$0
Three Months Ended June 30, 2019	4	97%	$0.6 million
Six Months Ended June 30, 2020	4	90%	$0.006 million
Six Months Ended June 30, 2019	4	97%	$0.6 million

Blue Dolphin Energy Company June 30, 2020

21

Notes to Consolidated Financial Statements

 

One of our significant customers is an Affiliate. The Affiliate, LEH, purchases our jet fuel under a Jet Fuel Sales Agreement and bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification. LEH accounted for nearly 25% and 31% of our total revenue from operations for the three months ended June 30, 2020 and 2019, respectively. LEH accounted for nearly 28% and 31% of our total revenue from operations for the six months ended June 30, 2020 and 2019, respectively. LEH represented $0 in accounts receivable at June 30, 2020. LEH represented $0.5 million in accounts receivable at June 30, 2019.

Amounts outstanding relating to the Jet Fuel Sales Agreement can vary significantly period to period based on the timing of the related sales and payments received. The amounts are settled under normal business terms. The total amount owed to LEH under the June LEH Note and the BDPL Loan Agreement totaled $12.8 million and $6.2 million at June 30, 2020 and December 31, 2019, respectively. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to transactions with Affiliates.

Concentration of Customers. Our operations have a concentration of customers who are refined petroleum product wholesalers. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that these customers may be similarly affected by changes in economic or other conditions including the uncertainties concerning COVID-19 and volatility in the global oil markets. Historically, we have not had any significant problems collecting our accounts receivable.

Refined Product Sales. We sell our products primarily in the U.S. within PADD 3. Occasionally we sell refined products to customers that export to Mexico. Total refined product sales by distillation (from light to heavy) for the periods indicated consisted of the following:

	Three Months Ended June 30,				Six Months Ended Ended June 30,
	2020		2019		2020		2019
	(in thousands, except percent amounts)
LPG mix	$-	0.0%	$1	0%	$-	0.0%	$9	0%
Naphtha	3,160	18.2%	15,416	20.3%	14,675	18.8%	29,211	20.1%
Jet fuel	4,587	26.4%	24,173	30.7%	22,302	28.5%	44,982	31.0%
HOBM	3,691	21.3%	16,747	23.8%	18,882	24.1%	32,907	22.7%
AGO	5,921	34.1%	20,920	25.2%	22,397	28.6%	38,006	26.2%
	$17,359	100.0%	$77,257	100.0%	$78,256	100.0%	$145,115	100.0%

An Affiliate, LEH, purchases all of our jet fuel. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate transactions.

(6) 

Prepaid Expenses and Other Current Assets

Prepaid expenses and other current assets as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
Prepaid insurance	$1,691	$417
Other prepaids	111	87
Prepaid easement renewal fees	110	121
Prepaid crude oil and condensate	-	1,651
	$1,912	$2,276

(7) 

Inventory

Inventory as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
HOBM	$2,833	$-
Crude oil and condensate	445	959
Chemicals	227	120
AGO	38	440
Propane	12	26
LPG mix	3	5
Naphtha	-	95
	$3,558	$1,645

Due to fluctuating commodity prices, we recorded a net realizable value adjustment to inventory of approximately $0.2 million and $0.3 million at June 30, 2020 and December 31, 2019, respectively.

Blue Dolphin Energy Company June 30, 2020

22

Notes to Consolidated Financial Statements

(8) 

Property, Plant and Equipment, Net

Property, plant and equipment, net, as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
Refinery and facilities	$71,254	$66,317
Land	566	566
Other property and equipment	833	833
	72,653	67,716
Less: Accumulated depletion, depreciation, and amortiation	(13,938)	(12,739)
	58,715	54,977
CIP	4,886	8,916
	$63,601	$63,893

We capitalize interest cost incurred on funds used to construct property, plant, and equipment. Capitalized interest is recorded as part of the asset it relates to and is depreciated over the asset’s useful life. Capitalized interest cost, which is included in CIP, was $0 and $0.7 million at June 30, 2020 and December 31, 2019. Capital expenditures for expansion at the Nixon facility were funded by long-term debt from Veritex, revenue from operations, and working capital from Affiliates. At June 30, 2020, unused amounts for capital expenditures derived from Veritex loans were reflected in restricted cash (current and non-current portions) on our consolidated balance sheets. See “Note (10)” to our consolidated financial statements for additional disclosures related to working capital deficits and borrowings for capital spending.

(9) 

Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
Insurance	$1,079	$159
Unearned revenue from contracts with customers	643	1,990
Unearned contract renewal income	500	500
Property, fuel and other taxes	331	183
Other payable	177	228
Board of director fees payable	35	263
Customer deposits	10	10
	$2,775	$3,333

Remainder of Page Intentionally Left Blank

Blue Dolphin Energy Company June 30, 2020

23

Notes to Consolidated Financial Statements

(10) 

Third-Party Long-Term Debt

Loan Agreements

Loan Description	Original Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$25.0	Jun 2034	$0.2 million	WSJ Prime + 2.75%	Refinance loan; capital improvements
Second Term Loan Due 2034 (in default)	$10.0	Dec 2034	$0.1 million	WSJ Prime + 2.75%	Refinance bridge loan; capital improvements
Notre Dame Debt (in default)	$11.7(1)	Jan 2018	No payments to date; payment rights subordinated(2)	16.00%	Working capital; reduced balance of GEL Final Arbitration Award

(1) 

Original principal amount was $8.0 million; pursuant to a 2017 sixth amendment, the Notre Dame Debt was amended to increase the principal amount by $3.7 million; the additional principal was used to reduce the GEL Final Arbitration Award by $3.6 million.

(2) 

Pursuant to a 2015 subordination agreement, the holder of the Notre Dame Debt agreed to subordinate their right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in favor of Veritex as holder of the First Term Loan Due 2034.

Guarantees and Security

Loan Description	Guarantees	Security
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	● 100% USDA-guarantee; ● Jonathan Carroll personal guarantee(1); ● LEH, LRM and Blue Dolphin cross-guarantee	● first priority lien on Nixon facility’s business assets (excluding accounts receivable and inventory); ● assignment of all Nixon facility contracts, permits, and licenses; ● absolute assignment of Nixon facility rents and leases, including tank rental income; ● $1.0 million payment reserve account held by Veritex; and ● $5.0 million life insurance policy on Jonathan Carroll.
Second Term Loan Due 2034 (in default)	● 100% USDA-guarantee; ● Jonathan Carroll personal guarantee(1); ● LEH, LE and Blue Dolphin cross-guarantee	● second priority lien on rights of LE in crude distillation tower and other collateral of LE; ● first priority lien on real property interests of LRM; ● first priority lien on all LRM fixtures, furniture, machinery and equipment; ● first priority lien on all LRM contractual rights, general intangibles and instruments, except with respect to LRM rights in its leases of certain specified tanks for which Veritex has second priority lien; and ● all other collateral as described in the security documents.
Notre Dame Debt (in default)	---	● Subordinated deed of trust that encumbers the crude distillation tower and general assets of LE(2).

(1) 

As a condition of the First Term Loan Due 2034 and Second Term Loan Due 2034, Jonathan Carroll was required to personally guarantee repayment borrowed funds and accrued interest.

(2) 

Pursuant to a 2015 subordination agreement, the holder of the Notre Dame Debt agreed to subordinate their right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in favor of Veritex as holder of the First Term Loan Due 2034.

The USDA, acting through its agencies, administers a federal rural credit program that makes direct loans and guarantees portions of loans made and serviced by USDA-qualified lenders for various purposes. Each USDA guarantee is a full faith and credit obligation of the U.S. with the USDA guaranteeing up to 100% of the principal amount. The lender for a USDA-guaranteed loan, in our case Veritex, is required by regulations to retain both the guaranteed and unguaranteed portions of the loan, to service the entire underlying loan, and to remain mortgage and/or secured party of record. Both the guaranteed and unguaranteed portions of the loan are to be secured by the same collateral with equal lien priority. The USDA-guaranteed portion of a loan cannot be paid later than, or in any way be subordinated to, the related unguaranteed portion. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and transactions, including long-term debt guarantees.

Representations, Warranties, Covenants, and Defaults

The First Term Loan Due 2034 and Second Term Loan Due 2034 contain representations and warranties, affirmative and negative covenants, and events of default that we consider usual and customary for bank facilities of this type. Specifically, the First Term Loan Due 2034 and Second Term Loan Due 2034 contain debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants. The First Term Loan Due 2034 also requires that a $1.0 million payment reserve account be maintained. There are no financial maintenance covenants associated with the Notre Dame Debt.

Proceeds available for use under the First Term Loan Due 2034 and Second Term Loan Due 2034 were placed in a disbursement account whereby Veritex makes payments for construction related expenses. Amounts held in the disbursement account are reflected as restricted cash (current portion) and restricted cash, noncurrent in our consolidated balance sheets.

As described elsewhere in this report, we are in default under our secured loan agreements. Defaults include events of default and financial covenant violations. Defaults under our secured loan agreements permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. The debt associated with these loans was classified within the current portion of long-term debt on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

Blue Dolphin Energy Company June 30, 2020

24

Notes to Consolidated Financial Statements

Events of Default. In September 2017, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex regarding events of default under our secured loan agreements, including, but not limited to, the occurrence of the GEL Final Arbitration Award, associated material adverse effect conditions, failure by LE to replenish a $1.0 million payment reserve account, and the occurrence of events of default under our other secured loan agreements with Veritex. Further, Veritex informed obligors that it would consider a final confirmation of the GEL Final Arbitration Award to be a material event of default under the loan agreements. Veritex did not accelerate or call due our secured loan agreements considering then ongoing settlement discussions between GEL and the Lazarus Parties. Instead, Veritex expressly reserved all its rights, privileges and remedies related to events of default.

In April 2019, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex that the bank agreed to waive certain covenant violations and forbear from enforcing its remedies under our secured loan agreements subject to: (i) the agreement and concurrence of the USDA and (ii) the replenishment of the payment reserve account on or before August 31, 2019. Following the GEL Settlement, the associated mutual releases became effective and GEL filed the stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and the obligors were still in default under our secured loan agreements with Veritex.

Payment Deferments. In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

Financial Covenant Violations. At June 30, 2020, LE and LRM were in violation of the debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants under our secured loan agreements with Veritex. Any exercise by Veritex of its rights and remedies under our secured loan agreements would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Vertitex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. Defaults under our secured loan agreements and any exercise by Veritex of its rights and remedies related to such defaults may have a material adverse effect on the trading prices of our common stock and on the value of an investment in our common stock, and holders of our common stock could lose their investment in our common stock in its entirety. See “Note (1)” and “Note (11)” to our consolidated financial statements for additional information regarding defaults under our secured loan agreements and their potential effects on our business, financial condition, and results of operations.

Outstanding Principal, Debt Issue Costs, and Accrued Interest

Third-party long-term debt (outstanding principal and accrued interest), as of the dates indicated was as follows:

	June 30,	December 31,
	2020	2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$22,006	$21,776
Second Term Loan Due 2034 (in default)	9,125	9,031
Notre Dame Debt (in default)	9,015	8,617
	40,146	39,424
Less: Current portion of long-term debt, net	(33,612)	(33,836)
Less: Unamortized debt issue costs	(1,813)	(1,877)
Less: Accrued interest payable (in default)	(4,721)	(3,711)
	$-	$-

Blue Dolphin Energy Company June 30, 2020

25

Notes to Consolidated Financial Statements

Unamortized debt issue costs associated with USDA-guaranteed loans as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$1,674	$1,674
Second Term Loan Due 2034 (in default)	768	768
Less: Accumulated amortization	(629)	(565)
	$1,813	$1,877

Amortization expense was $0.03 million for both three-month periods ended June 30, 2020 and 2019. Amortization expense was $0.06 million for both six-month periods ended June 30, 2020 and 2019.

Accrued interest related to third-party long-term debt, reflected as accrued interest payable in our consolidated balance sheets, as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
Notre Dame Debt (in default)	$4,037	$3,639
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	461	25
Second Term Loan Due 2034 (in default)	223	47
	4,721	3,711
Less: Accrued interest payable (in default)	(4,721)	(3,711)
Long-term Interest Payable, Net of Current Portion	$-	$-

(11) 

Line of Credit Payable

Line of Credit Agreement

Line of Credit Description	Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
Amended Pilot Line of Credit (in default)	$13.0	May 2020	----	14.00%	GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital

Under the Amended Pilot Line of Credit, NPS was required to make monthly interest only payments to Pilot in each of September and October 2019 in the amount of $0.1 million. The required payments were made.

On May 4, 2020, Pilot sent NPS, as borrower, and LRM, LEH, LE and Blue Dolphin, each a guarantor and collectively guarantors, a notice demanding the immediate payment of the Obligations under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, the Obligations began to accrue interest at a rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor of paying the past due Obligations constituted an event of default. Pilot expressly retained and reserved all its rights and remedies available to it at any time, including without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity. Any exercise by Pilot of its rights and remedies under the Amended Pilot Line of Credit would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations.

On June 1, 2020, Pilot notified borrower and guarantors by letter of its intent to apply as a setoff Pilot’s payment obligations owing to or for the credit or the account of borrower under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May, 2019, between borrower and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between the borrower and Pilot, against the Obligations. As of the date of the letter, the amount of such setoff was approximately $0.2 million. The setoff was only in partial satisfaction of the Obligations and Pilot expressly retained and reserved all its rights and remedies available to it at any time, including, without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

NPS and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue to work with NPS to settle the Obligations. NPS and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. Our ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. In the event we are unsuccessful in such endeavors, we may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

Guarantees and Security

Loan Description	Guarantees	Security
Amended Pilot Line of Credit (in default)	●  Blue Dolphin pledged its equity interests in NPS to Pilot to secure NPS’ obligations; ●  Blue Dolphin, LE, LRM, and LEH have each guaranteed NPS’ obligations.	● NPS receivables; ● NPS assets, including a tank lease (the “Tank Lease”); ● LRM receivables.

Representations, Warranties, and Covenants

The Amended Pilot Line of Credit contains customary affirmative and negative covenants and events of default. In a April 30, 2019, Agreement Regarding Attornment of Tank Leases between Veritex, LE, NPS, and Pilot, Veritex in its capacity as a secured lender of LE and LRM, agreed to permit the continued performance of obligations under a certain tank lease agreement if it were to foreclose on LE property that NPS was leasing from LE so long as certain conditions were met. The effectiveness of the Agreement Regarding Attornment of Tank Leases was subject to certain conditions, including the agreement and concurrence of the USDA that the Agreement Regarding Attornment of Tank Leases does not impair or void the First Term Loan Due 2034 and Second Term Loan Due 2034 or any associated guarantees. Veritex agreed to use commercially reasonable efforts to obtain such USDA concurrence, however, as of the filing date of this report such USDA concurrence has not been provided.

Line of credit payable, which represents outstanding principal and accrued interest, as of the dates indicated was as follows:

	June 30,	December 31,
	2020	2019
	(in thousands)
Amended Pilot Line of Credit (in default)	$10,573	$11,786
Less: Unamortized debt issue costs	-	(219)
Less: Interest payable, short-term	(103)	(103)
	$10,470	$11,464

(12) 

AROs

Refinery and Facilities

Management has concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Management believes that the refinery and facilities assets have indeterminate lives under FASB ASC guidance for estimating AROs because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.

Pipelines and Facilities and Oil and Gas Properties

We have AROs associated with the decommissioning of our pipelines and facilities assets, as well as the plugging and abandonment of our oil and gas properties. We recorded a discounted liability for the fair value of an ARO with a corresponding increase to the carrying value of the related long-lived asset at the time the asset was installed or placed in service, and we depreciated the amount added to property and equipment and recognized accretion expense relating to the discounted liability over the remaining life of the asset. At June 30, 2020 and December 31, 2019, the liability was fully accreted. See “Note (16)” to our consolidated financial statements for disclosures related to decommissioning of our offshore pipelines and platform assets and related risks.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

ARO liability as of the dates indicated was as follows:

	June 30,	December 31,
	2020	2019
	(in thousands)
AROs, at the beginning of the period	$2,565	$2,565
Liabilities settled	(129)	-
	2,436	2,565
Less: AROs, current portion	(2,436)	(2,565)
Long-term AROs, at the end of the period	$-	$-

Liabilities settled reflects preparatory costs associated with decommissioning our offshore pipelines and platform assets.

(13) 

Lease Obligations

Lease Obligations

Operating Lease

Office Lease. BDSC has an office lease related to our headquarters office in Houston, Texas. The 68-month operating lease expires in 2023. BDSC has the option to extend the lease term for one additional five (5) year period if notice of intent to extend is provided to the lessor at least twelve (12) months before the end of the current term. An Affiliate, LEH, subleases a portion of this office space.  Sublease income received from LEH totaled approximately $0.01 million for both the three months ended June 30, 2020 and 2019. Sublease income received from LEH totaled approximately $0.02 million for both the six months ended June 30, 2020 and 2019. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.

Finance Leases

Crane. In January 2018, LE entered a 24-month lease for the purchase of a 20-ton crane for use at the Nixon facility. The lease required a negligible monthly payment and matured in January 2020.

Backhoe Rent-to-Own Agreement. In May 2019,LE entered into a 12-month equipment rental agreement with the option to purchase the backhoe at maturity. The backhoe is being used at the Nixon facility. The equipment rental agreement matured in May 2020. The parties are currently negotiating on the end of lease purchase price for the backhoe.

LACT Unit Rent-to-Own Agreement. In April 2020,LE entered into a 12-month equipment rental agreement with the option to purchase the LACT unit at maturity. The LACT unit, which was installed in June 2020, is being used at the Nixon facility. The equipment rental agreement requires a negligible monthly payment and matures in June 2021. Subsequent to the consolidated balance sheet date, the lease was canceled, and the related equipment was returned.

The following table presents the lease-related assets and liabilities recorded on the consolidated balance sheet:

		June 30,	December 31,
	Balance Sheet Location	2020	2019
		(in thousands)
Assets
Operating lease ROU assets	Operating lease ROU assets	$787	$787
Less: Accumulated amortization on operating lease assets	Operating lease ROU assets	(211)	(138)
		576	649
Finance lease assets	Property and equipment, net	148	180
Less: Accumulated amortization on finance lease assets	Property and equipment, net	(10)	(34)
		138	146
Total lease assets		714	795
Liabilities
Current
Operating lease	Current portion of lease liabilities	185	175
Finance leases	Current portion of lease liabilities	128	76
		313	251
Noncurrent
Operating lease	Long-term lease liabilities, net of current	470	564
Total lease liabilities		$783	$815

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

Weighted average remaining lease term in years
Operating lease	3.17
Finance leases	0.68
Weighted average discount rate
Operating lease	8.25%
Finance leases	8.25%

The following table presents information related to lease costs for operating and finance leases:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Operating lease costs	$51	$51	$103	$77
Finance lease costs:
Depreciation of leased assets	4	4	10	8
Interest on lease liabilities	2	1	3	2
Total lease cost	$57	$56	$116	$87

The table below presents supplemental cash flow information related to leases as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Cash paid for amounts included in the measurement
of lease liabilities:
Operating cash flows for operating lease	$43	$40	$131	$96
Operating cash flows for finance leases	$2	$1	$4	$2
Financing cash flows for finance leases	$6	$10	$12	$21

As of June 30, 2020, maturities of lease liabilities for the periods indicated were as follows:

June 30,	Operating Lease	Financing Leases	Total
	(in thousands)
2020	$184	$128	$312
2021	204	-	204
2022	226	-	226
2023	41	-	41
	$655	$128	$783

Future minimum annual lease commitments that are non-cancelable:

	Operating
June 30,	Lease
	(in thousands)
2020	$232
2021	235
2022	239
2023	40
	$746

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

(14) 

Income Taxes

Tax Provision

The provision for income tax benefit (expense) for the periods indicated was as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Current
Federal	$-	$-	$(15)	$-
State	-	-	-	-
Deferred
Federal	893	800	1,591	643
State	-		-
Change in valuation allowance	(893)	(800)	(1,591)	(643)
Total provision for income taxes	$-	$-	$(15)	$-

The state of Texas, TMT is treated as an income tax for financial reporting purposes.

Deferred income taxes as of the dates indicated consisted of the following:

	June 30,	December 31,
	2020	2019
	(in thousands)
Deferred tax assets:
NOL and capital loss carryforwards	$13,897	$12,463
Business interest expense	2,648	1,923
Start-up costs (crude oil and condensate processing facility)	551	594
ARO liability/deferred revenue	511	539
AMT credit	-	50
Other	36	11
Total deferred tax assets	17,643	15,580
Deferred tax liabilities:
Basis differences in property and equipment	(6,705)	(6,183)
Total deferred tax liabilities	(6,705)	(6,183)
	10,938	9,397
Valuation allowance	(10,938)	(9,347)
Deferred tax assets, net	$-	$50

Deferred Income Taxes

Deferred income tax balances reflect the effects of temporary differences between the carrying amounts of assets and liabilities and their tax basis, as well as from NOL carryforwards. We state those balances at the enacted tax rates we expect will be in effect when taxes are paid. NOL carryforwards and deferred tax assets represent amounts available to reduce future taxable income.

NOL Carryforwards. Under IRC Section 382, a corporation that undergoes an “ownership change” is subject to limitations on its use of pre-change NOL carryforwards to offset future taxable income. Within the meaning of IRC Section 382, an “ownership change” occurs when the aggregate stock ownership of certain stockholders (generally 5% shareholders, applying certain look-through rules) increases by more than fifty (50) percentage points over such stockholders' lowest percentage ownership during the testing period (generally three years). For income tax purposes, we experienced ownership changes in 2005, relating to a series of private placements, and in 2012, because of a reverse acquisition, that limit the use of pre-change NOL carryforwards to offset future taxable income. In general, the annual use limitation equals the aggregate value of common stock at the time of the ownership change multiplied by a specified tax-exempt interest rate. The 2012 ownership change will subject approximately $16.3 million in NOL carryforwards that were generated prior to the ownership change to an annual use limitation of approximately $0.6 million per year. Unused portions of the annual use limitation amount may be used in subsequent years. Because of the annual use limitation, approximately $6.7 million in NOL carryforwards that were generated prior to the 2012 ownership change will expire unused. NOL carryforwards that were generated after the 2012 ownership change and prior to 2018 are not subject to an annual use limitation under IRC Section 382 and may be used for a period of 20 years in addition to available amounts of NOL carryforwards generated prior to the ownership change.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

NOL Carryforwards. NOL carryforwards that remained available for future use for the periods indicated were as follow (amounts shown are net of NOLs that will expire unused because of the IRC Section 382 limitation):

	Net Operating Loss Carryforward
	Pre-Ownership Change	Post-Ownership Change	Total
	(in thousands)
Balance at December 31, 2018	$9,614	$37,335	$46,949
Net operating losses	-	5,723	5,723
Balance at December 31, 2019	9,614	43,058	52,672
Net operating losses	-	6,826	6,826
Balance at June 30, 2020	$9,614	$49,884	$59,498

Valuation Allowance. As of each reporting date, management considers new evidence, both positive and negative, to determine the realizability of deferred tax assets. Management considers whether it is more likely than not that some portion or all the deferred tax assets will be realized, which is dependent upon the generation of future taxable income prior to the expiration of any NOL carryforwards. At June 30, 2020 and December 31, 2019, management determined that cumulative losses incurred over the prior three-year period provided significant objective evidence that limited the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of June 30, 2020 and December 31, 2019.

(15) 

Earnings Per Share

A reconciliation between basic and diluted income per share for the periods indicated was as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Net income (loss)	$(4,242)	$(3,299)	$(7,582)	$(2,552)
Basic and diluted income (loss) per share	$(0.34)	$(0.30)	$(0.61)	$(0.23)
Basic and Diluted
Weighted average number of shares of
common stock outstanding and potential
dilutive shares of common stock	12,580,853	10,975,514	12,454,109	10,975,215

Diluted EPS is computed by dividing net income available to common stockholders by the weighted average number of shares of common stock outstanding. Diluted EPS for the three and six months ended June 30, 2020 and 2019 was the same as basic EPS as there were no stock options or other dilutive instruments outstanding.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

(16) 

Commitments and Contingencies

Amended and Restated Operating Agreement

See “Note (3)” to our consolidated financial statements for additional disclosures related to operation and management of all Blue Dolphin properties by an Affiliate under the Amended and Restated Operating Agreement.

BSEE Offshore Pipelines and Platform Decommissioning

BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations. Until such structures are abandoned or removed, lessees and rights-of-way holders are required to inspect and maintain the assets in accordance with regulatory requirements.

In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE on August 15, 2019 to address BDPL’s plans with respect to decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning, along with a safe boarding plan for the platform, within six (6) months (no later than February 15, 2020), and develop and implement a safe boarding plan for submission with such permit applications. Further, BSEE proposed that BDPL complete approved, permitted work within 12 months (no later than August 15, 2020).  BDPL timely submitted permit applications for decommissioning of the subject offshore pipelines and platform assets to BSEE on February 11, 2020 and the USACOE on March 25, 2020. Not all permit applications have been approved by BSEE and the USACOE as required prior to work commencement. Delays in permit approvals may be the result of COVID-19. As a result, BDPL plans to request an extension for decommissioning work.

In April 2020, BSEE issued another INC to BDPL for failure to perform the required structural surveys for the GA-288C Platform. BDPL requested an extension to the INC related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platform surveys were completed, and the INC was resolved in June 2020.

BSEE’s deadline to complete decommissioning of BDPL’s offshore pipelines and platform assets, as well as to complete the structural platform surveys, does not relieve BDPL of its obligations to remedy the BSEE INCs or of BSEE’s authority to impose financial penalties. There can be no assurance that we will be able to meet BSEE’s time tables. If BDPL fails to complete decommissioning of the offshore pipelines and platform assets and/or structural surveys of the platform are not completed by the allowable time frames, BDPL will be subject to vigorous regulatory oversight and enforcement, including but not limited to failure to correct an INC, civil penalties, and revocation of BDPL’s operator designation, which may have a material adverse effect on our earnings, cash flows and liquidity.

We are currently unable to predict the outcome of the BSEE INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At June 30, 2020 and December 31, 2019, BDPL maintained $2.4 million and $2.6 million, respectively, in AROs related to abandonment of these assets.

Defaults Under Secured Loan Agreements with Third Parties

See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for additional disclosures related to defaults under our secured and unsecured debt agreements.

Financing Agreements and Guarantees

Indebtedness. See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for disclosures related to Affiliate and third-party indebtedness and defaults thereto.

