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 March 31, 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 May 15, 2020: 12,693,514
 
 
 
 
1
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
 
 
TABLE OF CONTENTS
 
PART I.

6
 
 
 
ITEM 1. 
FINANCIAL STATEMENTS
6
 
Consolidated Balance Sheets (Unaudited)
6
 
Consolidated Statements of Operations (Unaudited)
7
 
Consolidated Statements of Cash Flows (Unaudited)
8
 
Notes to Consolidated Financial Statements
9
ITEM 2. 
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
37
ITEM 3. 
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
49
ITEM 4.
CONTROLS AND PROCEDURES
49
 
 
 
PART II.

50
 
 
 
ITEM 1. 
LEGAL PROCEEDINGS
50
ITEM 1A. 
RISK FACTORS
50
ITEM 2. 
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
50
ITEM 3. 
DEFAULTS UPON SENIOR SECURITIES
50
ITEM 4. 
MINE SAFETY DISCLOSURES
51
ITEM 5. 
OTHER INFORMATION
51
ITEM 6. 
EXHIBITS
51
 
 
 
SIGNATURES  
52
 
 
2
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
 
 
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; line of credit amount is $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 the 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.)
 
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. A hydrocarbon-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.
 
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.
 
 
 
3
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
 
  
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.
 
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.
 
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.
 
SEC. Securities and Exchange Commission.
 
 
5
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
 
 
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.
 
 
 
6
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
  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
 
Refinery and Tolling and Terminaling Operations
 
●
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, 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 recent 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.
 

 
●
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 recent 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 failure to satisfy orders to provide additional financial assurance (supplemental pipeline bonds) within the time period prescribed.
●
Assessment of civil penalties by BSEE for 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 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.
 
 
7
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Financial Statements
 
PART I
 
ITEM 1.  FINANCIAL STATEMENTS
 
Consolidated Balance Sheets (Unaudited)
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
 
 
 
 
 
 
 
(in thousands except share amounts)
 
 
 
 
 
 
 
 
 ASSETS
 
 
 
 
 
 
 CURRENT ASSETS
 
 
 
 
 
 
 Cash and cash equivalents
 $269 
 $72 
 Restricted cash
  49 
  49 
 Accounts receivable, net
  1,325 
  446 
 Accounts receivable, related party (Note 3)
  - 
  1,364 
 Prepaid expenses and other current assets (Note 6)
  780 
  2,276 
 Deposits
  174 
  158 
 Inventory (Note 7)
  813 
  1,645 
 Refundable federal income tax (Note 14)
  100 
  65 
 Total current assets
  3,510 
  6,075 
 
    
    
 LONG-TERM ASSETS
    
    
 Total property and equipment, net (Note 8)
  63,509 
  63,893 
 Operating lease ROU assets (Note 13)
  613 
  649 
 Restricted cash, noncurrent
  547 
  547 
 Surety bonds (Note 16)
  230 
  230 
 Deferred tax assets, net (Note 14) 
  - 
  50 
 Total long-term assets
  64,899 
  65,369 
 
    
    
 TOTAL ASSETS
  68,409 
  71,444 
 
    
    
 LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
    
    
 CURRENT LIABILITIES
    
    
 Long-term debt less unamortized debt issue costs, current portion, in default (Note 10)
  33,580 
  33,836 
 Line of credit payable, less umamortized debt issue costs (Note 11)
  11,243 
  11,464 
 Long-term debt, related party, current portion, in default (Note 3)
  7,572 
  6,001 
 Current portion of lease liabilities (Note 13)
  250 
  251 
 Interest payable (in default) (Note 10)
  4,033 
  3,814 
 Interest payable, related party (in default) (Note 3)
  2,334 
  2,174 
 Accounts payable
  1,425 
  1,877 
 Accounts payable, related party (Note 3)
  149 
  149 
 Asset retirement obligations (Note 12)
  2,550 
  2,565 
 Accrued expenses and other current liabilities (Note 9)
  2,801 
  3,333 
 Total current liabilities
  65,937 
  65,464 
 
    
    
 LONG-TERM LIABILITIES
    
    
 Long-term lease liabilities, net of current portion (Note 13)
  518 
  564 
 Deferred revenue
  1,808 
  1,930 
 Total long-term liabilities
  2,326 
  2,494 
 
    
    
 TOTAL LIABILITIES
  68,263 
  67,958 
 
    
    
 Commitments and contingencies (Note 16)
    
    
 
    
    
 STOCKHOLDERS' EQUITY
    
    
 Common Stock shares issued and outstanding (12,327,365 at both March 31, 2020 and December 31, 2019)
  123 
  123 
 Additional paid-in capital
  38,275 
  38,275 
 Accumulated deficit
  (38,252)
  (34,912)
 TOTAL STOCKHOLDERS' EQUITY
  146 
  3,486 
 
    
    
 TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
 $68,409 
 $71,444 
 
The accompanying notes are an integral part of these consolidated financial statements. 
 