Guarantees. Affiliates provided guarantees on certain debt of Blue Dolphin and its subsidiaries. The maximum amount of any guarantee is equal to the principal amount and accrued interest, which amounts are reduced as payments are made. See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for additional disclosures related to Affiliate and third-party guarantees associated with indebtedness and defaults thereto.

Health, Safety and Environmental Matters

Our operations are subject to extensive federal, state, and local environmental, health, and safety regulations governing, among other things, the generation, storage, handling, use and transportation of petroleum products and hazardous substances; the emission and discharge of materials into the environment; waste management; characteristics and composition of jet fuel and other products; and the monitoring, reporting and control of air emissions. Our operations also require numerous permits and authorizations under various environmental, health, and safety laws and regulations. Failure to obtain and comply with these permits or environmental, health, or safety laws generally could result in fines, penalties or other sanctions, or a revocation of our permits.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

Legal Matters

BOEM Additional Financial Assurance (Supplemental Pipeline Bonds). To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.

BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, and the IBLA granted multiple extension requests that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (see “Note (16) – BSEE Offshore Pipelines and Platform Decommissioning”)will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Due to delays in permit application approvals likely because of COVID-19, BDPL plans to request an extension to BSEE’s August 2020 deadline.

BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.

We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At both June 30, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.

Resolved - GEL Settlement. As previously disclosed, GEL was awarded the GEL Final Arbitration Award in the aggregate amount of $31.3 million. In July 2018, the Lazarus Parties and GEL entered into the GEL Settlement Agreement. The GEL Settlement Agreement was subsequently amended five (5) times to extend the GEL Settlement Payment Date and/or modify certain terms related to the GEL Interim Payments or the GEL Settlement Payment. During the period September 2017 to August 2019, GEL received the following amounts from the Lazarus Parties to reduce the outstanding balance of the GEL Final Arbitration Award:

	(in millions)
Initial payment (September 2017)	$3.7
GEL Interim Payments (July 2018 to April 2019)	8.0
Settlement Payment (Multiple Payments May 7 to 10, 2019)	10.0
Deferred Interim Installment Payments (June 2019 to August 2019)	0.5
	$22.2

The GEL Settlement Effective Date occurred on August 23, 2019. As a result of the GEL Settlement: (i) the mutual releases became effective, (ii) GEL filed the stipulation of dismissal of claims against LE, and (iii) Blue Dolphin recognized a $9.1 million gain on the extinguishment of debt on its consolidated statements of operations in the third quarter of 2019. Until the GEL Settlement occurred, the debt was reflected on Blue Dolphin’s consolidated balance sheets as accrued arbitration award payable. At both June 30, 2020 and December 31, 2019, the accrued arbitration award payable was $0.

Other Legal Matters. We are involved in lawsuits, claims, and proceedings incidental to the conduct of our business, including mechanic’s liens, contract-related disputes, and administrative proceedings. Management is in discussion with all concerned parties and does not believe that such matters will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurance that such discussions will result in a manageable outcome. If Veritex and/or Pilot exercise their rights and remedies due to defaults under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

Blue Dolphin Energy Company June 30, 2020

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Notes to Consolidated Financial Statements

Nixon Facility Improvements

Wehave made and will continue to make capital and efficiency improvements at the Nixon facility. Therefore, we incurred and will continue to incur capital expenditures related to these improvements, which include, among other things, facility and land improvements and installation of new or refurbished refinery process equipment.

Share Issuances (Sales of Unregistered Securities)

We are obligated to issue shares of our Common Stock to: (i) non-employee directors for services rendered to the Board and (ii) to Jonathan Carroll pursuant to the Guaranty Fee Agreements. Set forth below is information regarding the sale or issuance of Common Stock related to these obligations during the three and six months ended June 30, 2020:

● 

On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the guaranty fee agreements.

● 

On April 30, 2020, we also issued an aggregate of 135,084 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three month periods ended September 30, 2018, March 31, 2019, September 30, 2019, and March 31, 2020. The average cost basis was $0.97, the low was $0.57, and the high was $1.18.

The sale and issuance of these securities were exempt from registration under the Securities Act in reliance on Section 4(a)(2) of the Securities Act.

We recognized a gain on the issuance of shares of approximately $0.1 million for both the three and six months ended June 30, 2020.

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Management’s Discussion and Analysis

ITEM 2.  

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis is our analysis of our financial performance, financial condition, and significant trends that may affect future performance. All statements in this section, other than statements of historical fact, are forward-looking statements that are inherently uncertain. See “Important Information Regarding Forward-Looking Statements” for a discussion of the factors that could cause actual results to differ materially from those projected in these statements. You should read the following discussion together with the financial statements and the related notes included elsewhere in this Quarterly Report, as well as with the business strategy, risk factors, and financial statements and related notes included thereto in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 and our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020.  

Overview

Blue Dolphin is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operate a light sweet-crude, 15,000-bpd crude distillation tower with more than 1.2 million bbls of petroleum storage tank capacity in Nixon, Texas. Our assets are primarily organized in two segments: refinery operations (owned by LE) and tolling and terminaling services (owned by LRM and NPS). Active subsidiaries that are reflected in corporate and other include BDPL (inactive pipeline assets), BDPC (inactive leasehold interests in oil and gas wells), and BDSC (administrative services). See “Note (4)” to our consolidated financial statements for more information related to our business segments and properties. Blue Dolphin was formed in 1986 as a Delaware corporation and is traded on the OTCQX under the ticker symbol “BDCO”.

Affiliates

Affiliates control approximately 82% of the voting power of our Common Stock. An Affiliate operates and manages all Blue Dolphin properties and funds working capital requirements during periods of working capital deficits, and an Affiliate is a significant customer of our refined products. Blue Dolphin and certain of its subsidiaries are currently parties to a variety of agreements with Affiliates. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and arrangements and risks associated with working capital deficits.

Business Operations Update

The ongoing COVID-19 pandemic has resulted in significant economic disruption globally, including in the United States. Governmental authorities around the world have taken actions, such as stay-at-home orders and other social distancing measures, to prevent the spread of COVID-19. These measures have resulted in significant business and operational disruptions, including demand destruction for non-essential businesses, business closures, liquidity strains, supply chain challenges, travel restrictions, controls on in-person gathering, and limitations on workforce availability. In particular, travel restrictions have dramatically reduced flights, cruises, and motor vehicle usage at a time when seasonal travel patterns typically result in an increase in consumer demand for certain refined petroleum products.

The impact of COVID-19 was further amplified by market plays between the world’s oil producers beginning late in the first quarter of 2020, which led to a decline in the demand for, and thus also the market prices of, crude oil, and most of our refined products. In addition, global crude oil production levels did not decline despite lower demand and storage capacity constraints, which further intensified the decline in crude oil prices and contributed to an increase in crude oil price volatility. The decrease in demand for refined petroleum products coupled with the decline in the price of crude oil resulted in a significant decrease in the price of refined petroleum products. Although prices recovered slightly during the second quarter, overall market prices remained volatile. The purchase price of crude oil and the selling price of refined products significantly impacts our revenue, cost of goods sold, operating income, and liquidity. In addition, declines in the market prices of crude oil and refined products below their inventory carrying values results in a write down in the value of our inventories and an adjustment to cost of goods sold.

We continue to proactively address the known impacts of COVID-19 to the extent possible. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable to predict the ultimate economic impact of COVID-19 on our business.

Going Concern

Management has determined that certain factors raise substantial doubt about our ability to continue as a going concern. These factors include the following:

Defaults Under Secured Loan Agreements with Third Parties. Defaults under our secured loan agreements with third parties include loans with Veritex in the original aggregate principal amount of $35.0 million, which are guaranteed 100% by the USDA, and a line of credit agreement with Pilot in the original principal amount of $13.0 million. Certain of our related-party debt is also in default. See “Note (3)” of our consolidated financial statements for disclosures related to related-party debt.

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Management’s Discussion and Analysis

Veritex Loan Agreements

In September 2017, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex regarding events of default under our secured loan agreements, including, but not limited to, the occurrence of the GEL Final Arbitration Award, associated material adverse effect conditions, failure by LE to replenish a $1.0 million payment reserve account, and the occurrence of events of default under our other secured loan agreements with Veritex. Further, Veritex informed obligors that it would consider a final confirmation of the GEL Final Arbitration Award to be a material event of default under the loan agreements. Veritex did not accelerate or call due our secured loan agreements considering then ongoing settlement discussions between GEL and the Lazarus Parties. Instead, Veritex expressly reserved all its rights, privileges and remedies related to events of default.

In April 2019, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex that the bank agreed to waive certain covenant defaults and forbear from enforcing its remedies under our secured loan agreements subject to: (i) the agreement and concurrence of the USDA and (ii) the replenishment of the payment reserve account on or before August 31, 2019. Following the GEL Settlement, the associated mutual releases became effective and GEL filed the stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and the obligors were still in default under our secured loan agreements with Veritex.

In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

At June 30, 2020, LE and LRM were in violation of the debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants under our secured loan agreements with Veritex. As a result, the debt associated with these loans was classified within the current portion of long-term debt on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Veritex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. Defaults under our secured loan agreements with Veritex permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. Any exercise by Veritex of its rights and remedies under our secured loan agreements would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. Further, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

Amended Pilot Line of Credit

On May 4, 2020, Pilot sent NPS, as borrower, and LRM, LEH, LE and Blue Dolphin, each a guarantor and collectively guarantors, a notice demanding the immediate payment of the unpaid principal amount and all interest accrued and unpaid, and all other amounts owing or payable (the “Obligations”) under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, the Obligations began to accrue interest at a rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor of paying the past due Obligations constituted an event of default. Pilot expressly retained and reserved all its rights and remedies available to it at any time, including without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity. Any exercise by Pilot of its rights and remedies under the Amended Pilot Line of Credit would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations.

On June 1, 2020, Pilot notified borrower and guarantors by letter of its intent to apply as a setoff Pilot’s payment obligations owing to or for the credit or the account of borrower under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May, 2019, between borrower and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between the borrower and Pilot, against the Obligations. As of the date of the letter, the amount of such setoff was approximately $0.2 million. The setoff was only in partial satisfaction of the Obligations and Pilot expressly retained and reserved all its rights and remedies available to it at any time, including, without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity.

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Management’s Discussion and Analysis

The borrower and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue to work with the borrower to settle the Obligations. Borrower and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. Our ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. In the event we are unsuccessful in such endeavors, we may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

See “Note (10)” and “Note (11)” to our consolidated financial statements for additional information related to defaults under our secured loan agreements with Veritex and Pilot and their potential effects on our business, financial condition, and results of operations.

Margin Deterioration and Volatility. Steps taken to address the COVID-19 pandemic globally and nationally and the actions of members of the OPEC and other producer countries with respect to oil production and pricing significantly impacted supply and demand in global oil and gas markets, causing oil prices to decline sharply, as well as other changes to the economic outlook in the near term. Such developments included, but are not limited to, government-imposed temporary business closures and voluntary shelter-at-home directives as well as developments in production discussions between global oil producers, and the effect thereof. Oil prices as well as demand are expected to continue to be volatile as a result of the near-term over-supply and the ongoing COVID-19 pandemic as changes in oil inventories, industry demand and global and national economic performance are reported, and we cannot predict when prices and demand will improve and stabilize. We are currently unable to estimate the impact these events will have on our future financial position and results of operations. However, we expect margins will likely remain weak for the remainder of 2020 until global demand begins to recover. Accordingly, we can provide no assurances that these events will not have a material adverse effect on our financial position or results of operations.

Net Losses and Working Capital Deficits.

Net Losses

Net loss for the three months ended June 30, 2020 was $4.2 million, or a loss of $0.34 per share, compared to a net loss of $3.3 million, or a loss of $0.30 per share, for the three months ended June 30, 2019. The increase in net loss was the result of less favorable margins per bbl and lower sales volume in the three-month period ended June 30, 2020 compared to the three-month period ended June 30, 2019. Net loss for the six months ended June 30, 2020 was $7.6 million, or a loss of $0.61 per share, compared to a net loss of $2.6 million, or a loss of $0.23 per share, for the six months ended June 30, 2019. The significant increase in net loss was the result of less favorable margins per bbl and lower sales volume in the six-month period ended June 30, 2020 compared to the same period a year earlier.

Working Capital Deficits

We had a working capital deficit of $66.6 million and $59.4 million at June 30, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $20.5 million and $19.6 million at June 30, 2020 and December 31, 2019, respectively. We had cash and cash equivalents and restricted cash (current portion) of less than $0.01 million and $0.05 million, respectively, at June 30, 2020. Comparatively, we had cash and cash equivalents and restricted cash (current portion) of $0.07 million and $0.05 million, respectively, at December 31, 2019.

Operating Risks

Successful execution of our business strategy depends on several key factors, including, having adequate working capital to meet operational needs and regulatory requirements, maintaining safe and reliable operations at the Nixon facility, meeting contractual obligations, and having favorable margins on refined products. As discussed under ”Going Concern” within this Management’s Discussion and Analysis of Financial Condition and Results of Operations and throughout this report, we are currently unable to estimate the impact the COVID-19 pandemic will have on our future financial position and results of operations. Our business was deemed as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. Management believes that it is taking all prudent steps, however, there can be no assurance that our business strategy will be successful, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. Further, if Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

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Management’s Discussion and Analysis

Business Strategy

Considering the uncertainty of the depth and extent of the contraction in demand due to the COVID-19 pandemic, combined with the weaker commodity price environment, we remain focused on safe and reliable operations and cash conservation. In May 2020, we safely completed the planned maintenance turnaround of the Nixon facility.

As discussed above under “Going Concern” and ”Operating Risks” within this Management’s Discussion and Analysis of Financial Condition and Results of Operations many uncertainties remain with respect to COVID-19 and the global oil markets, and it is currently difficult to accurately forecast and plan future business activities. There can be no assurance that our business strategy will be successful, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. If Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

We regularly engage in discussions with third parties regarding the possible purchase of assets and operations that are strategic and complementary to our existing operations. However, we do not anticipate any material acquisition activity in the foreseeable future. As noted above, management has determined that conditions exist that raise substantial doubt about our ability to continue as a going concern due to defaults under our secured loan agreements with third parties, margin deterioration and volatility, and historic net losses and working capital deficits. A ‘going concern’ opinion could impair our ability to finance our operations through the sale of equity, incurring debt, or other financing alternative s. Our ability to continue as a going concern will depend on sustained positive operating margins and working capital to sustain operations, including the purchase of crude oil and condensate and payments on our secured debt agreements with third parties. If we are unable to achieve these goals, our business would be jeopardized, and we may not be able to continue.

Refinery Operations

Our refinery operations segment consists of the following assets and operations:

Property	Key Products Handled	Operating Subsidiary	Location
Nixon facility ● Crude distillation tower (15,000 bpd) ● Petroleum storage tanks ● Loading and unloading facilities ● Land (56 acres)	Crude Oil Refined Products	LE	Nixon, Texas

Capital Improvement Expansion Project. In 2015, the Nixon facility began a 5-year capital improvement expansion project primarily to construct new petroleum storage tanks. The project also included smaller efficiency improvements and the acquisition of refurbished refinery equipment for future deployment. The increase of nearly 1.0 million bbls of petroleum storage capacity has helped with de-bottlenecking the Nixon refinery. In the future, additional petroleum storage capacity will allow for increased refinery throughput of up to approximately 30,000 bpd while deployment of various refurbished refinery equipment will help improve processing capacity and increase the Nixon refinery’s complexity. The project was completed in the second quarter of 2020 at a total cost of approximately $32.5 million.

Crude Oil and Condensate Supply. Operation of the Nixon refinery depends on our ability to purchase adequate amounts of crude oil and condensate. We have a long-term crude supply agreement in place with Pilot. Under the initial term of the crude supply agreement, Pilot will sell us approximately 24.8 million net bbls of crude oil. Thereafter, the crude supply agreement will continue on a one-year evergreen basis. Effective March 1, 2020, Pilot assigned its rights, title, interest, and obligations in the crude supply agreement to Tartan Oil LLC, a Pilot affiliate. Either party may terminate the crude supply agreement by providing the other party 60 days prior written notice.

Pilot also stores crude oil at the Nixon facility under two terminal services agreements. Under the terminal services agreement, Pilot stores crude oil at the Nixon facility at a specified rate per bbl of the storage tank’s shell capacity. Although the initial term of the terminal services agreement expired April 30, 2020, the agreement renewed on a one-year evergreen basis. Either party may terminate the terminal services agreement by providing the other party 60 days prior written notice. However, the terminal services agreement will automatically terminate upon expiration or termination of the crude supply agreement. During the second quarter of 2020, Pilot applied as a setoff Pilot’s payment obligations owed to us under the terminal services agreements between us and Pilot. The setoff was in partial satisfaction of our obligations to Pilot under the Amended Pilot Line of Credit. As of June 1, 2020, the amount of such setoff was approximately $0.2 million. See ‘going concern’ within this Management’s Discussion and Analysis section, as well as “Note (1)” to our consolidated financial statements for additional disclosures related to defaults in our debt obligations.

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Management’s Discussion and Analysis

Our financial health could be materially and adversely affected by defaults under our secured loan agreements, margin deterioration and volatility, historic net losses and working capital deficits, as well as termination of the crude supply agreement or terminal services agreement with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, a sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations.

Products and Markets. Our market is the Gulf Coast region of the U.S., which is represented by the EIA as Petroleum Administration for PADD 3.  We sell our products primarily in the U.S. within PADD 3. Occasionally, we sell refined products to customers that export to Mexico.

The Nixon refinery’s product slate is moderately adjusted based on market demand. We currently produce a single finished product – jet fuel – and several intermediate products, including naphtha, HOBM, and AGO.  Our jet fuel is sold to an Affiliate, which is HUBZone certified. Our intermediate products are primarily sold in nearby markets to wholesalers and refiners as a feedstock for further blending and processing. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliates arrangements and transactions.

Customers.Customers for our refined products include distributors, wholesalers and refineries primarily in the lower portion of the Texas Triangle (the Houston - San Antonio - Dallas/Fort Worth area). We have bulk term contracts in place with most of our customers, including month-to-month, six months, and up to one-year terms. Certain of our contracts require our customers to prepay and us to sell fixed quantities and/or minimum quantities of finished and intermediate petroleum products. Many of these arrangements are subject to periodic renegotiation on a forward-looking basis, which could result in higher or lower relative prices on future sales of our refined products. See “Note (5)” to our consolidated financial statements for disclosures related to concentration of risk associated with significant customers.

Competition.Many of our competitors are substantially larger than us and are engaged on a national or international level in many segments of the oil and gas industry, including exploration and production, gathering and transportation, and marketing. These competitors may have greater flexibility in responding to or absorbing market changes occurring in one or more of these business segments. We compete primarily based on cost. Due to the low complexity of our simple “topping unit” refinery, we can be relatively nimble in adjusting our refined products slate because of changing commodity prices, market demand, and refinery operating costs.

Safety and Downtime. Our refinery operations are operated in a manner materially consistent with industry safe practices and standards. These operations are subject to regulations under OSHA, the EPA, and comparable state and local requirements. Together, these regulations are designed for personnel safety, process safety management, and risk management, as well as to prevent or minimize the probability and consequences of an accidental release of toxic, reactive, flammable, or explosive chemicals. Storage tanks used for refinery operations are designed for crude oil and condensate and refined products, and most are equipped with appropriate controls that minimize emissions and promote safety. Our refinery operations have response and control plans, spill prevention and other programs to respond to emergencies.

The Nixon refinery periodically experiences planned and unplanned temporary shutdowns. Unplanned shutdowns can occur for a variety of reasons, including voluntary regulatory compliance measures, cessation or suspension by regulatory authorities, or disabled equipment. However, in Texas the most typical reason is excessive heat or power outages from high winds and thunderstorms. Planned turnarounds are used to repair, restore, refurbish, or replace refinery equipment. Refineries typically undergo a major turnaround every three to five years. Since the Nixon refinery was placed back in service in 2012 (commonly referred to as “recommissioning”), turnarounds are needed more frequently for unanticipated maintenance or repairs.

We are particularly vulnerable to disruptions in our operations because all our refining operations are conducted at a single facility. Any scheduled or unscheduled downtime will result in lost margin opportunity, potential increased maintenance expense, and a reduction of refined products inventory, which could reduce our ability to meet our payment obligations.

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Management’s Discussion and Analysis

Tolling and Terminaling Operations

Our tolling and terminaling segment consists of the following assets and operations:

Property	Key Products Handled	Operating Subsidiary	Location
Nixon facility ● Petroleum storage tanks ● Loading and unloading facilities	Crude Oil Refined Products	LRM, NPS	Nixon, Texas

Capital Improvement Expansion Project. As previously noted, the Nixon facility underwent a 5-year capital improvement expansion project beginning in 2015. Tolling and terminaling capital improvements primarily related to construction of new petroleum storage tanks to significantly increase petroleum storage capacity. Increased petroleum storage capacity will provide an opportunity to generate additional tolling and terminaling revenue.

Products and Customers. The Nixon facility’s petroleum storage tanks and infrastructure are primarily suited for crude oil and condensate and refined products, such as naphtha, jet fuel, diesel and fuel oil. Storage customers are typically refiners in the lower portion of the Texas Triangle (the Houston - San Antonio - Dallas/Fort Worth area). Shipments are received and redelivered from within the Nixon facility via pipeline or from third parties via truck. Contract terms range from month-to-month to three years.

Operations Safety. Our tolling and terminal operations are operated in a manner materially consistent with industry safe practices and standards. These operations are subject to regulations under OSHA and comparable state and local regulations. Storage tanks used for terminal operations are designed for crude oil and condensate and refined products, and most are equipped with appropriate controls that minimize emissions and promote safety. Our terminal operations have response and control plans, spill prevention and other programs to respond to emergencies.

Inactive Operations

We own certain other pipeline and facilities assets and have leasehold interests in oil and gas properties. These assets, which are shown below and included in corporate and other, are not operational and are fully impaired.

Property	Operating Subsidiary	Location
Freeport facility ● Crude oil and natural gas separation and dehydration ● Natural gas processing, treating, and redelivery ● Vapor recovery unit ● Two onshore pipelines ● Land (162 acres)	BDPL	Freeport, Texas
Offshore Pipelines (Trunk Line and Lateral Lines)	BDPL	Gulf of Mexico
Oil and Gas Leasehold Interests	BDPC	Gulf of Mexico

We fully impaired our pipeline assets at December 31, 2016 and our oil and gas properties at December 31, 2011. Our pipeline and oil and gas properties had no revenue during the three and six months ended June 30, 2020 and 2019. See “Note (16)” to our consolidated financial statements related to pipelines and platform decommissioning requirements and related risks.

Pipeline and Facilities Safety.

Although our pipeline and facility assets are inactive, they require upkeep and maintenance and are subject to safety regulations under OSHA, PHMSA, BOEM, BSEE, and comparable state and local regulations. We have response and control plans, spill prevention and other programs to respond to emergencies related to these assets.

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Management’s Discussion and Analysis

Results of Operations

A discussion and analysis of the factors contributing to our consolidated financial results of operations is presented below. The financial statements, together with the following information, are intended to provide investors with a reasonable basis for assessing our historical operations, but they should not serve as the only criteria for predicting future performance.

Major Influences on Results of Operations. Our results of operations and liquidity are highly dependent upon the margins that we receive for our refined products. The dollar per bbl price difference between crude oil and condensate (input) and refined products (output) is the most significant driver of refining margins, and they have historically been subject to wide fluctuations. Steps taken to address the COVID-19 pandemic globally and nationally and the actions of members of the OPEC and other producer countries with respect to oil production and pricing significantly impacted supply and demand in global oil and gas markets, causing oil prices to decline sharply, as well as other changes to the economic outlook in the near term. Such developments included, but are not limited to, government-imposed temporary business closures and voluntary shelter-at-home directives as well as developments in production discussions between global oil producers, and the effect thereof. Oil prices as well as demand are expected to continue to be volatile as a result of the near-term over-supply and the ongoing COVID-19 pandemic as changes in oil inventories, industry demand and global and national economic performance are reported, and we cannot predict when prices and demand will improve and stabilize. We are currently unable to estimate the impact these events will have on our future financial position and results of operations. Accordingly, we can provide no assurances that these events will not continue to have a material adverse effect on our financial position or results of operations.

How We Evaluate Our Operations. Management uses certain financial and operating measures to analyze segment performance. These measures are significant factors in assessing our operating results and profitability and include: segment contribution margin (deficit), and refining gross profit (deficit) per bbl, tank rental revenue, operation costs and expenses, refinery throughput and production data, and refinery downtime. Segment contribution margin (deficit) and refining gross profit (deficit) per bbl are non-GAAP measures.

Segment Contribution Margin (Deficit) and Refining Gross Profit (Deficit) per Bbl

Segment contribution margin (deficit) is used to evaluate both refinery operations and tolling and terminaling while refining gross profit (deficit) per bbl is a refinery operations benchmark. Both measures supplement our financial information presented in accordance with U.S. GAAP. Management uses these non-GAAP measures to analyze our results of operations, assess internal performance against budgeted and forecasted amounts, and evaluate future impacts to our financial performance as a result of capital investments. Non-GAAP measures have important limitations as analytical tools. These non-GAAP measures, which are defined in our glossary of terms, should not be considered a substitute for GAAP financial measures. We believe these measures may help investors, analysts, lenders, and ratings agencies analyze our results of operations and liquidity in conjunction with our U.S. GAAP results. See “Non-GAAP Reconciliations” within this “Item 2.” and the financial statements within “Item 1.” for a reconciliation of Non-GAAP measures to U.S. GAAP.

Tank Rental Revenue

Tolling and terminaling revenue primarily represents tank rental storage fees associated with customer tank rental agreements. As a result, tank rental revenue is one of the measures management uses to evaluate the performance of our tolling and terminaling business segment.

Operation Costs and Expenses

We manage operating expenses in tandem with meeting environmental and safety requirements and objectives and maintaining the integrity of our assets. Operating expenses are comprised primarily of labor expenses, repairs and other maintenance costs, and utility costs. Expenses for refinery operations generally remain stable across broad ranges of throughput volumes, but they can fluctuate from period to period depending on the mix of activities performed during that period and the timing of those expenses. Operation costs for tolling and terminaling operations are relatively fixed.

Refinery Throughput and Production Data

The amount of revenue we generate from our refinery operations business segment primarily depends on the volumes of crude oil and refined products that we handle through our processing assets and the volume sold to customers. These volumes are affected by the supply and demand of, and demand for, crude oil and refined products in the markets served directly or indirectly by our assets, as well as refinery downtime.

Refinery Downtime

The Nixon refinery periodically experiences planned and unplanned temporary shutdowns. Any scheduled or unscheduled downtime will result in lost margin opportunity, potential increased maintenance expense, and a reduction of refined products inventory, which could reduce our ability to meet our payment obligations.

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Management’s Discussion and Analysis

Consolidated Results. Our consolidated results of operations include certain other unallocated corporate activities and the elimination of intercompany transactions and therefore do not equal the sum of the operating results of our refinery operations and tolling and terminaling business segments.

Three Months Ended June 30, 2020 Versus June 30, 2019(Q2 2020 Versus Q2 2019) Overview. Net loss for Q2 2020 was $4.2 million, or a loss of $0.34 per share, compared to a net loss of $3.3 million, or a loss of $0.30 per share, in Q2 2019. The increase in net loss was the result of unfavorable margins per bbl and significantly lower sales volume. Total Revenue from Operations.Total revenue from operations for Q2 2020 decreased $59.8 million, or 76%, to $18.5 million compared to $78.3 million for Q2 2019. The significant decrease related to a decline in refinery operations revenue as a result of lower commodity pricing per bbl on refined products sold due to market fluctuations associated with the COVID-19 pandemic and significantly lower sales volumes in 2020. Tolling and terminaling revenue remained flat between the periods at approximately $1.1 million. Total Cost of Goods Sold.Total cost of goods sold was $19.7 million for Q2 2020 compared to $78.6 million for Q2 2019. The $58.9 million decrease related to lower commodity prices per bbl for crude oil and chemicals due to market fluctuations associated with the COVID-19 pandemic and significant refinery downtime in 2020, which resulted in lower sales volumes. Gross Deficit.Gross deficit was $1.2 million for Q2 2020 compared to a gross deficit of $0.2 million for Q2 2019. The significant decrease in gross profit between the periods primarily related to lower margins per bbl due to market fluctuations associated with the COVID-19 pandemic in 2020. General and Administrative Expenses.General and administrative expenses decreased approximately 8%, to $0.5 million compared to $0.6 million for Q2 2019. The decrease primarily related to lower legal fees in Q2 2020 compared to Q2 2019. Depletion, Depreciation and Amortization.Depletion, depreciation, and amortization expenses for Q2 2020 totaled approximately $0.7 million compared to approximately $0.6 million in Q2 2019. The nearly 6% increase primarily related to placing a petroleum storage tank in service. Total Other Expense.Total other expense in Q2 2020 was flat compared to Q2 2019 at $1.6 million. Other expense primarily related to interest expense associated with our secured loan agreements with Veritex, related-party debt, and the line of credit with Pilot. Six Months Ended June 30, 2020 Versus June 30, 2019(6 Months 2020 Versus 6 Months 2019) Overview. Net loss for 6 Months 2020 was $7.6 million, or a loss of $0.61 per share, compared to a net loss of $2.6 million, or a loss of $0.23 per share, in 6 Months 2019. The significant increase in net loss was the result of unfavorable margins per bbl and significantly lower sales volume. Total Revenue from Operations.Total revenue from operations for 6 Months 2020 decreased $66.8 million, or 45%, to $80.5 million compared to $147.3 million for 6 Months 2019. The significant decrease in refinery operations revenue was the result of lower commodity pricing per bbl on refined products sold due to market fluctuations associated with the COVID-19 pandemic and significantly lower sales volumes in 2020. Tolling and terminaling revenue remained flat between the periods at approximately $2.2 million. Total Cost of Goods Sold.Total cost of goods sold was $81.8 million for 6 Months 2020 compared to $144.1 million for 6 Months 2019. The $62.3 million, or 43%, decrease related to lower commodity prices per bbl for crude oil and chemicals due to market fluctuations associated with the COVID-19 pandemic and significant refinery downtime in 2020, which resulted in lower sales volumes. Gross Profit (Deficit).Gross deficit was $1.3 million for 6 Months 2020 compared to gross profit of $3.2 million for 6 Months 2019. The significant decrease in gross profit between the periods primarily related to lower margins per bbl due to market fluctuations associated with the COVID-19 pandemic in 2020. General and Administrative Expenses.General and administrative expenses were relatively flat at approximately $1.2 million for 6 Months 2020 compared to 6 Months 2019. General and administrative expenses primarily consisted of insurance, taxes, and professional fees. Depletion, Depreciation and Amortization.Depletion, depreciation, and amortization expenses for 6 Months 2020 totaled $1.3 million compared to $1.2 million for 6 Months 2019. The nearly 7% increase primarily related to placing a petroleum storage tank in service. Total Other Expense.Total other expense was $3.4 million in 6 Months 2020 compared to an expense of $2.8 million in 6 Months 2019, a 20% increase. Interest expense increased in 6 Months 2020 compared to 6 Months 2019 due to completion of certain CIP for which interest was no longer being capitalized and the addition of the line of credit with Pilot.

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Management’s Discussion and Analysis

Refinery Operations. Our refinery operations business segment is owned by LE. Assets within this segment consist of a light sweet-crude, 15,000-bpd crude distillation tower, petroleum storage tanks, loading and unloading facilities, and approximately 56 acres of land. Refinery operations revenue is derived from refined product sales.

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
	(in thousands)
Refined product sales	$17,359	$77,257	$78,256	$145,115
Less: Total cost of goods sold	(19,676)	(78,556)	(81,764)	(144,072)
Gross profit (deficit)	(2,317)	(1,299)	(3,508)	1,043
Sales (Bbls)	669	1,104	1,810	2,133
Gross Profit (Deficit) per Bbl	$(3.46)	$(1.18)	$(1.94)	$0.49

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
	(in thousands)
Net revenue (1)	$17,359	$77,257	$78,256	$145,115
Intercompany fees and sales	(406)	(653)	(1,023)	(1,259)
Operation costs and expenses	(19,418)	(78,376)	(81,251)	(143,528)
Segment Contribution Margin (Deficit)	$(2,465)	$(1,772)	$(4,018)	$328

(1) 

Net revenue excludes intercompany crude sales.

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Calendar	91	91	182	181
Operating	(68)	(84)	(156)	(163)
Refinery Downtime (Days)	23	7	26	18
Refinery Throughput
bpd	11,447	13,501	12,578	13,381
bbls	778,397	1,134,105	1,962,143	2,181,164
Capacity utilization rate	76.3%	90.0%	83.9%	89.2%
Refinery Production
bpd	11,088	13,123	12,270	13,038
bbls	754,014	1,102,340	1,914,105	2,125,169
Capacity utilization rate	73.9%	87.5%	81.8%	86.9%

Q2 2020 Versus Q2 2019

● 

Refining gross deficit per bbl was $3.46 for Q2 2020 compared to $1.18 in Q2 2019, representing a decrease of $2.28 per bbl.The significant decrease related to lower margins due to market fluctuations associated with the COVID-19 pandemic and significant refinery downtime in 2020.

● 

Segment contribution margin decreased approximately $0.7 million to a deficit of $2.5 million in Q2 2020 compared to a deficit of $1.8 million in Q2 2019. The decrease related to lower margins per bbl due to market fluctuations associated with the COVID-19 pandemic and lower sales volume in 2020.

● 

Refinery downtime increased significantly to 23 days in Q2 2020 compared to 7 days in Q2 2019; refinery downtime in 2020 related to a maintenance turnaround, lack of crude due to cash constraints, and an equipment repair while refinery downtime in Q2 2019 primarily related to equipment repairs. Significant refinery downtime in Q2 2020 negatively impacted refinery throughput, refinery production, and capacity utilization rate.

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Management’s Discussion and Analysis

6 Months 2020 Versus 6 Months 2019

● 

Refining gross deficit per bbl was $1.94 for 6 Months 2020 compared to a gross profit per bbl of $0.49 in 6 Months 2019, representing a decrease of $2.43 per bbl.The significant decrease related to lower margins due to market fluctuations associated with the COVID-19 pandemic and significant refinery downtime in 2020.

● 

Segment contribution margin decreased approximately $3.7 million to a loss of $4.0 million in 6 Months 2020 compared to a profit of $0.3 million in 6 Months 2019. The significant decrease related to lower margins per bbl due to market fluctuations associated with the COVID-19 pandemic and lower sales volume in 2020.

●

Refinery downtime increased significantly to 26 days in 6 Months 2020 compared to 18 days in 6 Months 2019. Refinery downtime in 2020 related to a maintenance turnaround, lack of crude due to cash constraints, and an equipment repair; 2019 downtime related to a maintenance turnaround and equipment repairs. Significant refinery downtime in 6 Months 2020 negatively impacted refinery throughput, refinery production, and capacity utilization rate.

Tolling and Terminaling. Our tolling and terminaling business segment is owned by LRM and NPS. Assets within this segment include petroleum storage tanks and loading and unloading facilities. Tolling and terminaling revenue is derived from tank storage rental fees, tolling and reservation fees for use of the naphtha stabilizer, and fees collected for ancillary services, such as in-tank blending.

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
	(in thousands)
Net revenue (1)	$1,110	$1,088	$2,213	$2,157
Intercompany fees and sales	406	653	1,023	1,259
Operation costs and expenses	(258)	(363)	(513)	(727)
Segment Contribution Margin (Deficit)	$1,258	$1,378	$2,723	$2,689

(1) 

Net revenue excludes intercompany crude sales.

Q2 2020 Versus Q2 2019

● 

Tolling and terminaling net revenue increased approximately 2% in Q2 2020 compared to Q2 2019 primarily as a result of increased tank storage rental fees and fees collected for ancillary services,such as in-tank and tank-to-tank blending.

● 

Intercompany fees and sales, which reflect fees associated with an intercompany tolling agreement tied to naphtha volumes, decreased in Q2 2020 compared to Q2 2019. Naphtha sales volumes decreased between the periods.

● 

Segment contribution margin in Q2 2020 decreased nearly 9% to approximately $1.3 million compared to approximately $1.4 million Q2 2019. The decrease related to lower intercompany fees and sales tied to naphtha.

6 Months 2020 Versus 6 Months 2019

● 

Tolling and terminaling net revenue increased nearly 3% in 6 Months 2020 compared to 6 Months 2019 primarily as a result of increased tank storage rental fees and fees collected for ancillary services.

● 

Intercompany fees and sales decreased in 6 Months 2020 compared to 6 Months 2019 as a result of lower naphtha sales volumes.

●

Segment contribution margin increased a nominal 1% between the periods. The increase was primarily due to increased fees associated with ancillary services.

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Management’s Discussion and Analysis

Non-GAAP Reconciliations.

Reconciliation of Segment Contribution Margin (Deficit)

	Three Months Ended June 30,
	2020	2019	2020	2019	2020	2019	2020	2019
	Refinery Operations		Tolling and Terminaling		Corporate and Other		Total
	(in thousands)
Segment contribution margin	$(2,465)	$(1,589)	$1,258	$1,378	$(47)	$(56)	$(1,254)	$(267)
General and administrative expenses(1)	(327)	(274)	(68)	(62)	(326)	(426)	$(721)	$(762)
Depreciation and amortization	(294)	(483)	(324)	(99)	(51)	(51)	$(669)	$(633)
Interest and other non-operating income (expenses), net	(751)	(823)	(616)	(579)	(231)	(235)	$(1,598)	$(1,637)
Income (loss) before income taxes	(3,837)	(3,169)	250	638	(655)	(768)	(4,242)	(3,299)
Income tax benefit	-	-	-	-	-	-	-	-
Income (loss) before income taxes	$(3,837)	$(3,169)	$250	$638	$(655)	$(768)	$(4,242)	$(3,299)

	Six Months Ended June 30,
	2020	2019	2020	2019	2020	2019	2020	2019
	Refinery Operations		Tolling and Terminaling		Corporate and Other		Total
	(in thousands)
Segment contribution margin	$(4,018)	$511	$2,723	$2,689	$(106)	$(113)	$(1,401)	$3,087
General and administrative expenses(1)	(631)	(606)	(136)	(105)	(745)	(871)	$(1,512)	$(1,582)
Depreciation and amortization	(582)	(948)	(618)	(198)	(102)	(77)	$(1,302)	$(1,223)
Interest and other non-operating income (expenses), net	(1,492)	(1,606)	(1,386)	(775)	(474)	(453)	$(3,352)	$(2,834)
Income (loss) before income taxes	(6,723)	(2,649)	583	1,611	(1,427)	(1,514)	(7,567)	(2,552)
Income tax benefit	-	-	-	-	(15)	-	(15)	-
Income (loss) before income taxes	$(6,723)	$(2,649)	$583	$1,611	$(1,442)	$(1,514)	$(7,582)	$(2,552)

(1) 

General and administrative expenses within refinery operations include the LEH operating fee.

 

Remainder of Page Intentionally Left Blank

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Management’s Discussion and Analysis

Capital Resources and Liquidity

Considering this period of extreme economic disruption, combined with the weaker commodity price environment, we remain focused on the safe and reliable operation of the Nixon facility and cash conservation. Our primary cash requirements relate to: (i) purchasing crude oil and condensate for the operation of the Nixon refinery, (ii) reimbursing LEH for direct operating expenses and paying the LEH operating fee under the Amended and Restated Operating Agreement and (iii) servicing debt. In instances where we experience a working capital deficit, we have historically relied on Affiliates to meet our liquidity needs. While we believe that we can fund our operations through revenue from operations and Affiliate financing, we may not be able to, among other things, (i) maintain our current general and administrative spending levels; (ii) fund certain obligations as they become due; and (iii) respond to competitive pressures or unanticipated capital requirements.We cannot provide any assurance that financing will be available to us in the future on acceptable terms.

We had a working capital deficit of $66.6 million and $59.4 million at June 30, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $20.5 million and $19.6 million at June 30, 2020 and December 31, 2019, respectively. During the three and six-month periods ended June 30, 2020, we did not receive funding under any federal or other governmental programs to support our operations as a result of the COVID-19 pandemic.

The future impact that COVID-19 will have on our business, cash flows, sources of liquidity, financial condition and results of operations will depend on future developments, including, among other things, volatility in the global capital markets, the ultimate geographic spread and severity of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume. A sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations.

Debt Overview.

Total Debt

	June 30,	December 31,
	2020	2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$22,006	$21,776
Second Term Loan Due 2034 (in default)	9,125	9,031
Amended Pilot Line of Credit (in default)	10,573	11,786
Notre Dame Debt (in default)	9,015	8,617
Related-Party Debt
BDPL Loan Agreement (in default)	6,494	6,174
March Ingleside Note (in default)	1,039	1,004
March Carroll Note (in default)	1,198	997
June LEH Note (in default)	6,336	-
Total Debt	65,786	59,385
Less: Current portion of long-term debt, net	(56,655)	(51,301)
Less: Unamortized debt issue costs	(1,813)	(2,096)
Less: Accrued interest payable (in default)	(7,318)	(5,988)
	$-	$-

Net proceeds from financing activities was $4.2 million in Q2 2020 compared to $12.1 million in Q2 2019. Net proceeds from financing activities was $4.9 in 6 Months 2020 compared to $12.1 million in 6 Months 2019.

Principal payments on long-term debt totaled $0.8 million in Q2 2020 compared to $0.3 million in Q2 2019. Principal payments on long-term debt totaled $1.5 million in 6 Months 2020 compared to $0.5 million in 6 Months 2019. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex. No payments have been made under subordinated loan agreements.

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Management’s Discussion and Analysis

On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the guaranty fee agreements.

On April 30, 2020, we also issued an aggregate of 135,084 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three month periods ended September 30, 2018, March 31, 2019, September 30, 2019, and March 31, 2020. The average cost basis was $0.97, the low was $0.57, and the high was $1.18.

Debt Defaults. All of our debt is in default. Defaults under our secured loan agreements with third parties include Veritex events of default and financial covenant violations and a Pilot event of default and debt acceleration. See ‘going concern’ within this Management’s Discussion and Analysis section, as well as “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for additional disclosures related to Affiliate and third-party debt agreements, including debt guarantees, and defaults in our debt obligations.

Concentration of Customers. Our operations have a concentration of customers who are refined petroleum product wholesalers. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that these customers may be similarly affected by changes in economic or other conditions including the uncertainties concerning COVID-19 and volatility in the global oil markets. Historically, we have not had any significant problems collecting our accounts receivable.

Contractual Obligations.

Related-Party

Agreement/Transaction	Parties	Type	Effective Date	Interest Rate	Key Terms
Amended and Restated Guaranty Fee Agreement	Jonathan Carroll - LE	Debt	04/01/2017	2.00%	Tied to payoff of LE $25 million Veritex loan; payments 50% cash, 50% Common Stock
Amended and Restated Guaranty Fee Agreement	Jonathan Carroll - LRM	Debt	04/01/2017	2.00%	Tied to payoff of LRM $10 million Veritex loan; payments 50% cash, 50% Common Stock
March Carroll Note (in default)	Jonathan Carroll – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; matured 01/01/2019; interest still accruing
March Ingleside Note (in default)	Ingleside – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to Ingleside under previous Amended and Restated Tank Lease Agreement; matured 01/01/2019; interest still accruing
June LEH Note (in default)	LEH – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; reflects amounts owed to Jonathan Carroll under guaranty fee agreements; matured 01/01/2019; interest still accruing
Loan and Security Agreement (in default)	LEH - BDPL	Debt	08/15/2016	16.00%	2-year term; $4.0 million principal amount; $0.5 million annual payment; proceeds used for working capital; no financial maintenance covenants; secured by certain BDPL property

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Management’s Discussion and Analysis

 

Third-Party Debt

Loan Description	Original Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$25.0	Jun 2034	$0.2 million	WSJ Prime + 2.75%	Refinance loan; capital improvements
Second Term Loan Due 2034 (in default)	$10.0	Dec 2034	$0.1 million	WSJ Prime + 2.75%	Refinance bridge loan; capital improvements
Notre Dame Debt (in default)	$11.7(1)	Jan 2018	No payments to date; payment rights subordinated(2)	16.00%	Working capital; reduce balance of GEL Final Arbitration Award
Amended Pilot Line of Credit (in default)	$13.0	May 2020	----	14.00%	GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital

(1) 

Original principal amount was $8.0 million; pursuant to a 2017 sixth amendment, the Notre Dame Debt was amended to increase the principal amount by $3.7 million; the additional principal was used to reduce the GEL Final Arbitration Award by $3.6 million.

(2) 

Pursuant to a 2015 subordination agreement, the holder of the Notre Dame Debt agreed to subordinate their right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in favor of Veritex as holder of the First Term Loan Due 2034.

BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)

To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.

BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, and the IBLA granted multiple extension requests that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (see “Note (16) – BSEE Offshore Pipelines and Platform Decommissioning”) will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Due to delays in permit application approvals likely because of COVID-19, BDPL plans to request an extension to BSEE’s August 2020 deadline.

BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.

We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At both June 30, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.

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Management’s Discussion and Analysis

 

BSEE Offshore Pipelines and Platform Decommissioning

BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations. Until such structures are abandoned or removed, lessees and rights-of-way holders are required to inspect and maintain the assets in accordance with regulatory requirements.

In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE on August 15, 2019 to address BDPL’s plans with respect to decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning, along with a safe boarding plan for the platform, within six (6) months (no later than February 15, 2020), and develop and implement a safe boarding plan for submission with such permit applications. Further, BSEE proposed that BDPL complete approved, permitted work within 12 months (no later than August 15, 2020).  BDPL timely submitted permit applications for decommissioning of the subject offshore pipelines and platform assets to BSEE on February 11, 2020 and the USACOE on March 25, 2020. Not all permit applications have been approved by BSEE and the USACOE as required prior to work commencement. Delays in permit approvals may be the result of COVID-19. As a result, BDPL plans to request an extension for decommissioning work.

In April 2020, BSEE issued another INC to BDPL for failure to perform the required structural surveys for the GA-288C Platform. BDPL requested an extension to the INC related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platform surveys were completed, and the INC was resolved in June 2020.

BSEE’s deadline to complete decommissioning of BDPL’s offshore pipelines and platform assets, as well as to complete the structural platform surveys, does not relieve BDPL of its obligations to remedy the BSEE INCs or of BSEE’s authority to impose financial penalties. There can be no assurance that we will be able to meet BSEE’s time tables. If BDPL fails to complete decommissioning of the offshore pipelines and platform assets and/or structural surveys of the platform are not completed by the allowable time frames, BDPL will be subject to vigorous regulatory oversight and enforcement, including but not limited to failure to correct an INC, civil penalties, and revocation of BDPL’s operator designation, which may have a material adverse effect on our earnings, cash flows and liquidity.

We are currently unable to predict the outcome of the BSEE INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At June 30, 2020 and December 31, 2019, BDPL maintained $2.4 million and $2.6 million, respectively, in AROs related to abandonment of these assets.

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Management’s Discussion and Analysis

Sources and Use of Cash.

Components of Cash Flows

	Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019
	(in thousands)
Cash Flows Provided By (Used In):
Operating activities	$(3,707)	$(11,421)	$(4,034)	$(11,294)
Investing activities	(710)	(371)	(908)	(494)
Financing activities	4,152	12,079	4,874	12,090
Increase (Decrease) in Cash and Cash Equivalents	$(265)	$287	$(68)	$302

2020 Compared to 2019

We had a cash flow deficit from operations of $3.7 million for Q2 2020 compared to a cash flow deficit of $11.4 million for Q2 2019. The cash flow deficit from operations in Q2 2020 and 6 Months 2020 primarily related to loss from operations. The cash flow deficit from operations in Q2 2019 and 6 Months 2019 was primarily the result of payments toward the accrued arbitration award with GEL.

Capital Spending

We account for our capital expenditures in accordance with GAAP. We also distinguish between capital expenditures that are for maintenance and those that are for expansion. We classify a capital expenditure as maintenance if it maintains capacity or throughput. A classification of expansion is used if the capital expenditure is expected to increase capacity or throughput. The distinction between maintenance and expansion is made consistent with our accounting policies and is generally a straightforward process. However, in certain circumstances the distinction can be a matter of management judgment and discretion.

Budgeting and approval of maintenance capital expenditures is done throughout the year on a project-by-project basis. We budget for and make maintenance capital expenditures that are necessary to maintain safe and efficient operations, meet customer needs and comply with operating policies and applicable law. We may budget for and make additional maintenance capital expenditures that we expect to produce economic benefits such as increasing efficiency and/or lowering future expenses. Budgeting and approval of expansion capital expenditures are generally made periodically on a project-by-project basis in response to specific investment opportunities identified by our business segments.

Capital Improvement Expansion Project

In 2015, the Nixon facility began a 5-year capital improvement expansion project primarily to construct new petroleum storage tanks. The project also included smaller efficiency improvements and the acquisition of refurbished refinery equipment for future deployment. The increase of nearly 1.0 million bbls of petroleum storage capacity has helped with de-bottlenecking the Nixon refinery. In the future, additional petroleum storage capacity will allow for increased refinery throughput of up to approximately 30,000 bpd while deployment of various refurbished refinery equipment will help improve processing capacity and increase the Nixon refinery’s complexity. The project was completed in the second quarter of 2020 at a total cost of approximately $32.5 million.

2020 Capital Expenditures

During Q2 2020, capital expenditures totaled $0.7 million compared to $0.4 million during Q2 2019. During 6 Months 2020, capital expenditures totaled $0.9 million compared to $0.5 million during 6 Months 2019. Expenditures during 2020 primarily related to completion of a petroleum storage tank and a maintenance turnaround. The 5-year Nixon capital improvement expansion project was completed during Q2 2020 with completion of the last petroleum storage tank.

Future Expected Capital Expenditures

We remain focused on the safe and reliable operation of the Nixon facility. In view of the uncertainty surrounding the COVID-19 pandemic, combined with the weaker commodity price environment, we anticipate new capital expenditures to be minimal over the next 12 months. However, capital spending using remaining funds under a loan from Veritex will continue until the funds are depleted. Unused amounts under the Veritex loans are reflected in restricted cash (current and non-current portions) on our consolidated balance sheets. See “Note (10)” to our consolidated financial statements for additional disclosures related to borrowings for capital spending.

Off-Balance Sheet Arrangements.None.

Blue Dolphin Energy Company June 30, 2020

50

Management’s Discussion and Analysis and Internal Controls

Accounting Standards.

Critical Accounting Policies and Estimates

Our significant accounting policies and recent accounting developments are described in “Note (2)” to our consolidated financial statements. The ongoing COVID-19 pandemic and certain developments in the global oil markets have impacted and continue to impact our business. Our business was designated as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable to predict the ultimate economic impact of COVID-19 on our business.

The nature of our business requires that we make estimates and assumptions in accordance with U.S. GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenue and expenses during the reporting period. The ongoing COVID-19 pandemic has impacted these estimates and assumptions and will continue to do so.

We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of COVID-19 as of June 30, 2020 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.

New Accounting Standards and Disclosures

New accounting standards and disclosures are discussed in “Note (2)” to our consolidated financial statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not applicable.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision of, and with the participation of our management, including our Chief Executive Officer (principal executive officer and principal financial officer), we conducted an evaluation of the effectiveness of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”). As previously reported in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019, based on our evaluation, our Chief Executive Officer (principal executive officer, principal financial officer, and principal accounting officer) concluded that our disclosure controls and procedures were ineffective due to certain material weaknesses and/or significant deficiencies as described below:

● Significant deficiency – There is currently not a process in place for formal review of manual journal entries.

● Material weakness – The company currently lacks resources to handle complex accounting transactions. This can result in errors related to the recording, disclosure and presentation of consolidated financial information in quarterly, annual, and other filings.

These disclosure controls and procedures remained ineffective as of the end of the period covered by this Quarterly Report. Management continues to evaluate internal processes to take corrective actions. Corrective actions may include implementing formal policies, improving processes, documenting procedures, and better defining segregation of duties to improve financial reporting. These actions will be subject to ongoing senior management review, as well as Audit Committee oversight. Although we plan to complete remediation efforts as quickly as possible, we cannot at this time estimate how long it will take, and our initiatives may not prove to be successful in fully remediating the identified weakness and deficiency.

Changes in Internal Control over Financial Reporting

There have been no change in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the three and six months ended June 30, 2020 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting. See the above section “Evaluation of Disclosure Controls and Procedures” for a discussion related to current ineffective disclosure controls and procedures.

Blue Dolphin Energy Company June 30, 2020

51

Legal Proceedings

PART II

ITEM 1.  LEGAL PROCEEDINGS

BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)

To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.

BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, and the IBLA granted multiple extension requests that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (see “Note (16) – BSEE Offshore Pipelines and Platform Decommissioning”) will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Due to delays in permit application approvals likely because of COVID-19, BDPL plans to request an extension to BSEE’s August 2020 deadline.

BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.

We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At both June 30, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.