 
8
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Financial Statements
 
Consolidated Statements of Operations (Unaudited)
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
 
 
 
 
 
 
 
 
(in thousands except share and per-share amounts)
 
 
 
 
 
 
 
 
 REVENUE FROM OPERATIONS
 
 
 
 
 
 
 Refinery operations (Note 4)
 $60,897 
 $67,858 
 Tolling and terminaling (Note 4)
  1,103 
  1,069 
 Total revenue from operations
  62,000 
  68,927 
 
    
    
 COST OF GOODS SOLD
    
    
 Crude oil, fuel use, and chemicals
  59,720 
  63,187 
 Other conversion costs
  2,368 
  2,329 
 Total costs of goods sold
  62,088 
  65,516 
 
    
    
 Gross profit (deficit)
  (88)
  3,411 
 
    
    
 COST OF OPERATIONS
    
    
 LEH operating fee (Note 3)
  147 
  150 
 Other operating expenses
  59 
  57 
 General and administrative expenses
  644 
  670 
 Depletion, depreciation and amortization
  633 
  590 
 Total cost of operations
  1,483 
  1,467 
 
    
    
 Income (loss) from operations
  (1,571)
  1,944 
 
    
    
 OTHER INCOME (EXPENSE)
    
    
 
    
    
 Easement, interest and other income
  20 
  - 
 Interest and other expense
  (1,774)
  (1,197)
 Total other income (expense) (Note 3)
  (1,754)
  (1,197)
 
    
    
 Income (loss) before income taxes
  (3,325)
  747 
 
    
    
 Income tax expense
  (15)
  - 
 
    
    
 Net income (loss)
 $(3,340)
 $747 
 
    
    
 
    
    
 Income (loss) per common share (Note 15):
    
    
 Basic
 $(0.27)
 $0.07 
 Diluted
 $(0.27)
 $0.07 
 
    
    
 Weighted average number of common shares outstanding (Note 15):
  12,327,365 
  10,975,514 
 Basic
  12,327,365 
  10,975,514 
 Diluted
    
    
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
9
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Financial Statements
 
Consolidated Statements of Cash Flows (Unaudited)
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
(in thousands)
OPERATING ACTIVITIES
 
 
 
 
 
 
Cash flows used in operating activities:
 
 
 
 
 
 
Net income (loss)
 $(3,340)
 $747 
Adjustments to reconcile net income (loss) to net cash from operating activities:
    
    
Depletion, depreciation and amortization
  633 
  590 
Deferred income tax
  15 
  - 
Amortization of debt issue costs
  220 
  32 
Guaranty fees paid in kind
  153 
  - 
Deferred revenues and expenses
  (122)
  - 
Changes in operating assets and liabilities
    
    
Changes in accounts receivable
  (879)
  (739)
Changes in accounts receivable, related party
  1,364 
  (482)
Changes in prepaid expenses and other current assets
  1,496 
  910 
Changes in deposits and other assets
  (16)
  - 
Changes in inventory
  832 
  (333)
Changes in accrued arbitration award
  - 
  (1,500)
Changes in accounts payable, accrued expenses and other liabilities
  (683)
  593 
Changes in accounts payable, related party
  - 
  151 
Net cash used in operating activities
  (327)
  (31)
 
    
    
INVESTING ACTIVITIES
    
    
Cash flows from (used in) investing activities:
    
    
Capital expenditures
  (198)
  (123)
Net cash used in investing activities
  (198)
  (123)
 
    
    
FINANCING ACTIVITIES
    
    
Cash flows from (used in) financing activities:
    
    
Payments on debt
  (696)
  (250)
Net activity on related-party debt
  1,418 
  419 
Net cash provided by financing activities
  722 
  169 
 
    
    
Increase in cash and cash equivalents
  197 
  15 
 
    
    
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD
  668 
  1,665 
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD
 $865 
 $1,680 
 
    
    
Supplemental Information:
    
    
Non-cash investing and financing activities:
    
    
Financing of guaranty fees via long-term debt, related party
 $153 
 $158 
Interest paid
 $937 
 $361 
Income taxes paid (received)
 $- 
 $- 
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
10
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 approximately 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 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 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 a stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and obligors were still in default under our other secured loan agreements with Veritex.
 
At March 31, 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 March 31, 2020 and December 31, 2019. We were current on required monthly payments under our secured loan agreements with Veritex as of the filing date of this report.
 
 
11
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, all amounts outstanding under the Amended Pilot Line of Credit 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.
 