Resolved - GEL Settlement

As previously disclosed, GEL was awarded the GEL Final Arbitration Award in the aggregate amount of $31.3 million. In July 2018, the Lazarus Parties and GEL entered into the GEL Settlement Agreement. The GEL Settlement Agreement was subsequently amended five (5) times to extend the GEL Settlement Payment Date and/or modify certain terms related to the GEL Interim Payments or the GEL Settlement Payment. During the period September 2017 to August 2019, GEL received the following amounts from the Lazarus Parties to reduce the outstanding balance of the GEL Final Arbitration Award:

	(in millions)
Initial payment (September 2017)	$3.7
GEL Interim Payments (July 2018 to April 2019)	8.0
Settlement Payment (Multiple Payments May 7 to 10, 2019)	10.0
Deferred Interim Installment Payments (June 2019 to August 2019)	0.5
	$22.2

The GEL Settlement Effective Date occurred on August 23, 2019. As a result of the GEL Settlement: (i) the mutual releases became effective, (ii) GEL filed the stipulation of dismissal of claims against LE, and (iii) Blue Dolphin recognized a $9.1 million gain on the extinguishment of debt on its consolidated statements of operations in the third quarter of 2019. Until the GEL Settlement occurred, the debt was reflected on Blue Dolphin’s consolidated balance sheets as accrued arbitration award payable. At both June 30, 2020 and December 31, 2019, accrued arbitration award payable was $0.

Blue Dolphin Energy Company June 30, 2020

52

Legal Proceedings (Continued) and Risk Factors

Other Legal Matters

We are involved in lawsuits, claims, and proceedings incidental to the conduct of our business, including mechanic’s liens, contract-related disputes, and administrative proceedings. Management is in discussion with all concerned parties and does not believe that such matters will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurance that such discussions will result in a manageable outcome. If Veritex and/or Pilot exercise their rights and remedies due to defaults under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

ITEM 1A.  RISK FACTORS

In addition to the other information set forth in this Quarterly Report, careful consideration should be given to the risk factors discussed under “Part I, Item 1A. Risk Factors” and elsewhere in our Annual Report for the fiscal year ended December 31, 2019 and our Quarterly Report for the three month period ended March 31, 2020 as filed with the SEC. These risks and uncertainties could materially and adversely affect our business, financial condition and results of operations. Our operations could also be affected by additional factors that are not presently known to us or by factors that we currently consider immaterial to our business. Except as noted below, there have been no material changes in our assessment of our risk factors from those set forth in our Annual Report for the fiscal year ended December 31, 2019 and our Quarterly Report for the three month period ended March 31, 2020.

The ongoing COVID-19 pandemic, and actions taken in response thereto, as well as certain developments in the global oil markets have had, and will likely continue to have, material adverse consequences for general economic, financial and business conditions, and could materially and adversely affect our business, financial condition, results of operations and cash flows and those of our customers and suppliers.

The ongoing COVID-19 pandemic, and actions taken in response thereto, have resulted in significant economic disruption globally, including in the United States. Governmental authorities around the world have taken actions, such as stay-at-home orders and other social distancing measures, to prevent the spread of COVID-19. These measures have resulted in significant business and operational disruptions, including demand destruction for non-essential businesses, business closures, liquidity strains, supply chain challenges, travel restrictions, controls on in-person gathering, and limitations on workforce availability. In particular, travel restrictions have dramatically reduced flights, cruises, and motor vehicle usage at a time when seasonal travel patterns typically result in an increase in consumer demand for certain refined petroleum products.

Concerns over the negative effects of COVID-19 on economic and business prospects across the world have contributed to increased market and oil price volatility and have diminished expectations for the global economy. These factors, coupled with the emergence of decreasing business and consumer confidence and increasing unemployment resulting from the COVID-19 outbreak and the recent abrupt oil price decline, may precipitate a prolonged economic slowdown and recession. Our refinery utilization and operating margins and other aspects of our business have been adversely impacted by these developments. Any such prolonged period of economic slowdown or recession, or a protracted period of depressed prices for crude oil and our refined products or reduced margins for the refined products we produce and sell could have significant adverse consequences for our financial condition and the financial condition of our customers and suppliers, and could diminish our liquidity and negatively affect our ability to obtain adequate crude oil volumes and to market certain of our products at favorable prices, or at all.

Due to declines in the market prices of products held in our inventories, in future periods we may record an inventory write-down to cost of goods sold to value certain of our inventories at the lower of cost or market, which charge may be material. This expected inventory valuation write-down will have a negative effect on our earnings. Depending on future movements of refined product prices, future inventory valuation adjustments could have a negative or positive effect on our financial performance. In addition, a sustained period of low crude oil prices may also result in significant financial constraints on our crude oil supplier, which could result in long term crude oil supply constraints and higher transportation costs for our business. Such conditions could also result in an increased risk that our customers may be unable to fully fulfill their obligations in a timely manner, or at all. Any of the foregoing events or conditions, or other unforeseen consequences of COVID-19, could significantly adversely affect our business and financial condition and the business and financial condition of our customers.

The future impact that COVID-19 will have on our business, results of operations, financial condition, cash flows, and stock price will depend on future developments, including, among others, volatility in the global capital markets, the ultimate geographic spread and severity of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume. A sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations.

Blue Dolphin Energy Company June 30, 2020

53

Unregistered Sales of Equity Securities and Exhibits

ITEM 2.  UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Set forth below is information regarding the sale or issuance of shares of Common Stock by us that were not registered under the Securities Act of 1933 during the three and six months ended June 30, 2020:

On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the guaranty fee agreements.

On April 30, 2020, we also issued an aggregate of 135,084 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three month periods ended September 30, 2018, March 31, 2019, September 30, 2019, and March 31, 2020. The average cost basis was $0.97, the low was $0.57, and the high was $1.18.

The sale and issuance of the securities were exempt from registration under the Securities Act in reliance on Section 4(a)(2) of the Securities Act.

ITEM 3.  DEFAULTS UPON SENIOR SECURITIES

See “Part I, Item. 1. Financial Statements – Note (10)” and “Note (11)” for disclosures related to defaults on our debt.

ITEM 4.  MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.  

OTHER INFORMATION

In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

ITEM 6.  EXHIBITS

Exhibits Index

No.  Description 

31.1*	Jonathan P. Carroll Certification Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to section 302 of the Sarbanes-Oxley Act of 2002.
32.1*	Jonathan P. Carroll Certification Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*	XBRL Instance Document.
101.SCH*	XBRL Taxonomy Schema Document.
101.CAL*	XBRL Calculation Linkbase Document.
101.LAB*	XBRL Label Linkbase Document.
101.PRE*	XBRL Presentation Linkbase Document.
101.DEF*	XBRL Definition Linkbase Document.

*            

Filed herewith

Blue Dolphin Energy Company June 30, 2020

54

Signature Page

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this Quarterly Report to be signed on its behalf by the undersigned, thereunto duly authorized.

	BLUE DOLPHIN ENERGY COMPANY
	(Registrant)
August 14, 2020	By:	/s/ JONATHAN P. CARROLL
		Jonathan P. Carroll Chief Executive Officer, President, Assistant Treasurer and Secretary (Principal Executive Officer, Principal Financial Officer, and Principal Accounting Officer)

Blue Dolphin Energy Company June 30, 2020

55

EX-31.1

Exhibit 31.1

I, Jonathan P. Carroll, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Blue Dolphin Energy Company (the “Registrant”).

2.

Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the periods covered by this quarterly report;

3.

Based on my knowledge, the financial statements and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this quarterly report;

4.

I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and I have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under my supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to me by others within those entities, particularly during the period in which this quarterly report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under my supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the Registrant’s disclosure controls and procedures and presented in this quarterly report my conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this quarterly report based on such evaluation; and

d) Disclosed in this quarterly report any change in the Registrant’s internal control over financial reporting that occurred during the Registrant’s most recent fiscal quarter (the Registrant’s first fiscal quarter in the case of this quarterly report) that has materially affected, or is reasonably likely to materially affect, the Registrant’s internal control over financial reporting; and

5.

I have disclosed, based on my most recent evaluation of internal control over financial reporting, to the Registrant’s auditors and the Audit Committee of the Registrant’s Board of Directors:

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant’s internal control over financial reporting.

Date: August 14, 2020

/s/ JONATHAN P. CARROLL

Jonathan P. Carroll

Chief Executive Officer, President, Assistant Treasurer and Secretary

(Principal Executive Officer and Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION OF

PRINCIPAL EXECUTIVE OFFICER AND

PRINCIPAL FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Blue Dolphin Energy Company (the “Blue Dolphin”) on Form 10-Q for the period ended June 30, 2020 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Jonathan P. Carroll, Chief Executive Officer, President, Assistant Treasurer and Secretary (Principal Executive Officer and Principal Financial Officer) of Blue Dolphin, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

1. The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Blue Dolphin.

/s/ JONATHAN P. CARROLL

Jonathan P. Carroll

Chief Executive Officer, President, Assistant Treasurer and Secretary

(Principal Executive Officer and Principal Financial Officer)

August 14, 2020

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2020	Aug. 14, 2020
Document And Entity Information
Entity Registrant Name	BLUE DOLPHIN ENERGY CO
Entity Central Index Key	0000793306
Document Type	10-Q
Document Period End Date	Jun. 30, 2020
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Is Entity's Reporting Status Current?	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	true
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity Incorporation State Country Code	DE
Entity File Number	0-15905
Entity Common Stock, Shares Outstanding		12,693,514
Document Fiscal Period Focus	Q2
Document Fiscal Year Focus	2020

XML

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
CURRENT ASSETS
Cash and cash equivalents	$ 4	$ 72
Restricted cash	49	49
Accounts receivable, net	138	446
Accounts receivable, related party	0	1,364
Prepaid expenses and other current assets	1,912	2,276
Deposits	224	158
Inventory	3,558	1,645
Refundable federal income tax	100	65
Total current assets	5,985	6,075
LONG-TERM ASSETS
Total property and equipment, net	63,601	63,893
Operating lease ROU assets	576	649
Restricted cash, noncurrent	547	547
Surety bonds	230	230
Deferred tax assets, net	0	50
Total long-term assets	64,954	65,369
TOTAL ASSETS	70,939	71,444
CURRENT LIABILITIES
Long-term debt less unamortized debt issue costs, current portion, in default	33,612	33,836
Line of credit payable less unamortized debt issue costs (in default)	10,470	11,464
Long-term debt, related party, current portion, in default	12,573	6,001
Interest payable (in default)	4,824	3,814
Interest payable, related party (in default)	2,494	2,174
Accounts payable	2,985	1,877
Accounts payable, related party	149	149
Current portion of lease liabilities	313	251
Asset retirement obligations, current portion	2,436	2,565
Accrued expenses and other current liabilities	2,775	3,333
Total current liabilities	72,631	65,464
LONG-TERM LIABILITIES
Long-term operating leases, net of current	470	564
Deferred revenue	1,748	1,930
Total long-term liabilities	2,218	2,494
TOTAL LIABILITIES	74,849	67,958
Commitments and contingencies (Note 18)
STOCKHOLDERS' DEFICIT
Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 and 12,327,365 shares issued at June 30, 2020 and December 31, 2019, respectively)	127	123
Additional paid-in capital	38,457	38,275
Accumulated deficit	(42,494)	(34,912)
TOTAL STOCKHOLDERS' EQUITY (DEFICIT)	(3,910)	3,486
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)	$ 70,939	$ 71,444

XML

Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
STOCKHOLDERS' DEFICIT
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	20,000,000	20,000,000
Common stock, shares issued	12,693,514	12,327,365
Common stock, shares outstanding	12,693,514	12,327,365

XML

Consolidated Statements of Operations (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
REVENUE FROM OPERATIONS
Refinery operations	$ 17,359	$ 77,257	$ 78,256	$ 145,115
Tolling and terminaling	1,110	1,088	2,213	2,157
Total revenue from operations	18,469	78,345	80,469	147,272
COST OF GOODS SOLD
Crude oil, fuel use, and chemicals	16,783	76,364	76,503	139,551
Other conversion costs	2,893	2,192	5,261	4,521
Total cost of goods sold	19,676	78,556	81,764	144,072
Gross profit (deficit)	(1,207)	(211)	(1,295)	3,200
COST OF OPERATIONS
LEH operating fee	190	183	337	333
Other operating expenses	47	56	106	113
General and administrative expenses	531	579	1,175	1,249
Depletion, depreciation and amortization	669	633	1,302	1,223
Total cost of operations	1,437	1,451	2,920	2,918
Income (loss) from operations	(2,644)	(1,662)	(4,215)	282
OTHER INCOME (EXPENSE)
Easement, interest and other income	80	1	100	1
Interest and other expense	(1,678)	(1,638)	(3,452)	(2,835)
Total other expense	(1,598)	(1,637)	(3,352)	(2,834)
Loss before income taxes	(4,242)	(3,299)	(7,567)	(2,552)
Income tax expense	0	0	(15)	0
Net loss	$ (4,242)	$ (3,299)	$ (7,582)	$ (2,552)
Loss per common share:
Basic	$ (0.34)	$ (0.30)	$ (0.61)	$ (0.23)
Diluted	$ (0.34)	$ (0.30)	$ (0.61)	$ (0.23)
Weighted average number of common shares outstanding:
Basic	12,580,853	10,975,514	12,454,109	10,975,514
Diluted	12,580,853	10,975,514	12,454,109	10,975,514

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
OPERATING ACTIVITIES
Net loss	$ (7,582)	$ (2,552)
Adjustments to reconcile net loss to net cash used in operating activities:
Depletion, depreciation and amortization	1,302	1,223
Deferred income tax	15	0
Amortization of debt issue costs	284	189
Guaranty fees paid in kind	305	0
Deferred revenues and expenses	(182)	0
Gain on issuance of shares	(80)	0
Changes in operating assets and liabilities
Changes in accounts receivable	308	209
Changes in accounts receivable, related party	1,364	(492)
Changes in prepaid expenses and other current assets	364	503
Changes in deposits and other assets	(66)	0
Changes in inventory	(1,913)	(287)
Changes in accrued arbitration award	0	(11,600)
Changes in accounts payable, accrued expenses and other liabilities	1,807	1,211
Changes in accounts payable, related party	0	302
Net cash used in operating activities	(4,074)	(11,294)
INVESTING ACTIVITIES
Capital expenditures	(908)	(494)
Net cash used in investing activities	(908)	(494)
FINANCING ACTIVITIES
Proceeds from line of credit	0	12,402
Payments on debt	(1,501)	(541)
Net activity on related-party debt	6,415	229
Net cash provided by financing activities	4,914	12,090
Net change in cash, cash equivalents, and restricted cash	(68)	302
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD	668	1,665
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD	600	1,967
Non-cash investing and financing activities:
Financing of capital expenditures via accounts payable and finance leases	0	86
Issuance of shares to extinguish debt	120	0
Conversion of related-party notes to common stock	148	0
Line of credit closing costs included in principal balance	0	398
Interest paid	1,608	1,174
Income taxes paid	$ 0	$ 0

XML

1. Organization

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization

Overview

Blue Dolphin is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operate a light sweet-crude, 15,000-bpd crude distillation tower with more than 1.2 million bbls of petroleum storage tank capacity in Nixon, Texas. Blue Dolphin was formed in 1986 as a Delaware corporation and is traded on the OTCQX under the ticker symbol “BDCO”. Blue Dolphin has 20.0 million shares of Common Stock and 2.5 million shares of Preferred Stock authorized. There are approximately 12.7 million shares of Common Stock and no shares of Preferred Stock issued and outstanding.

Our assets are primarily organized in two segments: refinery operations (owned by LE) and tolling and terminaling services (owned by LRM and NPS). Subsidiaries that are reflected in corporate and other include BDPL (inactive pipeline and facilities assets), BDPC (inactive leasehold interests in oil and gas wells), and BDSC (administrative services). See “Note (4)” to our consolidated financial statements for more information about our business segments.

Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours,” refer to Blue Dolphin, one or more of its consolidated subsidiaries or all of them taken as a whole.

Affiliates

Affiliates control approximately 82% of the voting power of our Common Stock. An Affiliate operates and manages all Blue Dolphin properties and funds working capital requirements during periods of working capital deficits, and an Affiliate is a significant customer of our refined products. Blue Dolphin and certain of its subsidiaries are currently parties to a variety of agreements with Affiliates. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and arrangements and working capital deficits.

Going Concern

Management has determined that certain factors raise substantial doubt about our ability to continue as a going concern. These factors include the following:

Defaults Under Secured Loan Agreements with Third Parties. Defaults under our secured loan agreements with third parties include loan agreements with Veritex in the original aggregate principal amount of $35.0 million, which are guaranteed 100% by the USDA, and a line of credit agreement with Pilot in the original principal amount of $13.0 million. Certain of our related-party debt is also in default. See “Note (3)” of our consolidated financial statements for disclosures related to related-party debt.

Veritex Loan Agreements. In September 2017, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex regarding events of default under our secured loan agreements, including, but not limited to, the occurrence of the GEL Final Arbitration Award, associated material adverse effect conditions, failure by LE to replenish a $1.0 million payment reserve account, and the occurrence of events of default under our other secured loan agreements with Veritex. Further, Veritex informed obligors that it would consider a final confirmation of the GEL Final Arbitration Award to be a material event of default under the loan agreements. Veritex did not accelerate or call due our secured loan agreements considering then ongoing settlement discussions between GEL and the Lazarus Parties. Instead, Veritex expressly reserved all its rights, privileges and remedies related to events of default.

In April 2019, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex that the bank agreed to waive certain covenant defaults and forbear from enforcing its remedies under our secured loan agreements subject to: (i) the agreement and concurrence of the USDA and (ii) the replenishment of the payment reserve account on or before August 31, 2019. Following the GEL Settlement, the associated mutual releases became effective and GEL filed the stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and the obligors were still in default under our secured loan agreements with Veritex.

In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

At June 30, 2020, LE and LRM were in violation of the debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants under our secured loan agreements with Veritex. As a result, the debt associated with these loans was classified within current portion of long-term debt on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Veritex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. Defaults under our secured loan agreements with Veritex permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. Any exercise by Veritex of its rights and remedies under our secured loan agreements would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. Further, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

Amended Pilot Line of Credit. On May 4, 2020, Pilot sent NPS, as borrower, and LRM, LEH, LE and Blue Dolphin, each a guarantor and collectively guarantors, a notice demanding the immediate payment of the unpaid principal amount and all interest accrued and unpaid, and all other amounts owing or payable (the “Obligations”) under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, the Obligations began to accrue interest at a rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor of paying the past due Obligations constituted an event of default. Pilot expressly retained and reserved all its rights and remedies available to it at any time, including without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity. Any exercise by Pilot of its rights and remedies under the Amended Pilot Line of Credit would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations.

On June 1, 2020, Pilot notified borrower and guarantors by letter of its intent to apply as a setoff Pilot’s payment obligations owing to or for the credit or the account of borrower under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May, 2019, between borrower and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between the borrower and Pilot, against the Obligations. As of the date of the letter, the amount of such setoff was approximately $0.2 million. The setoff was only in partial satisfaction of the Obligations and Pilot expressly retained and reserved all its rights and remedies available to it at any time, including, without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity.

The borrower and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue to work with the borrower to settle the Obligations. Borrower and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. Our ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. In the event we are unsuccessful in such endeavors, we may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

See “Note (10)” and “Note (11)” to our consolidated financial statements for additional information related to defaults under our secured loan agreements with Veritex and Pilot and their potential effects on our business, financial condition, and results of operations.

Margin Deterioration and Volatility. Steps taken to address the ongoing COVID-19 pandemic globally and nationally and the actions of members of the OPEC and other producer countries with respect to oil production and pricing significantly impacted supply and demand in global oil and gas markets, causing oil prices to decline sharply, as well as other changes to the economic outlook in the near term. Such subsequent developments included, but are not limited to, government-imposed temporary business closures and voluntary shelter-at-home directives as well as developments in production discussions between global oil producers, and the effect thereof. Oil prices as well as demand are expected to continue to be volatile as a result of the near-term over-supply and the ongoing COVID-19 pandemic as changes in oil inventories, industry demand and global and national economic performance are reported, and we cannot predict when prices and demand will improve and stabilize. We are currently unable to estimate the impact these events will have on our future financial position and results of operations. However, we expect margins will likely remain weak for the remainder of 2020 until global demand begins to recover. Accordingly, we can provide no assurances that these events will not have a material adverse effect on our financial position or results of operations.

Net Losses and Working Capital Deficits.

Net Losses. Net loss for the three months ended June 30, 2020 was $4.2 million, or a loss of $0.34 per share, compared to a net loss of $3.3 million, or a loss of $0.30 per share, for the three months ended June 30, 2019. The increase in net loss was the result of less favorable margins per bbl and lower sales volume during the three months ended June 30, 2020 compared to the same period in 2019. Net loss for the six months ended June 30, 2020 was $7.6 million, or a loss of $0.61 per share, compared to a net loss of $2.6 million, or a loss of $0.23 per share, for the six months ended June 30, 2019. The significant increase in net loss was the result of less favorable margins per bbl and lower sales volume during the six-month period ended June 30, 2020 compared to the same period a year earlier.

Working Capital Deficits. We had a working capital deficit of $66.6 million and $59.4 million at June 30, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $20.5 million and $19.6 million at June 30, 2020 and December 31, 2019, respectively. We had cash and cash equivalents and restricted cash (current portion) of less than $0.01 million and $0.05 million, respectively, at June 30, 2020. Comparatively, we had cash and cash equivalents and restricted cash (current portion) of $0.07 million and $0.05 million, respectively, at December 31, 2019.

Operating Risks

Successful execution of our business strategy depends on several key factors, including, having adequate working capital to meet operational needs and regulatory requirements, maintaining safe and reliable operations at the Nixon facility, meeting contractual obligations, and having favorable margins on refined products. As discussed under “Note (1) – Going Concern” above and throughout this report, we are currently unable to estimate the impact the ongoing COVID-19 pandemic will have on our future financial position and results of operations. Our business was deemed as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. Management has taken and continues to take all prudent steps, however, there can be no assurance that our business strategy will be successful, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. Further, if Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

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2. Principles of Consolidation and Significant Accounting Policies

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Principles of Consolidation and Significant Accounting Policies

Basis of Presentation

The accompanying unaudited consolidated financial statements, which include Blue Dolphin and its subsidiaries, have been prepared in accordance with GAAP for interim consolidated financial information pursuant to the rules and regulations of the SEC under Article 10 of Regulation S-X and the instructions to Form 10-Q. Accordingly, certain information and footnote disclosures normally included in our audited financial statements have been condensed or omitted pursuant to the SEC’s rules and regulations. Significant intercompany transactions have been eliminated in the consolidation. In management’s opinion, all adjustments considered necessary for a fair presentation have been included, disclosures are adequate, and the presented information is not misleading.

The consolidated balance sheet as of December 31, 2019 was derived from the audited financial statements at that date. The accompanying consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 as filed with the SEC. Operating results for the three and six months ended June 30, 2020 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2020, or for any other period. As discussed further below within this “Note (2) – Use of Estimates,” the ongoing COVID-19 pandemic has resulted in significant economic disruption globally. This disruption became more acute in the latter half of March 2020; therefore, our operating results for the three and six months ended June 30, 2020 do not fully reflect the impact this disruption has had, and will likely continue to have, on us.

Significant Accounting Policies

The summary of significant accounting policies of Blue Dolphin is presented to assist in understanding our consolidated financial statements. Our consolidated financial statements and accompanying notes are representations of management, who is responsible for their integrity and objectivity. These accounting policies conform to GAAP and have been consistently applied in the preparation of our consolidated financial statements.

Use of Estimates. The ongoing COVID-19 pandemic and certain developments in the global oil markets have impacted and continue to impact our business. Our business was designated as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable to predict the ultimate economic impact of COVID-19 on our business. 

The nature of our business requires that we make estimates and assumptions in accordance with U.S. GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenue and expenses during the reporting period. The ongoing COVID-19 pandemic has impacted these estimates and assumptions and will continue to do so.

We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of COVID-19 as of June 30, 2020 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.

Cash and Cash Equivalents. Cash and cash equivalents represent liquid investments with an original maturity of three months or less. Cash balances are maintained in depository and overnight investment accounts with financial institutions that, at times, may exceed insured deposit limits. We monitor the financial condition of the financial institutions and have experienced no losses associated with these accounts.

Restricted Cash. Restricted cash, current portion primarily represents a payment reserve account held by Veritex as security for payments under a loan agreement. Restricted cash, noncurrent represents funds held in the Veritex disbursement account for payment of construction related expenses to complete building new petroleum storage tanks.

Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable are presented net of any necessary allowance(s) for doubtful accounts. Receivables are recorded at the invoiced amount and generally do not bear interest. An allowance for doubtful accounts is established, when necessary, based on prior experience and other factors which, in management's judgment, deserve consideration in estimating bad debts.  Management assesses collectability of the customer’s account based on current aging status, collection history, and financial condition.  Based on a review of these factors, management establishes or adjusts the allowance for specific customers and the entire accounts receivable portfolio.  We had an allowance for doubtful accounts of $0.1 million at both June 30, 2020 and December 31, 2019.

Inventory. Inventory primarily consists of refined products, crude oil and condensate, and chemicals. Inventory is valued at lower of cost or net realizable value with cost determined by the average cost method, and net realizable value determined based on estimated selling prices less associated delivery costs. If the net realizable value of our refined products inventory declines to an amount less than our average cost, we record a write-down of inventory and an associated adjustment to cost of goods sold. See “Note (7)” to our consolidated financial statements for additional disclosures related to inventory.

Property and Equipment.

Refinery and Facilities. We plan to continue making improvements to the crude distillation tower based on operational needs and technological advances. Additions to refinery and facilities assets are capitalized, and expenditures for repairs and maintenance are expensed as incurred. We record refinery and facilities at cost less any adjustments for depreciation or impairment. Adjustment of the asset and the related accumulated depreciation accounts are made for the refinery and facilities asset’s retirement and disposal, with the resulting gain or loss included in the consolidated statements of operations. For financial reporting purposes, depreciation of refinery and facilities assets is computed using the straight-line method using an estimated useful life of 25 years beginning when the refinery and facilities assets are placed in service. We did not record any impairment of our refinery and facilities assets for the periods presented.

Pipelines and Facilities. Our pipelines and facilities are recorded at cost less any adjustments for depreciation or impairment. Depreciation is computed using the straight-line method over estimated useful lives ranging from 10 to 22 years. In accordance with FASB ASC guidance we performed periodic impairment testing of our pipeline and facilities assets in 2016. Upon completion of testing, our pipeline assets were fully impaired at December 31, 2016. All pipeline transportation services to third parties have ceased, existing third-party wells along our pipeline corridor have been permanently abandoned, and no new third-party wells are being drilled near our pipelines. We plan to decommission the offshore pipelines and platform assets in the third quarter of 2020.

Oil and Gas Properties. Our oil and gas properties are accounted for using the full-cost method of accounting, whereby all costs associated with acquisition, exploration and development of oil and gas properties, including directly related internal costs, are capitalized on a cost center basis.  Amortization of such costs and estimated future development costs are determined using the unit-of-production method. All leases associated with our oil and gas properties have expired, and our oil and gas properties were fully impaired in 2011.

CIP. CIP expenditures, including capitalized interest, relate to construction and refurbishment activities and equipment for the Nixon facility. These expenditures are capitalized as incurred. Depreciation begins once the asset is placed in service. See “Note (8)” to our consolidated financial statements for additional disclosures related to our refinery and facilities assets, oil and gas properties, pipelines and facilities assets, and CIP. 

Leases. We evaluate if a contract is or contains a lease at inception of the contract. If we determine that a contract is or contains a lease, we recognize ROU asset and lease liability at the commencement date of the lease based on the present value of lease payments over the lease term. The present value of the lease payments is determined by using the implicit rate when readily determinable. If not determinable, we use the incremental borrowing rate to discount lease payments to present value. Lease terms include options to extend or terminate the lease when it is reasonably certain that we will exercise those options.

We recognize ROU assets and lease liabilities for leasing arrangements with terms greater than one year. We account for lease and non-lease components in a contract as a single lease component for all classes of underlying assets. We allocate the consideration in these contracts based on pricing information contained in the lease.

Expense for an operating lease is recognized as a single lease cost on a straight-line basis over the lease term and is reflected in the appropriate income statement line item based on the leased asset’s function. Amortization expense of a finance lease ROU asset is recognized on a straight-line basis over the lesser of the useful life of the leased asset or the lease term. However, if the lease transfers ownership of the finance lease ROU asset to us at the end of the lease term, the finance lease ROU asset is amortized over the useful life of the leased asset. Amortization expense is reflected in ‘depreciation and amortization expense.’ Interest expense is incurred based on the carrying value of the lease liability and is reflected in ‘interest and other expense.’

Revenue Recognition.

Refinery Operations Revenue. Revenue from the sale of refined products is recognized when the product is sold to the customer in fulfillment of performance obligations. Each load of refined product is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are met when control is transferred to the customer. Control is transferred to the customer when the product has been lifted or, in cases where the product is not lifted immediately (bill and hold arrangements), when the product is added to the customer’s bulk inventory as stored at the Nixon facility.

We consider a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the refined product, the transfer of significant risks and rewards, our rights to payment, and transfer of legal title. In each case, the term between the sale and when payment is due is not significant. Transportation, shipping, and handling costs incurred are included in cost of goods sold. Excise and other taxes that are collected from customers and remitted to governmental authorities are not included in revenue.

Tolling and Terminaling Revenue. Tolling and terminaling revenue represents fees pursuant to: (i) tank storage agreements, whereby a customer agrees to pay a certain fee per tank based on tank size over a period of time for the storage of products and (ii) tolling agreements, whereby a customer agrees to pay a certain fee per gallon or barrel for throughput volumes moving through the naphtha stabilizer unit and a fixed monthly reservation fee for use of the naphtha stabilizer unit.

We typically satisfy performance obligations for tolling and terminaling operations with the passage of time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the term of the agreement. We allocate the transaction price to the single performance obligation that exists under the agreement, and we recognize revenue in the amount for which we have a right to invoice. Generally, payment terms do not exceed 30 days.

Revenue from tank storage customers may, from time to time, include fees for ancillary services, such as in-tank and tank-to-tank blending. These services are considered optional to the customer, and the price we charge for such services is not included in the fixed cost under the customer’s tank storage agreement. Ancillary services are considered a separate performance obligation by us under the tank storage agreement. The performance obligation is satisfied when the requested service has been performed in the applicable period.

Deferred Revenue. We record deferred revenue when cash payments are received or due in advance of our performance. An increase in the deferred revenue balance reflects cash payments received or due in advance of satisfying our performance obligations, offset by recognized revenue that was included in the deferred revenue balance at the beginning of the period. Deferred revenue represents a liability as of the balance sheet date related to a revenue producing activity for which revenue has not yet been recognized. We record deferred revenue when we receive consideration under a contract before achieving certain criteria that must be met for revenue to be recognized in conformity with GAAP.

Income Taxes. Deferred income taxes are determined based on the differences between the financial reporting and tax basis of assets and liabilities, as well as operating losses and tax credit carryforwards using currently enacted tax rates and laws in effect for the year in which the differences are expected to reverse. We record a valuation allowance against deferred income tax assets if it is more likely than not that those assets will not be realized. The provision for income taxes comprises our current tax liability and change in deferred income tax assets and liabilities.

Significant judgment is required in evaluating uncertain tax positions and determining its provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to determine the realizability of deferred tax assets. We consider whether it is more likely than not that a portion or all the deferred tax assets will be realized, which is dependent upon the generation of future taxable income prior to the expiration of any NOL carryforwards. When we determine that it is more likely than not that a tax benefit will not be realized, a valuation allowance is recorded to reduce deferred tax assets. A significant piece of objective negative evidence evaluated was cumulative losses incurred over the three-year period ended June 30, 2020. Such objective evidence limits the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of June 30, 2020 and December 31, 2019. We expect to recover deferred tax assets related to AMT credit carryforwards. In addition, we have NOL carryforwards that remain available for future use.

The benefit of an uncertain tax position is recognized in the financial statements if it meets a minimum recognition threshold. A determination is first made as to whether it is more likely than not that the income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If the income tax position is expected to meet the more-likely-than-not criteria, the benefit recorded in the financial statements equals the largest amount that is greater than 50% likely to be realized upon its ultimate settlement. At June 30, 2020 and December 31, 2019, there were no uncertain tax positions for which a reserve or liability was necessary. See “Note (14)” to our consolidated financial statements for more information related to income taxes.

Impairment or Disposal of Long-Lived Assets. We periodically evaluate our long-lived assets for impairment. Additionally, we evaluate our long-lived assets when events or circumstances indicate that the carrying value of these assets may not be recoverable. The carrying value is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset or group of assets is recognized. Significant management judgment is required in the forecasting of future operating results that are used in the preparation of projected cash flows and, should different conditions prevail or judgments be made, material impairment charges could be necessary. The GEL Final Arbitration Award represented a significant adverse change that could have affected the value of certain of our long-lived assets, and management performed potential impairment testing of our refinery and facilities assets in 2019 and 2018. Upon completion of each testing, no impairment was deemed necessary. In addition, the market volatility of crude oil prices as a result of the ongoing COVID-19 pandemic could have affected the value of certain of our long-lived assets, and management performed impairment testing of our refinery and facilities assets at June 30, 2020. No impairment was deemed necessary based upon June 30, 2020 testing, and we did not record any impairment of our refinery and facilities assets for the periods presented.

Asset Retirement Obligations. We record a liability for the discounted fair value of an ARO in the period incurred, and we also capitalize the corresponding cost by increasing the carrying amount of the related long-lived asset. The liability is accreted towards its future value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

We have concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Further, we believe that these assets have indeterminate lives because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.

We recorded an ARO liability related to future asset retirement costs associated with dismantling, relocating, or disposing of our offshore platform, pipeline systems, and related onshore facilities, as well as for plugging and abandoning wells and restoring land and sea-beds. Cost estimates for each of our assets were developed based upon regulatory requirements, structural makeup, water depth, reservoir characteristics, reservoir depth, equipment demand, current retirement procedures, and construction and engineering consultations. Estimating future costs are difficult and require management to make judgments that are subject to future revisions based upon numerous factors, including changing technology, political, and regulatory environments. We review our assumptions and estimates of future abandonment costs on an annual basis. See “Note (12)” to our consolidated financial statements for additional information related to AROs.

Computation of Earnings Per Share. We present basic and diluted EPS. Basic EPS excludes dilution and is computed by dividing net income available to common stockholders by the weighted-average number of shares of common stock outstanding for the period. Diluted EPS is computed by dividing net income available to common stockholders by the diluted weighted average number of common shares outstanding, which includes the potential dilution that could occur if securities or other contracts to issue shares of common stock were converted to common stock that then shared in the earnings of the entity. The number of shares related to restricted stock included in diluted EPS is based on the “Treasury Stock Method.” We do not have issued options, warrants, or similar instruments. See “Note (15)” to our consolidated financial statements for additional information related to EPS.

New Pronouncements Adopted. The FASB issues an ASU to communicate changes to the FASB ASC, including changes to non-authoritative SEC content. Recently adopted ASUs include:

Codification Updates to SEC Sections. In July 2019, FASB issued ASU 2019-07, Codification Updates to SEC Sections, which amended certain SEC sections or paragraphs within the FASB ASC. The amendments were made pursuant to SEC Final Rule Releases No. 33-10532, Disclosure Update and Simplification, and Nos. 33-10231 and 33-10442, Investment Company Reporting Modernization, and Miscellaneous Updates (SEC Update). The SEC Final Rule Releases, which required improvements to the XBRL taxonomy, were made to improve, update, and simplify SEC regulations on financial reporting and disclosure. For public companies, the amendments in ASU 2019-07 were effective upon issuance. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

Consolidation. In October 2018, FASB issued ASU 2018-17, Consolidation (Topic 810). This ASU provided targeted improvements to related-party guidance for variable interest entities. Indirect interests held through related parties in common control arrangements are considered on a proportional basis for determining whether fees paid to decision makers and service providers are variable interests. For entities other than private companies, the amendments in ASU 2018-17 were effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

New Pronouncements Issued, Not Yet Effective.

Income Taxes. In March 2018, FASB issued ASU 2018-05, Income Taxes (Topic 740). This guidance amends SEC paragraphs in ASC 740, Income Taxes, to reflect Staff Accounting Bulletin No. 118, which provides guidance for companies that are not able to complete their accounting for the income tax effects of the Tax Cuts and Jobs Act in the period of enactment.  This guidance also includes amendments to the XBRL taxonomy.  For public business entities, the amendments in ASU 2018-05 are effective for fiscal years ending after December 15, 2020. Early adoption is permitted.  We do not expect adoption of this guidance to have a significant impact on our consolidated financial statements.

Other new pronouncements issued but not yet effective are not expected to have a material impact on our financial position, results of operations, or liquidity.

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3. Related Party Transactions

6 Months Ended

Jun. 30, 2020

Related Party Transactions [Abstract]

Related Party Transactions

Working Capital

Currently, we depend on Affiliates for financing when revenue from operations and borrowings under bank facilities are insufficient to meet our liquidity and working capital needs. Such borrowings are reflected in our consolidated balance sheets in accounts payable, related party, and/or long-term debt, related party.

Affiliate Agreements/Transactions

Blue Dolphin and certain of its subsidiaries are party to several agreements with Affiliates. Management believes that these related-party transactions were consummated on terms equivalent to those that prevail in arm's-length transactions. Related-party transactions consist of the following:

Agreement/Transaction	Parties	Type	Effective Date	Interest Rate	Key Terms
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LE	Debt	04/01/2017	2.00%	Tied to payoff of LE $25 million Veritex loan; payments 50% cash, 50% Common Stock
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LRM	Debt	04/01/2017	2.00%	Tied to payoff of LRM $10 million Veritex loan; payments 50% cash, 50% Common Stock
Refinery Equipment Purchase	LTRI - LE	Operations	07/01/2019	---	LE purchase of two (2) refurbished heat exchangers for $0.08 million each
Dock Tolling Agreement	LMT - LE	Operations	05/24/2016	---	5-year term cancellable by either party any time; LE paid flat reservation fee for tolling volumes up to 84,000 gallons per day; excess tolling volumes subject to increased per gallon rate; terminated 07/01/2019
Jet Fuel Sales Agreement	LEH - LE	Operations	04/01/2020	---	1-year term expiring earliest to occur of 03/31/2021 plus 30-day carryover or delivery of maximum jet fuel quantity; LEH bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification
March Carroll Note (in default)	Jonathan Carroll – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; matured 01/01/2019; interest still accruing
March Ingleside Note (in default)	Ingleside – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to Ingleside under previous Amended and Restated Tank Lease Agreement; matured 01/01/2019; interest still accruing
June LEH Note (in default)	LEH – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; reflects amounts owed to Jonathan Carroll under guaranty fee agreements; matured 01/01/2019; interest still accruing
Office Sub-Lease Agreement	LEH - BDSC	Operations	01/01/2018	---	68-month term expiring 08/31/2023; office lease Houston, Texas; includes 6-month rent abatement period; rent approximately $0.02 million per month
Amended and Restated Operating Agreement	LEH – Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC	Debt	04/01/2020	---	3-year term; expires 04/01/2023 or notice by either party at any time of material breach or 90 days Board notice; LEH receives management fee of 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest, of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC
Loan and Security Agreement (in default)	LEH - BDPL	Debt	08/15/2016	16.00%	2-year term; $4.0 million principal amount; $0.5 million annual payment; proceeds used for working capital; no financial maintenance covenants; secured by certain BDPL property

(1)  On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note.

Related-Party Financial Impact

Consolidated Balance Sheets.

Accounts receivable, related party. Accounts receivable, related party totaled $0 and $1.4 million at June 30, 2020 and December 31, 2019, respectively. At December 31, 2019, accounts receivable, related party represented amounts owed from LEH for the sale of jet fuel under the Jet Fuel Sales Agreement.  Amounts are settled under normal business terms.  Amounts outstanding relating to the Jet Fuel Sales Agreement can vary significantly period to period based on the timing of the related sales and payments received.  See below for the total amount owed to LEH under the June LEH Note and the BDPL Loan Agreement.

Accounts payable, related party. Accounts payable, related party to LTRI related to the purchase of refinery equipment totaled $0.2 million at both June 30, 2020 and December 31, 2019.

Long-term debt, related party, current portion (in default) and accrued interest payable, related party.

	June 30,			December 31,
	2020			2019
	(in thousands)
LEH
June LEH Note (in default)	$	6,336		$	-
BDPL Loan Agreement		6,494			6,174
LEH Total		12,830			6,174
Ingleside
March Ingleside Note (in default)		1,039			1,004
Jonathan Carroll
March Carroll Note (in default)		1,198			997
		15,067			8,175
Less: Long-term debt, related party, current portion, in default		(12,573	)		(6,001	)
Less: Accrued interest payable, related party (in default)		(2,494	)		(2,174	)
	$	-		$	-

Consolidated Statements of Operations.

Total revenue from operations.

	Three Months Ended June 30,								Six Months Ended June 30,
	2020				2019				2020				2019
Refinery operations
LEH	$	4,587	24.8	%	$	24,173	30.2	%	$	22,302	27.7	%	$	44,982	30.2	%
Third-Parties		12,772	69.2	%		53,084	68.3	%		55,954	69.5	%		100,133	68.3	%
Tolling and terminaling
Third-Parties		1,110	6.0	%		1,088	1.5	%		2,213	2.8	%		2,157	1.5	%
	$	18,469	100.0	%	$	78,345	100.0	%	$	80,469	100.0	%	$	147,272	100.0	%

Interest expense.

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(in thousands)
Jonathan Carroll
Guaranty Fee Agreements
First Term Loan Due 2034	$	108	$	111	$	216	$	223
Second Term Loan Due 2034		44		46		89		92
March Carroll Note (in default)		20		28		43		53
LEH
BDPL Loan Agreement (in default)		160		160		320		320
June LEH Note (in default)		117		16		142		23
Ingleside
March Ingleside Note (in default)		15		26		35		52
	$	464	$	387	$	845	$	763

Other. Fees associated with the Dock Tolling Agreement with LMT totaled $0 and $0.2 million for the three months ended June 30, 2020 and 2019, respectively. Fees associated with the Dock Tolling Agreement with LMT totaled $0 and $0.4 million for the six months ended June 30, 2020 and 2019, respectively.

Lease payments received under the office sub-lease agreement with LEH totaled approximately $0.01 million for both three-month periods ended June 30, 2020 and 2019. Lease payments received under the office sub-lease agreement with LEH totaled approximately $0.02 million for both six-month periods ended June 30, 2020 and 2019.

The LEH operating fee was flat, totaling approximately $0.2 million for both three-month periods ended June 30, 2020 and 2019. The LEH operating fee was also relatively flat, totaling approximately $0.3 million for both six-month periods ended June 30, 2020 and 2019.

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4. Revenue and Segment Information

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Revenue and Segment Information

We have two reportable business segments: (i) refinery operations and (ii) tolling and terminaling. Refinery operations relate to the refining and marketing of petroleum products at our 15,000-bpd crude distillation tower. Tolling and terminaling operations relate to tolling and storage terminaling services under third-party lease agreements. Both operations are conducted at the Nixon facility. Corporate and other includes BDSC, BDPL and BDPC.

Revenue from Contracts with Customers

Disaggregation of Revenue. Revenue is presented in the table below under “Segment Information” disaggregated by business segment because this is the level of disaggregation that management has determined to be beneficial to users of our financial statements.

Receivables from Contracts with Customers. Our receivables from contracts with customers are presented as receivables, net on our consolidated balance sheets.

Contract Liabilities. Our contract liabilities from contracts with customers are included in accrued expenses and presented in “Note (9)” to our consolidated financial statements.

Remaining Performance Obligations. Most of our contracts with customers are spot contracts and therefore have no remaining performance obligations.

Segment Information. Business segment information for the periods indicated (and as of the dates indicated) was as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
	(in thousands)
Net revenue (excluding intercompany fees and sales)
Refinery operations	$	17,359		$	77,257		$	78,256		$	145,115
Tolling and terminaling		1,110			1,088			2,213			2,157
Total net revenue		18,469			78,345			80,469			147,272
Intercompany fees and sales
Refinery operations		(406	)		(653	)		(1,023	)		(1,259	)
Tolling and terminaling		406			653			1,023			1,259
Total intercompany fees		-			-			-			-
Operation costs and expenses(1)
Refinery operations		(19,418	)		(78,376	)		(81,251	)		(143,528	)
Tolling and terminaling		(258	)		(363	)		(513	)		(727	)
Corporate and other		(47	)		(56	)		(106	)		(113	)
Total operation costs and expenses		(19,723	)		(78,795	)		(81,870	)		(144,368	)
Segment contribution margin (deficit)
Refinery operations		(2,465	)		(1,772	)		(4,018	)		328
Tolling and terminaling		1,258			1,378			2,723			2,689
Corporate and other		(47	)		(56	)		(106	)		(113	)
Total segment contribution margin (deficit)		(1,254	)		(450	)		(1,401	)		2,904
General and administrative expenses(2)
Refinery operations		(327	)		(274	)		(631	)		(606	)
Tolling and terminaling		(68	)		(62	)		(136	)		(105	)
Corporate and other		(326	)		(243	)		(745	)		(688	)
Total general and administrative expenses		(721	)		(579	)		(1,512	)		(1,399	)
Depreciation and amortization
Refinery operations		(294	)		(483	)		(582	)		(948	)
Tolling and terminaling		(324	)		(99	)		(618	)		(198	)
Corporate and other		(51	)		(51	)		(102	)		(77	)
Total depreciation and amortization		(669	)		(633	)		(1,302	)		(1,223	)
Interest and other non-operating expenses, net
Refinery operations		(751	)		(823	)		(1,492	)		(1,606	)
Tolling and terminaling		(616	)		(579	)		(1,386	)		(775	)
Corporate and other		(231	)		(235	)		(474	)		(453	)
Total interest and other non-operating expenses, net		(1,598	)		(1,637	)		(3,352	)		(2,834	)
Income (loss) before income taxes
Refinery operations		(3,837	)		(3,352	)		(6,723	)		(2,832	)
Tolling and terminaling		250			638			583			1,611
Corporate and other		(655	)		(585	)		(1,427	)		(1,331	)
Total loss before income taxes		(4,242	)		(3,299	)		(7,567	)		(2,552	)
Income tax expense		-			-			(15	)		-
Net loss	$	(4,242	)	$	(3,299	)	$	(7,582	)	$	(2,552	)

(1)  Operation costs include cost of goods sold. Also, operation costs within: (a) tolling and terminaling includes terminal operating expenses and an allocation of other costs (e.g. insurance and maintenance) and (b) corporate and other includes expenses related to BDSC, BDPC and BDPL.

(2)  General and administrative expenses within refinery operations include the LEH operating fee.

	Six Months Ended
	June 30,
	2020		2019
	(in thousands)
Capital expenditures
Refinery operations	$	292	$	411
Tolling and terminaling		616		83
Corporate and other		-		-
Total capital expenditures	$	908	$	494

	June 30,		December 31,
	2020		2019
	(in thousands)
Identifiable assets
Refinery operations	$	50,341	$	51,317
Tolling and terminaling		18,750		18,401
Corporate and other		1,848		1,726
Total identifiable assets	$	70,939	$	71,444

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5. Concentration of Risk

6 Months Ended

Jun. 30, 2020

Risks and Uncertainties [Abstract]

Concentration of Risk

Bank Accounts

Financial instruments that potentially subject us to concentrations of risk consist primarily of cash, trade receivables and payables. We maintain cash balances at financial institutions in Houston, Texas. The FDIC insures certain financial products up to a maximum of $250,000 per depositor. At both June 30, 2020 and December 31, 2019, we had cash balances (including restricted cash) that exceeded the FDIC insurance limit per depositor of approximately $0.3 million.

Key Supplier

Operation of the Nixon refinery depends on our ability to purchase adequate amounts of crude oil and condensate. We have a long-term crude supply agreement in place with Pilot. Under the initial term of the crude supply agreement, Pilot will sell us approximately 24.8 million net bbls of crude oil. Thereafter, the crude supply agreement will continue on a one-year evergreen basis. Effective March 1, 2020, Pilot assigned its rights, title, interest, and obligations in the crude supply agreement to Tartan Oil LLC, a Pilot affiliate. Either party may terminate the crude supply agreement by providing the other party 60 days prior written notice.

Pilot also stores crude oil at the Nixon facility under two terminal services agreements. Under the terminal services agreements, Pilot stores crude oil at the Nixon facility at a specified rate per bbl of the storage tank’s shell capacity. Although the initial term of the terminal services agreement expired April 30, 2020, the agreement renewed on a one-year evergreen basis. Either party may terminate the terminal services agreement by providing the other party 60 days prior written notice. However, the terminal services agreement will automatically terminate upon expiration or termination of the crude supply agreement. During the second quarter of 2020, Pilot applied as a setoff Pilot’s payment obligations owed to us under the terminal services agreements between us and Pilot. The setoff was in partial satisfaction of our obligations to Pilot under the Amended Pilot Line of Credit. As of June 1, 2020, the amount of such setoff was approximately $0.2 million. See ‘going concern’ within “Note (1)” to our consolidated financial statements for additional disclosures related to defaults in our debt obligations.

Our financial health could be materially and adversely affected by defaults in our secured loan agreements, margin deterioration and volatility, historic net losses and working capital deficits, as well as termination of the crude supply agreement or terminal services agreement with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, a sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations.

Significant Customers

We routinely assess the financial strength of our customers and have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.

	Number Significant Customers	% Total Revenue from Operations	Portion of Accounts Receivable at Date Indicated
Three Months Ended June 30, 2020	3	69%	$0
Three Months Ended June 30, 2019	4	97%	$0.6 million
Six Months Ended June 30, 2020	4	90%	$0.006 million
Six Months Ended June 30, 2019	4	97%	$0.6 million

One of our significant customers is an Affiliate. The Affiliate, LEH, purchases our jet fuel under a Jet Fuel Sales Agreement and bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification. LEH accounted for nearly 25% and 31% of our total revenue from operations for the three months ended June 30, 2020 and 2019, respectively. LEH accounted for nearly 28% and 31% of our total revenue from operations for the six months ended June 30, 2020 and 2019, respectively. LEH represented $0 in accounts receivable at June 30, 2020. LEH represented $0.5 million in accounts receivable at June 30, 2019.

Amounts outstanding relating to the Jet Fuel Sales Agreement can vary significantly period to period based on the timing of the related sales and payments received. The amounts are settled under normal business terms. The total amount owed to LEH under the June LEH Note and the BDPL Loan Agreement totaled $12.8 million and $6.2 million at June 30, 2020 and December 31, 2019, respectively. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to transactions with Affiliates.

Concentration of Customers. Our operations have a concentration of customers who are refined petroleum product wholesalers. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that these customers may be similarly affected by changes in economic or other conditions including the uncertainties concerning COVID-19 and volatility in the global oil markets. Historically, we have not had any significant problems collecting our accounts receivable.

Refined Product Sales. We sell our products primarily in the U.S. within PADD 3. Occasionally we sell refined products to customers that export to Mexico. Total refined product sales by distillation (from light to heavy) for the periods indicated consisted of the following:

	Three Months Ended June 30,								Six Months Ended Ended June 30,
	2020				2019				2020				2019
	(in thousands, except percent amounts)
LPG mix	$	-	0.0	%	$	1	0	%	$	-	0.0	%	$	9	0	%
Naphtha		3,160	18.2	%		15,416	20.3	%		14,675	18.8	%		29,211	20.1	%
Jet fuel		4,587	26.4	%		24,173	30.7	%		22,302	28.5	%		44,982	31.0	%
HOBM		3,691	21.3	%		16,747	23.8	%		18,882	24.1	%		32,907	22.7	%
AGO		5,921	34.1	%		20,920	25.2	%		22,397	28.6	%		38,006	26.2	%
	$	17,359	100.0	%	$	77,257	100.0	%	$	78,256	100.0	%	$	145,115	100.0	%

An Affiliate, LEH, purchases all of our jet fuel. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate transactions.

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6. Prepaid Expenses and Other Current Assets

6 Months Ended

Jun. 30, 2020

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Prepaid Expenses and Other Current Assets

Prepaid expenses and other current assets as of the dates indicated consisted of the following:

	June 30,		December 31,
	2020		2019
	(in thousands)
Prepaid insurance	$	1,691	$	417
Other prepaids		111		87
Prepaid easement renewal fees		110		121
Prepaid crude oil and condensate		-		1,651
	$	1,912	$	2,276

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7. Inventory

6 Months Ended

Jun. 30, 2020

Inventory Disclosure [Abstract]

Inventory

Inventory as of the dates indicated consisted of the following:

	June 30,		December 31,
	2020		2019
	(in thousands)
HOBM	$	2,833	$	-
Crude oil and condensate		445		959
Chemicals		227		120
AGO		38		440
Propane		12		26
LPG mix		3		5
Naphtha		-		95
	$	3,558	$	1,645

Due to fluctuating commodity prices, we recorded a net realizable value adjustment to inventory of approximately $0.2 million and $0.3 million at June 30, 2020 and December 31, 2019, respectively.