The borrower and guarantors are attempting to reach a negotiated settlement with Pilot, and Pilot hopes to continue to work with the borrower to settle its obligations under the Amended Pilot Line of Credit. Additionally, the borrower and guarantors are working with a lender on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. 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 were 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 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 during the second quarter 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 loss for the three months ended March 31, 2020 was $3.3 million, or a loss of $0.27 per share, compared to net income of $0.7 million, or income of $0.07 per share, for the three months ended March 31, 2019. The significant decrease was the result of less favorable margins per bbl.
 
We had a working capital deficit of $62.4 million and $59.4 million at March 31, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $21.3 million and $19.6 million at March 31, 2020 and December 31, 2019, respectively. We had cash and cash equivalents and restricted cash (current portion) of $0.3 million and $0.05 million, respectively, at March 31, 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’ above 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.
 
 
12
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(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 months ended March 31, 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)” under ‘use of estimates,’ the recent outbreak of COVID-19 and its development into a pandemic in March 2020 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 months ended March 31, 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 outbreak of COVID-19 and its development into a pandemic in March 2020 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. Many uncertainties remain with respect to COVID-19, including its resulting economic effects, and we are unable to predict the ultimate economic impacts from COVID-19 on our business and how quickly national economies can recover once the pandemic subsidies. However, the adverse impacts of the economic effects from COVID-19 and uncertainty in the global oil markets on our business have been and will likely continue to be significant.
 
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 COVID-19 outbreak has impacted these estimates and assumptions and will continue to do so. Our estimates at the end of the first quarter assumed no material impact from the disruptions caused by COVID-19.
 
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 March 31, 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. While there was not a material impact to our consolidated financial statements as of and for the three months ended March 31, 2020, our future assessment of the magnitude and duration of COVID-19, as well as other factors, could result in material impacts to our consolidated financial statements in future reporting periods.
 
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 March 31, 2020 and December 31, 2019.
 
 
13
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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 that 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.
 
 
14
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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 March 31, 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 March 31, 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 March 31, 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 that testing, no impairment was deemed necessary 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.
 
 
15
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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.
 
 
16
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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
03/312017
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.
 
 
17
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 March 31, 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 paid 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 March 31, 20020 and December 31, 2019.
 
Long-term debt, related party, current portion (in default) and accrued interest payable, related party.
 
 
 
March 31,
 
 
December 31,
 
 
 
2020  
 
 
2019  
 
 
 
(in thousands)
 
LEH
 
 
 
 
 
 
June LEH Note (in default)
 $1,375 
 $- 
BDPL Loan Agreement
  6,334 
  6,174 
LEH Total
  7,709 
  6,174 
Ingleside
    
    
March Ingleside Note (in default)
  1,024 
  1,004 
Jonathan Carroll
    
    
March Carroll Note (in default)
  1,173 
  997 
 
  9,906 
  8,175 
 
    
    
Less: Long-term debt, related party, current portion, in default
  (7,572)
  (6,001)
Less: Accrued interest payable, related party (in default)
  (2,334)
  (2,174)
 
 $- 
 $- 
 
 
18
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
Consolidated Statements of Operations.
 
Total revenue from operations.
 
 
 
Three Months Ended March 31,
 
 
 
2020    
 
 
2019    
 
 
 
(in thousands, except percent amounts)
 
Refinery operations
 
   
 
 
 
 
 
 
 
 
 
 
LEH
 $17,715 
  28.6%
 $20,809 
  30.2%
Third-Parties
  43,182 
  69.6%
  47,049 
  68.3%
Tolling and terminaling
    
    
    
    
Third-Parties
  1,103 
  1.8%
  1,069 
  1.5%
 
 $62,000 
  100.0%
 $68,927 
  100.0%
 
Interest expense.
 
 
 
Three Months Ended March 31,
 
 
 
2020  
 
 
2019  
 
 
 
  (in thousands)
 
Jonathan Carroll
 
   
 
 
   
 
Guaranty Fee Agreements
 
   
 
 
   
 
First Term Loan Due 2034
 $108 
 $112 
Second Term Loan Due 2034
  45 
  46 
March Carroll Note (in default)
  23 
  25 
LEH
    
    
BDPL Loan Agreement (in default)
  160 
  160 
June LEH Note (in default)
  25 
  6 
Ingleside
    
    
March Ingleside Note (in default)
  20 
  26 
 
 $381 
 $375 
 
 
19
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 March 31, 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 March 31, 2020 and 2019. The LEH operating fee was flat, totaling approximately $0.2 million for both three-month periods ended March 31, 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
 
 
 
20
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 March 31,
 
 
 
2020
 
 
2019
 
 
(in thousands)
Net revenue (excluding intercompany fees and sales)
 
 
 
 
 