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8. Property, Plant and Equipment, Net

6 Months Ended

Jun. 30, 2020

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment, Net

Property, plant and equipment, net, as of the dates indicated consisted of the following:

	June 30,			December 31,
	2020			2019
	(in thousands)
Refinery and facilities	$	71,254		$	66,317
Land		566			566
Other property and equipment		833			833
		72,653			67,716
Less: Accumulated depletion, depreciation, and amortiation		(13,938	)		(12,739	)
		58,715			54,977
CIP		4,886			8,916
	$	63,601		$	63,893

We capitalize interest cost incurred on funds used to construct property, plant, and equipment. Capitalized interest is recorded as part of the asset it relates to and is depreciated over the asset’s useful life. Capitalized interest cost, which is included in CIP, was $0 and $0.7 million at June 30, 2020 and December 31, 2019. Capital expenditures for expansion at the Nixon facility were funded by long-term debt from Veritex, revenue from operations, and working capital from Affiliates. At June 30, 2020, unused amounts for capital expenditures derived from Veritex loans were reflected in restricted cash (current and non-current portions) on our consolidated balance sheets. See “Note (10)” to our consolidated financial statements for additional disclosures related to working capital deficits and borrowings for capital spending.

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9. Accrued Expenses and Other Current Liabilities

6 Months Ended

Jun. 30, 2020

Other Liabilities, Current [Abstract]

Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities as of the dates indicated consisted of the following:

	June 30,		December 31,
	2020		2019
	(in thousands)
Insurance	$	1,079	$	159
Unearned revenue from contracts with customers		643		1,990
Unearned contract renewal income		500		500
Property, fuel and other taxes		331		183
Other payable		177		228
Board of director fees payable		35		263
Customer deposits		10		10
	$	2,775	$	3,333

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10. Third-Party Long-Term Debt

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Third-Party Long-Term Debt

Loan Agreements

Loan Description	Original Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$25.0	Jun 2034	$0.2 million	WSJ Prime + 2.75%	Refinance loan; capital improvements
Second Term Loan Due 2034 (in default)	$10.0	Dec 2034	$0.1 million	WSJ Prime + 2.75%	Refinance bridge loan; capital improvements
Notre Dame Debt (in default)	$11.7(1)	Jan 2018	No payments to date; payment rights subordinated(2)	16.00%	Working capital; reduced balance of GEL Final Arbitration Award

(1)  Original principal amount was $8.0 million; pursuant to a 2017 sixth amendment, the Notre Dame Debt was amended to increase the principal amount by $3.7 million; the additional principal was used to reduce the GEL Final Arbitration Award by $3.6 million.

(2)  Pursuant to a 2015 subordination agreement, the holder of the Notre Dame Debt agreed to subordinate their right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in favor of Veritex as holder of the First Term Loan Due 2034.

Guarantees and Security

Loan Description	Guarantees	Security
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	● 100% USDA-guarantee; ● Jonathan Carroll personal guarantee(1); ● LEH, LRM and Blue Dolphin cross-guarantee	● first priority lien on Nixon facility’s business assets (excluding accounts receivable and inventory); ● assignment of all Nixon facility contracts, permits, and licenses; ● absolute assignment of Nixon facility rents and leases, including tank rental income; ● $1.0 million payment reserve account held by Veritex; and ● $5.0 million life insurance policy on Jonathan Carroll.
Second Term Loan Due 2034 (in default)	● 100% USDA-guarantee; ● Jonathan Carroll personal guarantee(1); ● LEH, LE and Blue Dolphin cross-guarantee	● second priority lien on rights of LE in crude distillation tower and other collateral of LE; ● first priority lien on real property interests of LRM; ● first priority lien on all LRM fixtures, furniture, machinery and equipment; ● first priority lien on all LRM contractual rights, general intangibles and instruments, except with respect to LRM rights in its leases of certain specified tanks for which Veritex has second priority lien; and ● all other collateral as described in the security documents.
Notre Dame Debt (in default)	---	● Subordinated deed of trust that encumbers the crude distillation tower and general assets of LE(2).

(1)  As a condition of the First Term Loan Due 2034 and Second Term Loan Due 2034, Jonathan Carroll was required to personally guarantee repayment borrowed funds and accrued interest.

(2)  Pursuant to a 2015 subordination agreement, the holder of the Notre Dame Debt agreed to subordinate their right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in favor of Veritex as holder of the First Term Loan Due 2034.

The USDA, acting through its agencies, administers a federal rural credit program that makes direct loans and guarantees portions of loans made and serviced by USDA-qualified lenders for various purposes. Each USDA guarantee is a full faith and credit obligation of the U.S. with the USDA guaranteeing up to 100% of the principal amount. The lender for a USDA-guaranteed loan, in our case Veritex, is required by regulations to retain both the guaranteed and unguaranteed portions of the loan, to service the entire underlying loan, and to remain mortgage and/or secured party of record. Both the guaranteed and unguaranteed portions of the loan are to be secured by the same collateral with equal lien priority. The USDA-guaranteed portion of a loan cannot be paid later than, or in any way be subordinated to, the related unguaranteed portion. See “Note (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and transactions, including long-term debt guarantees.

Representations, Warranties, Covenants, and Defaults

The First Term Loan Due 2034 and Second Term Loan Due 2034 contain representations and warranties, affirmative and negative covenants, and events of default that we consider usual and customary for bank facilities of this type. Specifically, the First Term Loan Due 2034 and Second Term Loan Due 2034 contain debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants. The First Term Loan Due 2034 also requires that a $1.0 million payment reserve account be maintained. There are no financial maintenance covenants associated with the Notre Dame Debt.

Proceeds available for use under the First Term Loan Due 2034 and Second Term Loan Due 2034 were placed in a disbursement account whereby Veritex makes payments for construction related expenses. Amounts held in the disbursement account are reflected as restricted cash (current portion) and restricted cash, noncurrent in our consolidated balance sheets.

As described elsewhere in this report, we are in default under our secured loan agreements. Defaults include events of default and financial covenant violations. Defaults under our secured loan agreements permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. The debt associated with these loans was classified within the current portion of long-term debt on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

Events of Default. In September 2017, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex regarding events of default under our secured loan agreements, including, but not limited to, the occurrence of the GEL Final Arbitration Award, associated material adverse effect conditions, failure by LE to replenish a $1.0 million payment reserve account, and the occurrence of events of default under our other secured loan agreements with Veritex. Further, Veritex informed obligors that it would consider a final confirmation of the GEL Final Arbitration Award to be a material event of default under the loan agreements. Veritex did not accelerate or call due our secured loan agreements considering then ongoing settlement discussions between GEL and the Lazarus Parties. Instead, Veritex expressly reserved all its rights, privileges and remedies related to events of default.

In April 2019, LE, Jonathan Carroll, Blue Dolphin, LRM, and LE received notification from Veritex that the bank agreed to waive certain covenant violations and forbear from enforcing its remedies under our secured loan agreements subject to: (i) the agreement and concurrence of the USDA and (ii) the replenishment of the payment reserve account on or before August 31, 2019. Following the GEL Settlement, the associated mutual releases became effective and GEL filed the stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and the obligors were still in default under our secured loan agreements with Veritex.

Payment Deferments. In April 2020, LE and LRM were each granted a two-month deferment period on their respective Veritex loans commencing from April 22, 2020 to June 22, 2020. During the deferment period, LE and LRM were not obligated to make payments and interest continued to accrue at the stated rates of the loans. Upon expiration of the deferment period: (i) Veritex re-amortized the loan such that future payments on principal and interest were adjusted based on the remaining principal balances and loan terms, and (ii) all other terms of the loans reverted to the original terms, and previous defaults were reinstated. The deferment did not address LE’s requirement to replenish the payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex.

Financial Covenant Violations.  At June 30, 2020, LE and LRM were in violation of the debt service coverage ratio, current ratio, and debt to net worth ratio financial covenants under our secured loan agreements with Veritex. Any exercise by Veritex of its rights and remedies under our secured loan agreements would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Vertitex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. Defaults under our secured loan agreements and any exercise by Veritex of its rights and remedies related to such defaults may have a material adverse effect on the trading prices of our common stock and on the value of an investment in our common stock, and holders of our common stock could lose their investment in our common stock in its entirety. See “Note (1)” and “Note (11)” to our consolidated financial statements for additional information regarding defaults under our secured loan agreements and their potential effects on our business, financial condition, and results of operations.

Outstanding Principal, Debt Issue Costs, and Accrued Interest

Third-party long-term debt (outstanding principal and accrued interest), as of the dates indicated was as follows:

	June 30,			December 31,
	2020			2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$	22,006		$	21,776
Second Term Loan Due 2034 (in default)		9,125			9,031
Notre Dame Debt (in default)		9,015			8,617
		40,146			39,424
Less: Current portion of long-term debt, net		(33,612	)		(33,836	)
Less: Unamortized debt issue costs		(1,813	)		(1,877	)
Less: Accrued interest payable (in default)		(4,721	)		(3,711	)
	$	-		$	-

Unamortized debt issue costs associated with USDA-guaranteed loans as of the dates indicated consisted of the following:

	June 30,			December 31,
	2020			2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$	1,674		$	1,674
Second Term Loan Due 2034 (in default)		768			768
Less: Accumulated amortization		(629	)		(565	)
	$	1,813		$	1,877

Amortization expense was $0.03 million for both three-month periods ended June 30, 2020 and 2019. Amortization expense was $0.06 million for both six-month periods ended June 30, 2020 and 2019.

Accrued interest related to third-party long-term debt, reflected as accrued interest payable in our consolidated balance sheets, as of the dates indicated consisted of the following:

	June 30,			December 31,
	2020			2019
	(in thousands)
Notre Dame Debt (in default)	$	4,037		$	3,639
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)		461			25
Second Term Loan Due 2034 (in default)		223			47
		4,721			3,711
Less: Accrued interest payable (in default)		(4,721	)		(3,711	)
Long-term Interest Payable, Net of Current Portion	$	-		$	-

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11. Line of Credit Payable

6 Months Ended

Jun. 30, 2020

Line of Credit Facility [Abstract]

Line of Credit Payable

Line of Credit Agreement

Line of Credit Description	Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
Amended Pilot Line of Credit (in default)	$13.0	May 2020	----	14.00%	GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital

Under the Amended Pilot Line of Credit, NPS was required to make monthly interest only payments to Pilot in each of September and October 2019 in the amount of $0.1 million. The required payments were made.

On May 4, 2020, Pilot sent NPS, as borrower, and LRM, LEH, LE and Blue Dolphin, each a guarantor and collectively guarantors, a notice demanding the immediate payment of the Obligations under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, the Obligations began to accrue interest at a rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor of paying the past due Obligations constituted an event of default. Pilot expressly retained and reserved all its rights and remedies available to it at any time, including without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity. Any exercise by Pilot of its rights and remedies under the Amended Pilot Line of Credit would have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations.

On June 1, 2020, Pilot notified borrower and guarantors by letter of its intent to apply as a setoff Pilot’s payment obligations owing to or for the credit or the account of borrower under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May, 2019, between borrower and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between the borrower and Pilot, against the Obligations. As of the date of the letter, the amount of such setoff was approximately $0.2 million. The setoff was only in partial satisfaction of the Obligations and Pilot expressly retained and reserved all its rights and remedies available to it at any time, including, without limitation, the right to exercise all rights and remedies available to Pilot under the Amended Pilot Line of Credit or applicable law or equity.

NPS and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue to work with NPS to settle the Obligations. NPS and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. Our ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. In the event we are unsuccessful in such endeavors, we may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.

Guarantees and Security

Loan Description	Guarantees	Security
Amended Pilot Line of Credit (in default)	●  Blue Dolphin pledged its equity interests in NPS to Pilot to secure NPS’ obligations; ●  Blue Dolphin, LE, LRM, and LEH have each guaranteed NPS’ obligations.	● NPS receivables; ● NPS assets, including a tank lease (the “Tank Lease”); ● LRM receivables.

Representations, Warranties, and Covenants

The Amended Pilot Line of Credit contains customary affirmative and negative covenants and events of default. In a April 30, 2019, Agreement Regarding Attornment of Tank Leases between Veritex, LE, NPS, and Pilot, Veritex in its capacity as a secured lender of LE and LRM, agreed to permit the continued performance of obligations under a certain tank lease agreement if it were to foreclose on LE property that NPS was leasing from LE so long as certain conditions were met. The effectiveness of the Agreement Regarding Attornment of Tank Leases was subject to certain conditions, including the agreement and concurrence of the USDA that the Agreement Regarding Attornment of Tank Leases does not impair or void the First Term Loan Due 2034 and Second Term Loan Due 2034 or any associated guarantees. Veritex agreed to use commercially reasonable efforts to obtain such USDA concurrence, however, as of the filing date of this report such USDA concurrence has not been provided.

Line of credit payable, which represents outstanding principal and accrued interest, as of the dates indicated was as follows:

	June 30,			December 31,
	2020			2019
	(in thousands)
Amended Pilot Line of Credit (in default)	$	10,573		$	11,786
Less: Unamortized debt issue costs		-			(219	)
Less: Interest payable, short-term		(103	)		(103	)
	$	10,470		$	11,464

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12. ARO's

6 Months Ended

Jun. 30, 2020

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Refinery and Facilities

Management has concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Management believes that the refinery and facilities assets have indeterminate lives under FASB ASC guidance for estimating AROs because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.

Pipelines and Facilities and Oil and Gas Properties

We have AROs associated with the decommissioning of our pipelines and facilities assets, as well as the plugging and abandonment of our oil and gas properties. We recorded a discounted liability for the fair value of an ARO with a corresponding increase to the carrying value of the related long-lived asset at the time the asset was installed or placed in service, and we depreciated the amount added to property and equipment and recognized accretion expense relating to the discounted liability over the remaining life of the asset. At June 30, 2020 and December 31, 2019, the liability was fully accreted. See “Note (16)” to our consolidated financial statements for disclosures related to decommissioning of our offshore pipelines and platform assets and related risks.

ARO liability as of the dates indicated was as follows:

	June 30,			December 31,
	2020			2019
	(in thousands)
AROs, at the beginning of the period	$	2,565		$	2,565
Liabilities settled		(129	)		-
		2,436			2,565
Less: AROs, current portion		(2,436	)		(2,565	)
Long-term AROs, at the end of the period	$	-		$	-

Liabilities settled reflects preparatory costs associated with decommissioning our offshore pipelines and platform assets.

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13. Lease Obligations

6 Months Ended

Jun. 30, 2020

Leases, Operating [Abstract]

Leases

Lease Obligations

Operating Lease

Office Lease. BDSC has an office lease related to our headquarters office in Houston, Texas. The 68-month operating lease expires in 2023. BDSC has the option to extend the lease term for one additional five (5) year period if notice of intent to extend is provided to the lessor at least twelve (12) months before the end of the current term. An Affiliate, LEH, subleases a portion of this office space.  Sublease income received from LEH totaled approximately $0.01 million for both the three months ended June 30, 2020 and 2019. Sublease income received from LEH totaled approximately $0.02 million for both the six months ended June 30, 2020 and 2019. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.

Finance Leases

Crane. In January 2018, LE entered a 24-month lease for the purchase of a 20-ton crane for use at the Nixon facility. The lease required a negligible monthly payment and matured in January 2020.

Backhoe Rent-to-Own Agreement. In May 2019, LE entered into a 12-month equipment rental agreement with the option to purchase the backhoe at maturity. The backhoe is being used at the Nixon facility. The equipment rental agreement matured in May 2020. The parties are currently negotiating on the end of lease purchase price for the backhoe.

LACT Unit Rent-to-Own Agreement. In April 2020, LE entered into a 12-month equipment rental agreement with the option to purchase the LACT unit at maturity. The LACT unit, which was installed in June 2020, is being used at the Nixon facility. The equipment rental agreement requires a negligible monthly payment and matures in June 2021. Subsequent to the consolidated balance sheet date, the lease was canceled, and the related equipment was returned.

The following table presents the lease-related assets and liabilities recorded on the consolidated balance sheet:

		June 30,			December 31,
	Balance Sheet Location	2020			2019
		(in thousands)
Assets
Operating lease ROU assets	Operating lease ROU assets	$	787		$	787
Less: Accumulated amortization on operating lease assets	Operating lease ROU assets		(211	)		(138	)
			576			649
Finance lease assets	Property and equipment, net		148			180
Less: Accumulated amortization on finance lease assets	Property and equipment, net		(10	)		(34	)
			138			146
Total lease assets			714			795
Liabilities
Current
Operating lease	Current portion of lease liabilities		185			175
Finance leases	Current portion of lease liabilities		128			76
			313			251
Noncurrent
Operating lease	Long-term lease liabilities, net of current		470			564
Total lease liabilities		$	783		$	815

Weighted average remaining lease term in years
Operating lease	3.17
Finance leases	0.68
Weighted average discount rate
Operating lease	8.25	%
Finance leases	8.25	%

The following table presents information related to lease costs for operating and finance leases:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Operating lease costs	$	51	$	51	$	103	$	77
Finance lease costs:
Depreciation of leased assets		4		4		10		8
Interest on lease liabilities		2		1		3		2
Total lease cost	$	57	$	56	$	116	$	87

The table below presents supplemental cash flow information related to leases as follows:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Cash paid for amounts included in the measurement
of lease liabilities:
Operating cash flows for operating lease	$	43	$	40	$	131	$	96
Operating cash flows for finance leases	$	2	$	1	$	4	$	2
Financing cash flows for finance leases	$	6	$	10	$	12	$	21

As of June 30, 2020, maturities of lease liabilities for the periods indicated were as follows:

June 30,	Operating Lease		Financing Leases		Total
	(in thousands)
2020	$	184	$	128	$	312
2021		204		-		204
2022		226		-		226
2023		41		-		41
	$	655	$	128	$	783

Future minimum annual lease commitments that are non-cancelable:

	Operating
June 30,	Lease
	(in thousands)
2020	$	232
2021		235
2022		239
2023		40
	$	746

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14. Income Taxes

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Tax Provision

The provision for income tax benefit (expense) for the periods indicated was as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Current
Federal	$	-		$	-		$	(15	)	$	-
State		-			-			-			-
Deferred
Federal		893			800			1,591			643
State		-						-
Change in valuation allowance		(893	)		(800	)		(1,591	)		(643	)
Total provision for income taxes	$	-		$	-		$	(15	)	$	-

The state of Texas, TMT is treated as an income tax for financial reporting purposes.

Deferred income taxes as of the dates indicated consisted of the following:

	June 30,			December 31,
	2020			2019
	(in thousands)
Deferred tax assets:
NOL and capital loss carryforwards	$	13,897		$	12,463
Business interest expense		2,648			1,923
Start-up costs (crude oil and condensate processing facility)		551			594
ARO liability/deferred revenue		511			539
AMT credit		-			50
Other		36			11
Total deferred tax assets		17,643			15,580
Deferred tax liabilities:
Basis differences in property and equipment		(6,705	)		(6,183	)
Total deferred tax liabilities		(6,705	)		(6,183	)
		10,938			9,397
Valuation allowance		(10,938	)		(9,347	)
Deferred tax assets, net	$	-		$	50

Deferred Income Taxes

Deferred income tax balances reflect the effects of temporary differences between the carrying amounts of assets and liabilities and their tax basis, as well as from NOL carryforwards. We state those balances at the enacted tax rates we expect will be in effect when taxes are paid. NOL carryforwards and deferred tax assets represent amounts available to reduce future taxable income.

NOL Carryforwards. Under IRC Section 382, a corporation that undergoes an “ownership change” is subject to limitations on its use of pre-change NOL carryforwards to offset future taxable income. Within the meaning of IRC Section 382, an “ownership change” occurs when the aggregate stock ownership of certain stockholders (generally 5% shareholders, applying certain look-through rules) increases by more than fifty (50) percentage points over such stockholders' lowest percentage ownership during the testing period (generally three years). For income tax purposes, we experienced ownership changes in 2005, relating to a series of private placements, and in 2012, because of a reverse acquisition, that limit the use of pre-change NOL carryforwards to offset future taxable income. In general, the annual use limitation equals the aggregate value of common stock at the time of the ownership change multiplied by a specified tax-exempt interest rate. The 2012 ownership change will subject approximately $16.3 million in NOL carryforwards that were generated prior to the ownership change to an annual use limitation of approximately $0.6 million per year. Unused portions of the annual use limitation amount may be used in subsequent years. Because of the annual use limitation, approximately $6.7 million in NOL carryforwards that were generated prior to the 2012 ownership change will expire unused. NOL carryforwards that were generated after the 2012 ownership change and prior to 2018 are not subject to an annual use limitation under IRC Section 382 and may be used for a period of 20 years in addition to available amounts of NOL carryforwards generated prior to the ownership change.

NOL Carryforwards. NOL carryforwards that remained available for future use for the periods indicated were as follow (amounts shown are net of NOLs that will expire unused because of the IRC Section 382 limitation):

	Net Operating Loss Carryforward
	Pre-Ownership Change		Post-Ownership Change		Total
	(in thousands)
Balance at December 31, 2018	$	9,614	$	37,335	$	46,949
Net operating losses		-		5,723		5,723
Balance at December 31, 2019		9,614		43,058		52,672
Net operating losses		-		6,826		6,826
Balance at June 30, 2020	$	9,614	$	49,884	$	59,498

Valuation Allowance. As of each reporting date, management considers new evidence, both positive and negative, to determine the realizability of deferred tax assets. Management considers whether it is more likely than not that some portion or all the deferred tax assets will be realized, which is dependent upon the generation of future taxable income prior to the expiration of any NOL carryforwards. At June 30, 2020 and December 31, 2019, management determined that cumulative losses incurred over the prior three-year period provided significant objective evidence that limited the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of June 30, 2020 and December 31, 2019.

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15. Earnings Per Share

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share

A reconciliation between basic and diluted income per share for the periods indicated was as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Net income (loss)	$	(4,242	)	$	(3,299	)	$	(7,582	)	$	(2,552	)
Basic and diluted income (loss) per share	$	(0.34	)	$	(0.30	)	$	(0.61	)	$	(0.23	)
Basic and Diluted
Weighted average number of shares of
common stock outstanding and potential
dilutive shares of common stock		12,580,853			10,975,514			12,454,109			10,975,215

Diluted EPS is computed by dividing net income available to common stockholders by the weighted average number of shares of common stock outstanding. Diluted EPS for the three and six months ended June 30, 2020 and 2019 was the same as basic EPS as there were no stock options or other dilutive instruments outstanding.

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16. Commitments and Contingencies

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Amended and Restated Operating Agreement

See “Note (3)” to our consolidated financial statements for additional disclosures related to operation and management of all Blue Dolphin properties by an Affiliate under the Amended and Restated Operating Agreement.

BSEE Offshore Pipelines and Platform Decommissioning

BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations. Until such structures are abandoned or removed, lessees and rights-of-way holders are required to inspect and maintain the assets in accordance with regulatory requirements.

In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE on August 15, 2019 to address BDPL’s plans with respect to decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning, along with a safe boarding plan for the platform, within six (6) months (no later than February 15, 2020), and develop and implement a safe boarding plan for submission with such permit applications. Further, BSEE proposed that BDPL complete approved, permitted work within 12 months (no later than August 15, 2020).  BDPL timely submitted permit applications for decommissioning of the subject offshore pipelines and platform assets to BSEE on February 11, 2020 and the USACOE on March 25, 2020. Not all permit applications have been approved by BSEE and the USACOE as required prior to work commencement. Delays in permit approvals may be the result of COVID-19. As a result, BDPL plans to request an extension for decommissioning work.

In April 2020, BSEE issued another INC to BDPL for failure to perform the required structural surveys for the GA-288C Platform. BDPL requested an extension to the INC related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platform surveys were completed, and the INC was resolved in June 2020.

BSEE’s deadline to complete decommissioning of BDPL’s offshore pipelines and platform assets, as well as to complete the structural platform surveys, does not relieve BDPL of its obligations to remedy the BSEE INCs or of BSEE’s authority to impose financial penalties. There can be no assurance that we will be able to meet BSEE’s time tables. If BDPL fails to complete decommissioning of the offshore pipelines and platform assets and/or structural surveys of the platform are not completed by the allowable time frames, BDPL will be subject to vigorous regulatory oversight and enforcement, including but not limited to failure to correct an INC, civil penalties, and revocation of BDPL’s operator designation, which may have a material adverse effect on our earnings, cash flows and liquidity.

We are currently unable to predict the outcome of the BSEE INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At June 30, 2020 and December 31, 2019, BDPL maintained $2.4 million and $2.6 million, respectively, in AROs related to abandonment of these assets.

Defaults Under Secured Loan Agreements with Third Parties

See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for additional disclosures related to defaults under our secured and unsecured debt agreements.

Financing Agreements and Guarantees

Indebtedness. See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for disclosures related to Affiliate and third-party indebtedness and defaults thereto.

Guarantees. Affiliates provided guarantees on certain debt of Blue Dolphin and its subsidiaries. The maximum amount of any guarantee is equal to the principal amount and accrued interest, which amounts are reduced as payments are made. See “Note (1),” “Note (3),” “Note (10),” and “Note (11)” to our consolidated financial statements for additional disclosures related to Affiliate and third-party guarantees associated with indebtedness and defaults thereto.

Health, Safety and Environmental Matters

Our operations are subject to extensive federal, state, and local environmental, health, and safety regulations governing, among other things, the generation, storage, handling, use and transportation of petroleum products and hazardous substances; the emission and discharge of materials into the environment; waste management; characteristics and composition of jet fuel and other products; and the monitoring, reporting and control of air emissions. Our operations also require numerous permits and authorizations under various environmental, health, and safety laws and regulations. Failure to obtain and comply with these permits or environmental, health, or safety laws generally could result in fines, penalties or other sanctions, or a revocation of our permits.

Legal Matters

BOEM Additional Financial Assurance (Supplemental Pipeline Bonds). To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.

BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, and the IBLA granted multiple extension requests that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (see “Note (16) – BSEE Offshore Pipelines and Platform Decommissioning”)will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Due to delays in permit application approvals likely because of COVID-19, BDPL plans to request an extension to BSEE’s August 2020 deadline.

BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.

We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of June 30, 2020. At both June 30, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.

Resolved - GEL Settlement. As previously disclosed, GEL was awarded the GEL Final Arbitration Award in the aggregate amount of $31.3 million. In July 2018, the Lazarus Parties and GEL entered into the GEL Settlement Agreement. The GEL Settlement Agreement was subsequently amended five (5) times to extend the GEL Settlement Payment Date and/or modify certain terms related to the GEL Interim Payments or the GEL Settlement Payment. During the period September 2017 to August 2019, GEL received the following amounts from the Lazarus Parties to reduce the outstanding balance of the GEL Final Arbitration Award:

	(in millions)
Initial payment (September 2017)	$	3.7
GEL Interim Payments (July 2018 to April 2019)		8.0
Settlement Payment (Multiple Payments May 7 to 10, 2019)		10.0
Deferred Interim Installment Payments (June 2019 to August 2019)		0.5
	$	22.2

The GEL Settlement Effective Date occurred on August 23, 2019. As a result of the GEL Settlement: (i) the mutual releases became effective, (ii) GEL filed the stipulation of dismissal of claims against LE, and (iii) Blue Dolphin recognized a $9.1 million gain on the extinguishment of debt on its consolidated statements of operations in the third quarter of 2019. Until the GEL Settlement occurred, the debt was reflected on Blue Dolphin’s consolidated balance sheets as accrued arbitration award payable. At both June 30, 2020 and December 31, 2019, the accrued arbitration award payable was $0.

Other Legal Matters. We are involved in lawsuits, claims, and proceedings incidental to the conduct of our business, including mechanic’s liens, contract-related disputes, and administrative proceedings. Management is in discussion with all concerned parties and does not believe that such matters will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurance that such discussions will result in a manageable outcome. If Veritex and/or Pilot exercise their rights and remedies due to defaults under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.

Nixon Facility Improvements

We have made and will continue to make capital and efficiency improvements at the Nixon facility. Therefore, we incurred and will continue to incur capital expenditures related to these improvements, which include, among other things, facility and land improvements and installation of new or refurbished refinery process equipment.

Share Issuances (Sales of Unregistered Securities)

We are obligated to issue shares of our Common Stock to: (i) non-employee directors for services rendered to the Board and (ii) to Jonathan Carroll pursuant to the Guaranty Fee Agreements. Set forth below is information regarding the sale or issuance of Common Stock related to these obligations during the three and six months ended June 30, 2020:

●  On April 30, 2020, we issued an aggregate of 231,065 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component of guaranty fees for the period November 2019 through March 2020. The average cost basis was $0.69, the low was $0.52, and the high was $1.07. For the foreseeable future, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to be accrued and added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the guaranty fee agreements.

●  On April 30, 2020, we also issued an aggregate of 135,084 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three month periods ended September 30, 2018, March 31, 2019, September 30, 2019, and March 31, 2020. The average cost basis was $0.97, the low was $0.57, and the high was $1.18.

The sale and issuance of these securities were exempt from registration under the Securities Act in reliance on Section 4(a)(2) of the Securities Act.

We recognized a gain on the issuance of shares of approximately $0.1 million for both the three and six months ended June 30, 2020.

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2. Principles of Consolidation and Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Use of Estimates

The ongoing COVID-19 pandemic and certain developments in the global oil markets have impacted and continue to impact our business. Our business was designated as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable to predict the ultimate economic impact of COVID-19 on our business. 

The nature of our business requires that we make estimates and assumptions in accordance with U.S. GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenue and expenses during the reporting period. The ongoing COVID-19 pandemic has impacted these estimates and assumptions and will continue to do so.

We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of COVID-19 as of June 30, 2020 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.

Cash and Cash Equivalents

Cash and cash equivalents represent liquid investments with an original maturity of three months or less. Cash balances are maintained in depository and overnight investment accounts with financial institutions that, at times, may exceed insured deposit limits. We monitor the financial condition of the financial institutions and have experienced no losses associated with these accounts.

Restricted Cash

Restricted cash, current portion primarily represents a payment reserve account held by Veritex as security for payments under a loan agreement. Restricted cash, noncurrent represents funds held in the Veritex disbursement account for payment of construction related expenses to complete building new petroleum storage tanks.

Accounts Receivable and Allowance for Doubtful Accounts

Accounts receivable are presented net of any necessary allowance(s) for doubtful accounts. Receivables are recorded at the invoiced amount and generally do not bear interest. An allowance for doubtful accounts is established, when necessary, based on prior experience and other factors which, in management's judgment, deserve consideration in estimating bad debts.  Management assesses collectability of the customer’s account based on current aging status, collection history, and financial condition.  Based on a review of these factors, management establishes or adjusts the allowance for specific customers and the entire accounts receivable portfolio.  We had an allowance for doubtful accounts of $0.1 million at both June 30, 2020 and December 31, 2019.

Inventory

Inventory primarily consists of refined products, crude oil and condensate, and chemicals. Inventory is valued at lower of cost or net realizable value with cost determined by the average cost method, and net realizable value determined based on estimated selling prices less associated delivery costs. If the net realizable value of our refined products inventory declines to an amount less than our average cost, we record a write-down of inventory and an associated adjustment to cost of goods sold. See “Note (7)” to our consolidated financial statements for additional disclosures related to inventory.

Property and Equipment

Refinery and Facilities. We plan to continue making improvements to the crude distillation tower based on operational needs and technological advances. Additions to refinery and facilities assets are capitalized, and expenditures for repairs and maintenance are expensed as incurred. We record refinery and facilities at cost less any adjustments for depreciation or impairment. Adjustment of the asset and the related accumulated depreciation accounts are made for the refinery and facilities asset’s retirement and disposal, with the resulting gain or loss included in the consolidated statements of operations. For financial reporting purposes, depreciation of refinery and facilities assets is computed using the straight-line method using an estimated useful life of 25 years beginning when the refinery and facilities assets are placed in service. We did not record any impairment of our refinery and facilities assets for the periods presented.

Pipelines and Facilities. Our pipelines and facilities are recorded at cost less any adjustments for depreciation or impairment. Depreciation is computed using the straight-line method over estimated useful lives ranging from 10 to 22 years. In accordance with FASB ASC guidance we performed periodic impairment testing of our pipeline and facilities assets in 2016. Upon completion of testing, our pipeline assets were fully impaired at December 31, 2016. All pipeline transportation services to third parties have ceased, existing third-party wells along our pipeline corridor have been permanently abandoned, and no new third-party wells are being drilled near our pipelines. We plan to decommission the offshore pipelines and platform assets in the third quarter of 2020.

Oil and Gas Properties. Our oil and gas properties are accounted for using the full-cost method of accounting, whereby all costs associated with acquisition, exploration and development of oil and gas properties, including directly related internal costs, are capitalized on a cost center basis.  Amortization of such costs and estimated future development costs are determined using the unit-of-production method. All leases associated with our oil and gas properties have expired, and our oil and gas properties were fully impaired in 2011.

CIP. CIP expenditures, including capitalized interest, relate to construction and refurbishment activities and equipment for the Nixon facility. These expenditures are capitalized as incurred. Depreciation begins once the asset is placed in service. See “Note (8)” to our consolidated financial statements for additional disclosures related to our refinery and facilities assets, oil and gas properties, pipelines and facilities assets, and CIP. 

Leases

We evaluate if a contract is or contains a lease at inception of the contract. If we determine that a contract is or contains a lease, we recognize ROU asset and lease liability at the commencement date of the lease based on the present value of lease payments over the lease term. The present value of the lease payments is determined by using the implicit rate when readily determinable. If not determinable, we use the incremental borrowing rate to discount lease payments to present value. Lease terms include options to extend or terminate the lease when it is reasonably certain that we will exercise those options.

We recognize ROU assets and lease liabilities for leasing arrangements with terms greater than one year. We account for lease and non-lease components in a contract as a single lease component for all classes of underlying assets. We allocate the consideration in these contracts based on pricing information contained in the lease.

Expense for an operating lease is recognized as a single lease cost on a straight-line basis over the lease term and is reflected in the appropriate income statement line item based on the leased asset’s function. Amortization expense of a finance lease ROU asset is recognized on a straight-line basis over the lesser of the useful life of the leased asset or the lease term. However, if the lease transfers ownership of the finance lease ROU asset to us at the end of the lease term, the finance lease ROU asset is amortized over the useful life of the leased asset. Amortization expense is reflected in ‘depreciation and amortization expense.’ Interest expense is incurred based on the carrying value of the lease liability and is reflected in ‘interest and other expense.’

Revenue Recognition

Refinery Operations Revenue. Revenue from the sale of refined products is recognized when the product is sold to the customer in fulfillment of performance obligations. Each load of refined product is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are met when control is transferred to the customer. Control is transferred to the customer when the product has been lifted or, in cases where the product is not lifted immediately (bill and hold arrangements), when the product is added to the customer’s bulk inventory as stored at the Nixon facility.

We consider a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the refined product, the transfer of significant risks and rewards, our rights to payment, and transfer of legal title. In each case, the term between the sale and when payment is due is not significant. Transportation, shipping, and handling costs incurred are included in cost of goods sold. Excise and other taxes that are collected from customers and remitted to governmental authorities are not included in revenue.

Tolling and Terminaling Revenue. Tolling and terminaling revenue represents fees pursuant to: (i) tank storage agreements, whereby a customer agrees to pay a certain fee per tank based on tank size over a period of time for the storage of products and (ii) tolling agreements, whereby a customer agrees to pay a certain fee per gallon or barrel for throughput volumes moving through the naphtha stabilizer unit and a fixed monthly reservation fee for use of the naphtha stabilizer unit.

We typically satisfy performance obligations for tolling and terminaling operations with the passage of time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the term of the agreement. We allocate the transaction price to the single performance obligation that exists under the agreement, and we recognize revenue in the amount for which we have a right to invoice. Generally, payment terms do not exceed 30 days.

Revenue from tank storage customers may, from time to time, include fees for ancillary services, such as in-tank and tank-to-tank blending. These services are considered optional to the customer, and the price we charge for such services is not included in the fixed cost under the customer’s tank storage agreement. Ancillary services are considered a separate performance obligation by us under the tank storage agreement. The performance obligation is satisfied when the requested service has been performed in the applicable period.

Deferred Revenue. We record deferred revenue when cash payments are received or due in advance of our performance. An increase in the deferred revenue balance reflects cash payments received or due in advance of satisfying our performance obligations, offset by recognized revenue that was included in the deferred revenue balance at the beginning of the period. Deferred revenue represents a liability as of the balance sheet date related to a revenue producing activity for which revenue has not yet been recognized. We record deferred revenue when we receive consideration under a contract before achieving certain criteria that must be met for revenue to be recognized in conformity with GAAP.

Income Taxes

Deferred income taxes are determined based on the differences between the financial reporting and tax basis of assets and liabilities, as well as operating losses and tax credit carryforwards using currently enacted tax rates and laws in effect for the year in which the differences are expected to reverse. We record a valuation allowance against deferred income tax assets if it is more likely than not that those assets will not be realized. The provision for income taxes comprises our current tax liability and change in deferred income tax assets and liabilities.

Significant judgment is required in evaluating uncertain tax positions and determining its provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to determine the realizability of deferred tax assets. We consider whether it is more likely than not that a portion or all the deferred tax assets will be realized, which is dependent upon the generation of future taxable income prior to the expiration of any NOL carryforwards. When we determine that it is more likely than not that a tax benefit will not be realized, a valuation allowance is recorded to reduce deferred tax assets. A significant piece of objective negative evidence evaluated was cumulative losses incurred over the three-year period ended June 30, 2020. Such objective evidence limits the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of June 30, 2020 and December 31, 2019. We expect to recover deferred tax assets related to AMT credit carryforwards. In addition, we have NOL carryforwards that remain available for future use.

The benefit of an uncertain tax position is recognized in the financial statements if it meets a minimum recognition threshold. A determination is first made as to whether it is more likely than not that the income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If the income tax position is expected to meet the more-likely-than-not criteria, the benefit recorded in the financial statements equals the largest amount that is greater than 50% likely to be realized upon its ultimate settlement. At June 30, 2020 and December 31, 2019, there were no uncertain tax positions for which a reserve or liability was necessary. See “Note (14)” to our consolidated financial statements for more information related to income taxes.

Impairment or Disposal of Long-Lived Assets

We periodically evaluate our long-lived assets for impairment. Additionally, we evaluate our long-lived assets when events or circumstances indicate that the carrying value of these assets may not be recoverable. The carrying value is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset or group of assets is recognized. Significant management judgment is required in the forecasting of future operating results that are used in the preparation of projected cash flows and, should different conditions prevail or judgments be made, material impairment charges could be necessary. The GEL Final Arbitration Award represented a significant adverse change that could have affected the value of certain of our long-lived assets, and management performed potential impairment testing of our refinery and facilities assets in 2019 and 2018. Upon completion of each testing, no impairment was deemed necessary. In addition, the market volatility of crude oil prices as a result of the ongoing COVID-19 pandemic could have affected the value of certain of our long-lived assets, and management performed impairment testing of our refinery and facilities assets at June 30, 2020. No impairment was deemed necessary based upon June 30, 2020 testing, and we did not record any impairment of our refinery and facilities assets for the periods presented.

Asset Retirement Obligations

We record a liability for the discounted fair value of an ARO in the period incurred, and we also capitalize the corresponding cost by increasing the carrying amount of the related long-lived asset. The liability is accreted towards its future value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

We have concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Further, we believe that these assets have indeterminate lives because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.

We recorded an ARO liability related to future asset retirement costs associated with dismantling, relocating, or disposing of our offshore platform, pipeline systems, and related onshore facilities, as well as for plugging and abandoning wells and restoring land and sea-beds. Cost estimates for each of our assets were developed based upon regulatory requirements, structural makeup, water depth, reservoir characteristics, reservoir depth, equipment demand, current retirement procedures, and construction and engineering consultations. Estimating future costs are difficult and require management to make judgments that are subject to future revisions based upon numerous factors, including changing technology, political, and regulatory environments. We review our assumptions and estimates of future abandonment costs on an annual basis. See “Note (12)” to our consolidated financial statements for additional information related to AROs.

Computation of Earnings Per Share

We present basic and diluted EPS. Basic EPS excludes dilution and is computed by dividing net income available to common stockholders by the weighted-average number of shares of common stock outstanding for the period. Diluted EPS is computed by dividing net income available to common stockholders by the diluted weighted average number of common shares outstanding, which includes the potential dilution that could occur if securities or other contracts to issue shares of common stock were converted to common stock that then shared in the earnings of the entity. The number of shares related to restricted stock included in diluted EPS is based on the “Treasury Stock Method.” We do not have issued options, warrants, or similar instruments. See “Note (15)” to our consolidated financial statements for additional information related to EPS.

New Pronouncements

The FASB issues an ASU to communicate changes to the FASB ASC, including changes to non-authoritative SEC content. Recently adopted ASUs include:

Codification Updates to SEC Sections. In July 2019, FASB issued ASU 2019-07, Codification Updates to SEC Sections, which amended certain SEC sections or paragraphs within the FASB ASC. The amendments were made pursuant to SEC Final Rule Releases No. 33-10532, Disclosure Update and Simplification, and Nos. 33-10231 and 33-10442, Investment Company Reporting Modernization, and Miscellaneous Updates (SEC Update). The SEC Final Rule Releases, which required improvements to the XBRL taxonomy, were made to improve, update, and simplify SEC regulations on financial reporting and disclosure. For public companies, the amendments in ASU 2019-07 were effective upon issuance. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

Consolidation. In October 2018, FASB issued ASU 2018-17, Consolidation (Topic 810). This ASU provided targeted improvements to related-party guidance for variable interest entities. Indirect interests held through related parties in common control arrangements are considered on a proportional basis for determining whether fees paid to decision makers and service providers are variable interests. For entities other than private companies, the amendments in ASU 2018-17 were effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. Adoption of this guidance did not have a significant impact on our consolidated financial statements.

New Pronouncements Issued, Not Yet Effective.

Income Taxes. In March 2018, FASB issued ASU 2018-05, Income Taxes (Topic 740). This guidance amends SEC paragraphs in ASC 740, Income Taxes, to reflect Staff Accounting Bulletin No. 118, which provides guidance for companies that are not able to complete their accounting for the income tax effects of the Tax Cuts and Jobs Act in the period of enactment.  This guidance also includes amendments to the XBRL taxonomy.  For public business entities, the amendments in ASU 2018-05 are effective for fiscal years ending after December 15, 2020. Early adoption is permitted.  We do not expect adoption of this guidance to have a significant impact on our consolidated financial statements.

Other new pronouncements issued but not yet effective are not expected to have a material impact on our financial position, results of operations, or liquidity.

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3. Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2020

Related Party Transactions [Abstract]

Affiliate Agreements/Transactions

Agreement/Transaction	Parties	Type	Effective Date	Interest Rate	Key Terms
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LE	Debt	04/01/2017	2.00%	Tied to payoff of LE $25 million Veritex loan; payments 50% cash, 50% Common Stock
Amended and Restated Guaranty Fee Agreement(1)	Jonathan Carroll - LRM	Debt	04/01/2017	2.00%	Tied to payoff of LRM $10 million Veritex loan; payments 50% cash, 50% Common Stock
Refinery Equipment Purchase	LTRI - LE	Operations	07/01/2019	---	LE purchase of two (2) refurbished heat exchangers for $0.08 million each
Dock Tolling Agreement	LMT - LE	Operations	05/24/2016	---	5-year term cancellable by either party any time; LE paid flat reservation fee for tolling volumes up to 84,000 gallons per day; excess tolling volumes subject to increased per gallon rate; terminated 07/01/2019
Jet Fuel Sales Agreement	LEH - LE	Operations	04/01/2020	---	1-year term expiring earliest to occur of 03/31/2021 plus 30-day carryover or delivery of maximum jet fuel quantity; LEH bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification
March Carroll Note (in default)	Jonathan Carroll – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; matured 01/01/2019; interest still accruing
March Ingleside Note (in default)	Ingleside – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to Ingleside under previous Amended and Restated Tank Lease Agreement; matured 01/01/2019; interest still accruing
June LEH Note (in default)	LEH – Blue Dolphin	Debt	03/31/2017	8.00%	Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; reflects amounts owed to Jonathan Carroll under guaranty fee agreements; matured 01/01/2019; interest still accruing
Office Sub-Lease Agreement	LEH - BDSC	Operations	01/01/2018	---	68-month term expiring 08/31/2023; office lease Houston, Texas; includes 6-month rent abatement period; rent approximately $0.02 million per month
Amended and Restated Operating Agreement	LEH – Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC	Debt	04/01/2020	---	3-year term; expires 04/01/2023 or notice by either party at any time of material breach or 90 days Board notice; LEH receives management fee of 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest, of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC
Loan and Security Agreement (in default)	LEH - BDPL	Debt	08/15/2016	16.00%	2-year term; $4.0 million principal amount; $0.5 million annual payment; proceeds used for working capital; no financial maintenance covenants; secured by certain BDPL property

Accounts payable, related party

	June 30,			December 31,
	2020			2019
	(in thousands)
LEH
June LEH Note (in default)	$	6,336		$	-
BDPL Loan Agreement		6,494			6,174
LEH Total		12,830			6,174
Ingleside
March Ingleside Note (in default)		1,039			1,004
Jonathan Carroll
March Carroll Note (in default)		1,198			997
		15,067			8,175
Less: Long-term debt, related party, current portion, in default		(12,573	)		(6,001	)
Less: Accrued interest payable, related party (in default)		(2,494	)		(2,174	)
	$	-		$	-

Refinery operating expenses

	Three Months Ended June 30,								Six Months Ended June 30,
	2020				2019				2020				2019
Refinery operations
LEH	$	4,587	24.8	%	$	24,173	30.2	%	$	22,302	27.7	%	$	44,982	30.2	%
Third-Parties		12,772	69.2	%		53,084	68.3	%		55,954	69.5	%		100,133	68.3	%
Tolling and terminaling
Third-Parties		1,110	6.0	%		1,088	1.5	%		2,213	2.8	%		2,157	1.5	%
	$	18,469	100.0	%	$	78,345	100.0	%	$	80,469	100.0	%	$	147,272	100.0	%

Accrued interest expenses

	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	(in thousands)
Jonathan Carroll
Guaranty Fee Agreements
First Term Loan Due 2034	$	108	$	111	$	216	$	223
Second Term Loan Due 2034		44		46		89		92
March Carroll Note (in default)		20		28		43		53
LEH
BDPL Loan Agreement (in default)		160		160		320		320
June LEH Note (in default)		117		16		142		23
Ingleside
March Ingleside Note (in default)		15		26		35		52
	$	464	$	387	$	845	$	763

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4. Revenue and Segment Information (Tables)

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Business segment reporting

	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
	(in thousands)
Net revenue (excluding intercompany fees and sales)
Refinery operations	$	17,359		$	77,257		$	78,256		$	145,115
Tolling and terminaling		1,110			1,088			2,213			2,157
Total net revenue		18,469			78,345			80,469			147,272
Intercompany fees and sales
Refinery operations		(406	)		(653	)		(1,023	)		(1,259	)
Tolling and terminaling		406			653			1,023			1,259
Total intercompany fees		-			-			-			-
Operation costs and expenses(1)
Refinery operations		(19,418	)		(78,376	)		(81,251	)		(143,528	)
Tolling and terminaling		(258	)		(363	)		(513	)		(727	)
Corporate and other		(47	)		(56	)		(106	)		(113	)
Total operation costs and expenses		(19,723	)		(78,795	)		(81,870	)		(144,368	)
Segment contribution margin (deficit)
Refinery operations		(2,465	)		(1,772	)		(4,018	)		328
Tolling and terminaling		1,258			1,378			2,723			2,689
Corporate and other		(47	)		(56	)		(106	)		(113	)
Total segment contribution margin (deficit)		(1,254	)		(450	)		(1,401	)		2,904
General and administrative expenses(2)
Refinery operations		(327	)		(274	)		(631	)		(606	)
Tolling and terminaling		(68	)		(62	)		(136	)		(105	)
Corporate and other		(326	)		(243	)		(745	)		(688	)
Total general and administrative expenses		(721	)		(579	)		(1,512	)		(1,399	)
Depreciation and amortization
Refinery operations		(294	)		(483	)		(582	)		(948	)
Tolling and terminaling		(324	)		(99	)		(618	)		(198	)
Corporate and other		(51	)		(51	)		(102	)		(77	)
Total depreciation and amortization		(669	)		(633	)		(1,302	)		(1,223	)
Interest and other non-operating expenses, net
Refinery operations		(751	)		(823	)		(1,492	)		(1,606	)
Tolling and terminaling		(616	)		(579	)		(1,386	)		(775	)
Corporate and other		(231	)		(235	)		(474	)		(453	)
Total interest and other non-operating expenses, net		(1,598	)		(1,637	)		(3,352	)		(2,834	)
Income (loss) before income taxes
Refinery operations		(3,837	)		(3,352	)		(6,723	)		(2,832	)
Tolling and terminaling		250			638			583			1,611
Corporate and other		(655	)		(585	)		(1,427	)		(1,331	)
Total loss before income taxes		(4,242	)		(3,299	)		(7,567	)		(2,552	)
Income tax expense		-			-			(15	)		-
Net loss	$	(4,242	)	$	(3,299	)	$	(7,582	)	$	(2,552	)

(1)  Operation costs include cost of goods sold. Also, operation costs within: (a) tolling and terminaling includes terminal operating expenses and an allocation of other costs (e.g. insurance and maintenance) and (b) corporate and other includes expenses related to BDSC, BDPC and BDPL.

(2)  General and administrative expenses within refinery operations include the LEH operating fee.

	Six Months Ended
	June 30,
	2020		2019
	(in thousands)
Capital expenditures
Refinery operations	$	292	$	411
Tolling and terminaling		616		83
Corporate and other		-		-
Total capital expenditures	$	908	$	494

	June 30,		December 31,
	2020		2019
	(in thousands)
Identifiable assets
Refinery operations	$	50,341	$	51,317
Tolling and terminaling		18,750		18,401
Corporate and other		1,848		1,726
Total identifiable assets	$	70,939	$	71,444

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5. Concentration of Risk (Tables)

6 Months Ended

Jun. 30, 2020

Risks and Uncertainties [Abstract]

Significant customers

	Number Significant Customers	% Total Revenue from Operations	Portion of Accounts Receivable at Date Indicated
Three Months Ended June 30, 2020	3	69%	$0
Three Months Ended June 30, 2019	4	97%	$0.6 million
Six Months Ended June 30, 2020	4	90%	$0.006 million
Six Months Ended June 30, 2019	4	97%	$0.6 million

Percentages of all refined petroleum products sales to total sales

	Three Months Ended June 30,								Six Months Ended Ended June 30,
	2020				2019				2020				2019
	(in thousands, except percent amounts)
LPG mix	$	-	0.0	%	$	1	0	%	$	-	0.0	%	$	9	0	%
Naphtha		3,160	18.2	%		15,416	20.3	%		14,675	18.8	%		29,211	20.1	%
Jet fuel		4,587	26.4	%		24,173	30.7	%		22,302	28.5	%		44,982	31.0	%
HOBM		3,691	21.3	%		16,747	23.8	%		18,882	24.1	%		32,907	22.7	%
AGO		5,921	34.1	%		20,920	25.2	%		22,397	28.6	%		38,006	26.2	%
	$	17,359	100.0	%	$	77,257	100.0	%	$	78,256	100.0	%	$	145,115	100.0	%

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6. Prepaid Expenses and Other Current Assets (Tables)

6 Months Ended

Jun. 30, 2020

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Prepaid balances

	June 30,		December 31,
	2020		2019
	(in thousands)
Prepaid insurance	$	1,691	$	417
Other prepaids		111		87
Prepaid easement renewal fees		110		121
Prepaid crude oil and condensate		-		1,651
	$	1,912	$	2,276

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7. Inventory (Tables)

6 Months Ended

Jun. 30, 2020

Inventory Disclosure [Abstract]

Inventory

	June 30,		December 31,
	2020		2019
	(in thousands)
HOBM	$	2,833	$	-
Crude oil and condensate		445		959
Chemicals		227		120
AGO		38		440
Propane		12		26
LPG mix		3		5
Naphtha		-		95
	$	3,558	$	1,645

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8. Property, Plant and Equipment, Net (Tables)

6 Months Ended

Jun. 30, 2020

Property, Plant and Equipment [Abstract]

Property and equipment

	June 30,			December 31,
	2020			2019
	(in thousands)
Refinery and facilities	$	71,254		$	66,317
Land		566			566
Other property and equipment		833			833
		72,653			67,716
Less: Accumulated depletion, depreciation, and amortiation		(13,938	)		(12,739	)
		58,715			54,977
CIP		4,886			8,916
	$	63,601		$	63,893

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9. Accrued Expenses and Other Current Liabilities (Tables)

6 Months Ended

Jun. 30, 2020

Other Liabilities, Current [Abstract]

Accrued expenses and other current liabilities

	June 30,		December 31,
	2020		2019
	(in thousands)
Insurance	$	1,079	$	159
Unearned revenue from contracts with customers		643		1,990
Unearned contract renewal income		500		500
Property, fuel and other taxes		331		183
Other payable		177		228
Board of director fees payable		35		263
Customer deposits		10		10
	$	2,775	$	3,333

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10. Third-Party Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Loan agreements

Loan Description	Original Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$25.0	Jun 2034	$0.2 million	WSJ Prime + 2.75%	Refinance loan; capital improvements
Second Term Loan Due 2034 (in default)	$10.0	Dec 2034	$0.1 million	WSJ Prime + 2.75%	Refinance bridge loan; capital improvements
Notre Dame Debt (in default)	$11.7(1)	Jan 2018	No payments to date; payment rights subordinated(2)	16.00%	Working capital; reduced balance of GEL Final Arbitration Award

Schedule of long term debt

	June 30,			December 31,
	2020			2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$	22,006		$	21,776
Second Term Loan Due 2034 (in default)		9,125			9,031
Notre Dame Debt (in default)		9,015			8,617
		40,146			39,424
Less: Current portion of long-term debt, net		(33,612	)		(33,836	)
Less: Unamortized debt issue costs		(1,813	)		(1,877	)
Less: Accrued interest payable (in default)		(4,721	)		(3,711	)
	$	-		$	-

Schedule of debt issue costs

	June 30,			December 31,
	2020			2019
	(in thousands)
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)	$	1,674		$	1,674
Second Term Loan Due 2034 (in default)		768			768
Less: Accumulated amortization		(629	)		(565	)
	$	1,813		$	1,877

Accrued interest related to our long-term debt, net

	June 30,			December 31,
	2020			2019
	(in thousands)
Notre Dame Debt (in default)	$	4,037		$	3,639
USDA-Guaranteed Loans
First Term Loan Due 2034 (in default)		461			25
Second Term Loan Due 2034 (in default)		223			47
		4,721			3,711
Less: Accrued interest payable (in default)		(4,721	)		(3,711	)
Long-term Interest Payable, Net of Current Portion	$	-		$	-

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11. Line of Credit Payable (Tables)

6 Months Ended

Jun. 30, 2020

Line of Credit Facility [Abstract]

Line of credit agreement

Line of Credit Description	Principal Amount (in millions)	Maturity Date	Monthly Principal and Interest Payment	Interest Rate	Loan Purpose
Amended Pilot Line of Credit (in default)	$13.0	May 2020	----	14.00%	GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital

Line of credit

	June 30,			December 31,
	2020			2019
	(in thousands)
Amended Pilot Line of Credit (in default)	$	10,573		$	11,786
Less: Unamortized debt issue costs		-			(219	)
Less: Interest payable, short-term		(103	)		(103	)
	$	10,470		$	11,464

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12. AROs (Tables)

6 Months Ended

Jun. 30, 2020

Asset Retirement Obligation Disclosure [Abstract]

Asset retirement obligations

	June 30,			December 31,
	2020			2019
	(in thousands)
AROs, at the beginning of the period	$	2,565		$	2,565
Liabilities settled		(129	)		-
		2,436			2,565
Less: AROs, current portion		(2,436	)		(2,565	)
Long-term AROs, at the end of the period	$	-		$	-

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13. Leases (Tables)

6 Months Ended

Jun. 30, 2020

Leases [Abstract]

Schedule of leases

		June 30,			December 31,
	Balance Sheet Location	2020			2019
		(in thousands)
Assets
Operating lease ROU assets	Operating lease ROU assets	$	787		$	787
Less: Accumulated amortization on operating lease assets	Operating lease ROU assets		(211	)		(138	)
			576			649
Finance lease assets	Property and equipment, net		148			180
Less: Accumulated amortization on finance lease assets	Property and equipment, net		(10	)		(34	)
			138			146
Total lease assets			714			795
Liabilities
Current
Operating lease	Current portion of lease liabilities		185			175
Finance leases	Current portion of lease liabilities		128			76
			313			251
Noncurrent
Operating lease	Long-term lease liabilities, net of current		470			564
Total lease liabilities		$	783		$	815

Weighted average remaining lease term in years
Operating lease	3.17
Finance leases	0.68
Weighted average discount rate
Operating lease	8.25	%
Finance leases	8.25	%

Lease costs

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Operating lease costs	$	51	$	51	$	103	$	77
Finance lease costs:
Depreciation of leased assets		4		4		10		8
Interest on lease liabilities		2		1		3		2
Total lease cost	$	57	$	56	$	116	$	87

Supplemental cash flow information related to leases

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Cash paid for amounts included in the measurement
of lease liabilities:
Operating cash flows for operating lease	$	43	$	40	$	131	$	96
Operating cash flows for finance leases	$	2	$	1	$	4	$	2
Financing cash flows for finance leases	$	6	$	10	$	12	$	21

Maturities of operating lease liabilities

June 30,	Operating Lease		Financing Leases		Total
	(in thousands)
2020	$	184	$	128	$	312
2021		204		-		204
2022		226		-		226
2023		41		-		41
	$	655	$	128	$	783

Future minimum annual lease commitments

	Operating
June 30,	Lease
	(in thousands)
2020	$	232
2021		235
2022		239
2023		40
	$	746

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14. Income Taxes (Tables)

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Income tax benefit (expense)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Current
Federal	$	-		$	-		$	(15	)	$	-
State		-			-			-			-
Deferred
Federal		893			800			1,591			643
State		-						-
Change in valuation allowance		(893	)		(800	)		(1,591	)		(643	)
Total provision for income taxes	$	-		$	-		$	(15	)	$	-

Deferred tax assets and deferred tax liabilities

	June 30,			December 31,
	2020			2019
	(in thousands)
Deferred tax assets:
NOL and capital loss carryforwards	$	13,897		$	12,463
Business interest expense		2,648			1,923
Start-up costs (crude oil and condensate processing facility)		551			594
ARO liability/deferred revenue		511			539
AMT credit		-			50
Other		36			11
Total deferred tax assets		17,643			15,580
Deferred tax liabilities:
Basis differences in property and equipment		(6,705	)		(6,183	)
Total deferred tax liabilities		(6,705	)		(6,183	)
		10,938			9,397
Valuation allowance		(10,938	)		(9,347	)
Deferred tax assets, net	$	-		$	50

NOL carryforwards

	Net Operating Loss Carryforward
	Pre-Ownership Change		Post-Ownership Change		Total
	(in thousands)
Balance at December 31, 2018	$	9,614	$	37,335	$	46,949
Net operating losses		-		5,723		5,723
Balance at December 31, 2019		9,614	$	43,058		52,672
Net operating losses		-		6,826		6,826
Balance at June 30, 2020	$	9,614	$	49,884	$	59,498

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15. Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Earnings per share

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Net income (loss)	$	(4,242	)	$	(3,299	)	$	(7,582	)	$	(2,552	)
Basic and diluted income (loss) per share	$	(0.34	)	$	(0.30	)	$	(0.61	)	$	(0.23	)
Basic and Diluted
Weighted average number of shares of
common stock outstanding and potential
dilutive shares of common stock		12,580,853			10,975,514			12,454,109			10,975,215

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16. Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Amounts from the Lazarus Parties toward reducing the outstanding balance of the Final Arbitration Award

	(in millions)
Initial payment (September 2017)	$	3.7
GEL Interim Payments (July 2018 to April 2019)		8.0
Settlement Payment (Multiple Payments May 7 to 10, 2019)		10.0
Deferred Interim Installment Payments (June 2019 to August 2019)		0.5
	$	22.2

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1. Organization (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Net income (loss)	$ (4,242)	$ (3,299)	$ (7,582)	$ (2,552)
Net loss per common share	$ (0.34)	$ (0.30)	$ (0.61)	$ (0.23)
Working capital deficit	$ (6,240)		$ (6,240)		$ (5,940)

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2. Principles of Consolidation and Significant Accounting Policies (Details Narrative) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Allowance for doubtful accounts	$ 100	$ 100

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3. Related Party Transactions (Details)	6 Months Ended
	Jun. 30, 2020
Jonathan Carroll - LE
Type	Debt
Effective Date	4/1/2017
Interest rate	2.00%
Key Terms	Tied to payoff of LE $25 million Veritex loan; payments 50% cash, 50% Common Stock
Jonathan Carroll - LRM
Type	Debt
Effective Date	4/1/2017
Interest rate	2.00%
Key Terms	Tied to payoff of LRM $10 million Veritex loan; payments 50% cash, 50% Common Stock
LTRI LE
Type	Operations
Effective Date	7/1/2019
Interest rate	0.00%
Key Terms	LE purchase of two (2) refurbished heat exchangers for $0.08 million each
LMT - LE
Type	Operations
Effective Date	5/24/2016
Interest rate	0.00%
Key Terms	5-year term cancellable by either party any time; LE paid flat reservation fee for tolling volumes up to 84,000 gallons per day; excess tolling volumes subject to increased per gallon rate; terminated 07/01/2019
LEH - LE
Type	Operations
Effective Date	4/1/2020
Interest rate	0.00%
Key Terms	1-year term expiring earliest to occur of 03/31/2021 plus 30-day carryover or delivery of maximum jet fuel quantity; LEH bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification
Jonathan Carroll - Blue Dolphin
Type	Debt
Effective Date	3/31/2017
Interest rate	8.00%
Key Terms	Blue Dolphin working capital; matured 01/01/2019; interest still accruing
Ingleside - Blue Dolphin
Type	Debt
Effective Date	3/31/2017
Interest rate	8.00%
Key Terms	Blue Dolphin working capital; reflects amounts owed to Ingleside under previous Amended and Restated Tank Lease Agreement; matured 01/01/2019; interest still accruing
LEH - Blue Dolphin
Type	Debt
Effective Date	03/312017
Interest rate	8.00%
Key Terms	Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; reflects amounts owed to Jonathan Carroll under guaranty fee agreements; matured 01/01/2019; interest still accruing
LEH - BDSC
Type	Operations
Effective Date	1/1/2018
Interest rate	0.00%
Key Terms	68-month term expiring 08/31/2023; office lease Houston, Texas; includes 6-month rent abatement period; rent approximately $0.02 million per month
LEH - Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC
Type	Debt
Effective Date	4/1/2020
Interest rate	0.00%
Key Terms	3-year term; expires 04/01/2023 or notice by either party at any time of material breach or 90 days Board notice; LEH receives management fee of 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC
LEH - BDPL
Type	Debt
Effective Date	8/15/2016
Interest rate	16.00%
Key Terms	2-year term; $4.0 million principal amount; $0.5 million annual payment; proceeds used for working capital; no financial maintenance covenants; secured by certain BDPL property

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3. Related Party Transactions (Details 1) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Prepaid operating expenses, related party	$ 15,067	$ 8,175
Less: Long-term debt, related party, current portion, in default	(12,573)	(6,001)
Less: Interest payable, related party, in default	(2,494)	(2,174)
Long-term debt - net of current portion, related party	0	0
LEH
Prepaid operating expenses, related party	12,830	6,174
LEH | June LEH Note
Prepaid operating expenses, related party	6,336	0
LEH | BDPL Loan Agreement
Prepaid operating expenses, related party	6,494	6,174
Ingleside | March Ingleside Note
Prepaid operating expenses, related party	1,039	1,004
Jonathan Carroll | March Carroll Note
Prepaid operating expenses, related party	$ 1,198	$ 997

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3. Related Party Transactions (Details 2) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Tolling and terminaling revenues	$ 1,110	$ 1,088	$ 2,213	$ 2,157
Total revenues	$ 18,469	$ 78,345	$ 80,469	$ 147,272
Tolling and terminaling revenues, percent	6.00%	1.50%	2.80%	1.50%
Total revenues, percent	100.00%	100.00%	100.00%	100.00%
LEH
Refinery operations revenues	$ 4,587	$ 24,173	$ 22,302	$ 44,982
Refinery operations revenues, percent	24.80%	30.20%	27.70%	30.20%
Third Parties
Refinery operations revenues	$ 12,772	$ 53,084	$ 55,954	$ 100,133
Refinery operations revenues, percent	69.20%	68.30%	69.50%	68.30%

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3. Related Party Transactions (Details 3) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Sep. 30, 2019	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Interest expenses under loan and guarantee, related party		$ 464		$ 387	$ 845	$ 763
Jonathan Carroll | First Term Loan Due 2034
Interest expenses under loan and guarantee, related party		108		111	216	223
Jonathan Carroll | Second Term Loan Due 2034
Interest expenses under loan and guarantee, related party		44		46	89	92
Jonathan Carroll | March Carroll Note
Interest expenses under loan and guarantee, related party		20		28	43	53
LEH | BDPL Loan Agreement
Interest expenses under loan and guarantee, related party		160		160	320	320
LEH | June LEH Note
Interest expenses under loan and guarantee, related party		$ 117		$ 16	142	23
Ingleside | March Ingleside Note
Interest expenses under loan and guarantee, related party	$ 15		$ 26		$ 35	$ 52

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3. Related Party Transactions (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Related Party Transactions [Abstract]
Accounts receivable, related party	$ 0		$ 0		$ 1,364
Accounts payable, related party	149		149		$ 149
Dock Tolling Agreement with LMT fees	0	$ 200	0	$ 400
Lease payments received under the office sub-lease agreement with LEH	$ 100	$ 100	$ 200	$ 200

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4. Revenue and Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Net revenues (excluding intercompany fees and sales)	$ 18,469	$ 78,345	$ 80,469	$ 147,272
General and administrative expenses	531	579	1,175	1,249
Net income (loss)	(4,242)	(3,299)	(7,582)	(2,552)
Refinery Operations
Net revenues (excluding intercompany fees and sales)	17,359	77,257	78,256	145,115
Intercompany fees and sales	(406)	(653)	(1,023)	(1,259)
Operation costs and expenses	(19,418)	(78,376)	(81,251)	(143,528)
Segment contribution margin	(2,465)	(1,772)	(4,018)	328
General and administrative expenses	(327)	(274)	(631)	(606)
Depreciation and amortization	(294)	(483)	(582)	(948)
Interest and other non-operating income (expenses)	(751)	(823)	(1,492)	(1,606)
Income (loss) before income taxes	(3,837)	(3,352)	(6,723)	(2,832)
Capital expenditures			292	411
Identifiable assets			50,341	51,317
Tolling and Terminaling
Net revenues (excluding intercompany fees and sales)	1,110	1,088	2,213	2,157
Intercompany fees and sales	406	653	1,023	1,259
Operation costs and expenses	(258)	(363)	(513)	(727)
Segment contribution margin	1,258	1,378	2,723	2,689
General and administrative expenses	(68)	(62)	(136)	(105)
Depreciation and amortization	(324)	(99)	(618)	(198)
Interest and other non-operating income (expenses)	(616)	(579)	(1,386)	(775)
Income (loss) before income taxes	250	638	583	1,611
Capital expenditures			616	83
Identifiable assets			18,750	18,401
Corporate & Other
Net revenues (excluding intercompany fees and sales)	0	0	0	0
Intercompany fees and sales	0	0	0	0
Operation costs and expenses	(47)	(56)	(106)	(113)
Segment contribution margin	(47)	(56)	(106)	(113)
General and administrative expenses	(326)	(243)	(745)	(688)
Depreciation and amortization	(51)	(51)	(102)	(77)
Interest and other non-operating income (expenses)	(231)	(235)	(474)	(453)
Income (loss) before income taxes	(655)	(585)	(1,427)	(1,331)
Capital expenditures			0	0
Identifiable assets			1,848	1,726
Total
Net revenues (excluding intercompany fees and sales)	18,469	78,345	80,469	147,272
Intercompany fees and sales	0	0	0	0
Operation costs and expenses	(19,723)	(78,795)	(81,870)	(144,368)
Segment contribution margin	(1,254)	(450)	(1,401)	2,904
General and administrative expenses	(721)	(579)	(1,512)	(1,399)
Depreciation and amortization	(669)	(633)	(1,302)	(1,223)
Interest and other non-operating income (expenses)	(1,598)	(1,637)	(3,352)	(2,834)
Income (loss) before income taxes	(4,242)	(3,299)	(7,567)	(2,552)
Income tax expense	0	0	(15)	0
Net income (loss)	$ (4,242)	$ (3,299)	(7,582)	(2,552)
Capital expenditures			908	494
Identifiable assets			$ 70,939	$ 71,444

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5. Concentration of Risk (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Concentration of risk	100.00%	100.00%	100.00%	100.00%
4 Significant Customers
Concentration of risk	69.00%	97.00%	90.00%	97.00%
Portion of accounts receivable	$ 6	$ 600	$ 6	$ 600

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5. Concentration of Risk (Details 1) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Total refined petroleum product sales	$ 17,359	$ 77,257	$ 78,256	$ 145,115
Concentration Risk	100.00%	100.00%	100.00%	100.00%
LPG mix
Total refined petroleum product sales	$ 0	$ 1	$ 0	$ 9
Concentration Risk	0.00%	0.00%	0.00%	0.00%
Naphtha
Total refined petroleum product sales	$ 3,160	$ 15,416	$ 14,675	$ 29,211
Concentration Risk	18.20%	20.30%	18.80%	20.10%
Jet Fuel
Total refined petroleum product sales	$ 4,587	$ 24,173	$ 22,302	$ 44,982
Concentration Risk	26.40%	30.70%	28.50%	31.00%
HOBM
Total refined petroleum product sales	$ 3,691	$ 16,747	$ 18,882	$ 32,907
Concentration Risk	21.30%	23.80%	24.10%	22.70%
AGO
Total refined petroleum product sales	$ 5,921	$ 20,920	$ 22,397	$ 38,006
Concentration Risk	34.10%	25.20%	28.60%	26.20%

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5. Concentration of Risk (Details Narrative) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Risks and Uncertainties [Abstract]
Balances in excess of FDIC insurance limit	$ 300	$ 300

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6. Prepaid Expenses and Other Current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid insurance	$ 1,691	$ 417
Other prepaids	111	87
Prepaid easement renewal fees	110	121
Prepaid crude oil and condensate	0	1,651
Prepaid expenses, net	$ 1,912	$ 2,276

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7. Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Inventory Disclosure [Abstract]
HOBM	$ 2,833	$ 0
Crude oil and condensate	445	959
Chemicals	227	120
AGO	38	440
Propane	12	26
LPG mix	3	5
Naphtha	0	95
Inventories, net	$ 3,558	$ 1,645

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8. Property, Plant and Equipment, Net (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Refinery and facilities	$ 71,254	$ 66,317
Land	566	566
Other property and equipment	833	833
Property, Plant and Equipment, gross	72,653	67,716
Less: Accumulated depletion, depreciation and amortization	(13,938)	(12,739)
Property, plant and equipment, gross	58,715	54,977
Construction in progress	4,886	8,916
Property, plant and equipment, net	$ 63,601	$ 63,893

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8. Property, Plant and Equipment, Net (Details Narrative) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Interest cost capitalized	$ 0	$ 700

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9. Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Other Liabilities, Current [Abstract]
Insurance	$ 1,079	$ 159
Unearned revenue from contracts with customers	643	1,990
Unearned contract renewal income	500	500
Property, fuel and other taxes	331	183
Other payable	177	228
Board of director fees payable	35	263
Customer deposits	10	10
Accrued Expenses and Other Current Liabilities, Net	$ 2,775	$ 3,333

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10. Third-Party Long-Term Debt (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2020 USD ($)
First term loan due 2034
Original Principal Amount	$ 25,000
Maturity Date	June 2034
Interest rate	WSJ Prime + 2.75%
Second term loan due 2034
Original Principal Amount	$ 10,000
Maturity Date	December 2034
Interest rate	WSJ Prime + 2.75%
Notre Dame Debt
Original Principal Amount	$ 11,700
Maturity Date	January 2018
Interest rate	16.00%

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10. Third-Party Long-Term Debt (Details 1) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Principal balance outstanding	$ 40,146	$ 39,424
Less: Current portion of long-term debt, net	(33,612)	(33,836)
Less: Unamortized debt issue costs	(1,813)	(1,877)
Less: Accrued interest payable (in default)	(4,721)	(3,711)
Long term debt	0	0
First Term Loan Due 2034
Principal balance outstanding	22,006	21,776
Second Term Loan Due 2034
Principal balance outstanding	9,125	9,031
Notre Dame Debt
Principal balance outstanding	$ 9,015	$ 8,617

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10. Third-Party Long-Term Debt (Details 2) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Debt Disclosure [Abstract]
First Term Loan Due 2034	$ 1,674	$ 1,674
Second Term Loan Due 2034	768	768
Less: Accumulated amortization	(629)	(565)
Long term debt	$ 1,813	$ 1,877

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10. Third-Party Long-Term Debt (Details 3) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Debt Disclosure [Abstract]
Notre Dame Debt (in default)	$ 4,037	$ 3,639
First Term Loan Due 2034	461	25
Second Term Loan Due 2034	223	47
Total	4,721	3,711
Less: Interest payable, in default	(4,721)	(3,711)
Long term debt	$ 0	$ 0

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11. Line of Credit Payable (Details) - Amended Pilot Line Of Credit $ in Thousands	6 Months Ended
	Jun. 30, 2020 USD ($)
Principal amount	$ 13,000
Maturity date	May 2020
Interest rate	14.00%

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11. Line of Credit Payable (Details 1) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Line of credit, gross	$ 40,146	$ 39,424
Less: Unamortized debt issue costs	(1,813)	(1,877)
Less: Interest payable, short term	(4,721)	(3,711)
Pilot Line of Credit
Line of credit, gross	10,573	11,786
Less: Unamortized debt issue costs	0	(219)
Less: Interest payable, short term	(103)	(103)
Line of credit	$ 10,470	$ 11,464

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12. ARO'S (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations, at the beginning of the period	$ 2,565	$ 2,565
Liabilities settled	(129)	0
Asset retirement obligations	2,436	2,565
Less: asset retirement obligations, current portion	(2,436)	(2,565)
Long-term asset retirement obligations, at the end of the period	$ 0	$ 2,565

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13. Lease Obligations (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease right-of-use assets, gross	$ 787		$ 787
Less: Accumulated amortization on operating lease assets	(211)	$ (138)
Operating lease right-of-use assets, net	576		649
Finance lease assets, gross	148		180
Less: Accumulated amortization on finance lease assets	(10)	$ (34)
Finance lease assets, net	138		140
Total lease assets	714		795
Current portion of operating lease	185		175
Current portion of finance lease	128		76
Total current lease liability	313		251
Long-term portion of operating lease	470		564
Total lease liabilities	$ 783		$ 815
Weighted average remaining lease term in years - operating lease	3 years 2 months 1 day
Weighted average remaining lease term in years - finance lease	8 months 5 days
Weighted average discount rate - operating lease	8.25%
Weighted average discount rate - finance lease	8.25%

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13. Lease Obligations (Details 1) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Leases [Abstract]
Operating lease costs	$ 51	$ 51	$ 103	$ 77
Depreciation of leased assets	4	4	10	8
Interest on lease liabilities	2	1	3	2
Total lease cost	$ 57	$ 56	$ 116	$ 87

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13. Lease Obligations (Details 2) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Leases [Abstract]
Operating cash flows for operating lease	$ 43	$ 40	$ 131	$ 96
Operating cash flows for finance leases	2	1	4	2
Financing cash flows for finance leases	$ 6	$ 10	$ 12	$ 21

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13. Lease Obligations (Details 3) $ in Thousands	Jun. 30, 2020 USD ($)
Operating Lease
2020	$ 184
2021	204
2022	226
2023	41
Total minimum rental payments	655
Finance Lease
2020	128
2021	0
2022	0
2023	0
Total minimum rental payments	128
Total
2020	312
2021	204
2022	226
2023	41
Total minimum rental payments	$ 783

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13. Lease Obligations (Details 4) $ in Thousands	Jun. 30, 2020 USD ($)
Leases [Abstract]
2020	$ 232
2021	235
2022	239
2023	40
Total	$ 746

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14. Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Current federal	$ 0	$ 0	$ (15)	$ 0
Current state	0	0	0	0
Deferred federal	893	800	1,591	643
Deferred state	0	0	0	0
Change in valuation allowance	(893)	(800)	(1,591)	(643)
Total provision for income taxes	$ 0	$ 0	$ (15)	$ 0

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14. Income Taxes (Details 1) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Deferred tax assets:
Net operating loss and capital loss carryforwards	$ 13,897	$ 12,463
Business interest expense	2,648	1,923
Start-up costs (crude oil and condensate processing facility)	551	594
ARO liability/deferred revenue	511	539
AMT credit	0	50
Other	36	11
Total deferred tax assets	17,643	15,580
Deferred tax liabilities:
Basis differences in property and equipment	(6,705)	(6,183)
Total deferred tax liabilities	(6,705)	(6,183)
Deferred tax assets, net	10,938	9,397
Valuation allowance	(10,938)	(9,347)
Deferred tax assets, net	$ 0	$ 50

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14. Income Taxes (Details 2) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Beginning balance	$ 52,672	$ 46,949
Net operating losses	6,826	5,723
Ending balance	59,498	52,672
Pre-Ownership Change
Beginning balance	9,614	9,614
Net operating losses	0	0
Ending balance	9,614	9,614
Post-Ownership Change
Beginning balance	43,058	37,335
Net operating losses	6,826	5,723
Ending balance	$ 49,884	$ 43,058

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14. Income Taxes (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Income tax benefit	$ 0	$ 0	$ 15	$ 0

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15. Earnings per share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Net income (loss)	$ (4,242)	$ (3,299)	$ (7,582)	$ (2,552)
Basic and diluted income per share	$ (0.34)	$ (0.30)	$ (0.61)	$ (0.23)
Basic and diluted
Weighted average number of shares of common stock outstanding and potential dilutive shares of common stock	12,580,853	10,975,514	12,454,109	10,975,215

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16. Commitments and Contingencies (Details) $ in Thousands	Jun. 30, 2020 USD ($)
Amounts received to reduce the outstanding balance of the Final Arbitration Award	$ 22,200
Initial payment (September 2017)
Amounts received to reduce the outstanding balance of the Final Arbitration Award	3,700
Interim Payments (July 2018 to April 2019)
Amounts received to reduce the outstanding balance of the Final Arbitration Award	8,000
Settlement Payment (May 2019)
Amounts received to reduce the outstanding balance of the Final Arbitration Award	10,000
Deferred Interim Installment Payments (June 2019 to July 2019)
Amounts received to reduce the outstanding balance of the Final Arbitration Award	$ 500