 
Refinery operations
 $60,897 
 $67,858 
Tolling and terminaling
  1,103 
  1,069 
Total net revenue
  62,000 
  68,927 
 
    
    
Intercompany fees and sales
    
    
Refinery operations
  (617)
  (606)
Tolling and terminaling
  617 
  606 
Total intercompany fees
  - 
  - 
 
    
    
Operation costs and expenses(1)
    
    
Refinery operations
  (61,833)
  (65,152)
Tolling and terminaling
  (255)
  (364)
Corporate and other
  (59)
  (57)
Total operation costs and expenses
  (62,147)
  (65,573)
 
    
    
Segment contribution margin (deficit)
    
    
Refinery operations
  (1,553)
  2,100 
Tolling and terminaling
  1,465 
  1,311 
Corporate and other
  (59)
  (57)
Total segment contribution margin (deficit)
  (147)
  3,354 
 
    
    
General and administrative expenses(2)
    
    
Refinery operations
  (304)
  (332)
Tolling and terminaling
  (68)
  (43)
Corporate and other
  (419)
  (445)
Total general and administrative expenses
  (791)
  (820)
 
    
    
Depreciation and amortization
    
    
Refinery operations
  (288)
  (465)
Tolling and terminaling
  (294)
  (99)
Corporate and other
  (51)
  (26)
Total depreciation and amortization
  (633)
  (590)
 
    
    
Interest and other non-operating expenses, net
    
    
Refinery operations
  (741)
  (783)
Tolling and terminaling
  (770)
  (196)
Corporate and other
  (243)
  (218)
Total interest and other non-operating expenses, net
  (1,754) 
  (1,197)
 
    
    
Income (loss) before income taxes
    
    
Refinery operations
  (2,886)
  520 
Tolling and terminaling
  333 
  973 
Corporate and other
  (772)
  (746)
Total income (loss) before income taxes
  (3,325)
  747 
 
    
    
Income tax expense
  (15)
  - 
 
    
    
Net income (loss)
 $(3,340)
 $747 
 
(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.
 
 
21
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
 
 
March 31,    
 
 
 
2020
 
 
2019
 
 
 
 (in thousands)
 
Capital expenditures
 
 
 
 
 
 
Refinery operations
 $6 
 $40 
Tolling and terminaling
  192 
  83 
Corporate and other
  - 
  - 
Total capital expenditures
  198 
  123 
 
    
    
Identifiable assets
    
    
Refinery operations
  48,418 
  50,340 
Tolling and terminaling
  18,407 
  18,880 
Corporate and other
  1,584 
  2,429 
Total identifiable assets
 $68,409 
 $71,649 
 
(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 March 31, 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. Pilot may terminate the crude supply agreement by providing the other party 60 days prior written notice. We may terminate the agreement upon the expiration of the initial term or at any time during a renewal term by giving Pilot 60 days prior written notice.
 
Pilot also stores crude oil at the Nixon facility under a terminal services agreement. 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.
 
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.
 
 
22
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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 March 31
 
 
 
 
 
 
 
 
Three Months March 31, 2020
  4 
94%
$0.6 million
 
    
       
 
Three Months March 31, 2019
  4 
96%
$0.8 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 29% and 30% of our total revenue from operations for the three months ended March 31, 2020 and 2019, respectively. LEH represented $0 in accounts receivable at both March 31, 2020 and March 31, 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 paid under normal business terms. The total amount owed to LEH under the June LEH Note and the BDPL Loan Agreement totaled $7.6 million and $6.2 million at March 31, 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.
 
 
23
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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:
 
 
 
Year Ended March 31,      
 
 
 
2020    
 
 
2019    
 
 
 
(in thousands, except percent amounts)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
LPG mix
 $- 
  0.0%
 $8 
  0%
Naphtha
  11,515 
  18.9%
  13,795 
  20.3%
Jet fuel
  17,715 
  29.1%
  20,809 
  30.7%
HOBM
  15,191 
  24.9%
  16,160 
  23.8%
AGO
  16,476 
  27.1%
  17,086 
  25.2%
 
 $60,897 
  100.0%
 $67,858 
  100.0%
 
An Affiliate, LEH, purchases 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:
 
 
 
  March 31,
 
 
December 31,
 
 
 
2020  
 
 
 2019
 
 
 
  (in thousands)
 
Prepaid crude oil and condensate
 $379 
 $1,651 
Other prepaids
  191 
  87 
Prepaid easement renewal fees
  115 
  121 
Prepaid insurance
  95 
  417 
 
 $780 
 $2,276 
 
 
24
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(7)
Inventory
 
Inventory as of the dates indicated consisted of the following:
 
 
 
  March 31,
 
 
  December 31,
 
 
 
2020  
 
 
2019  
 
 
 
  (in thousands)      
 
Crude oil and condensate
 $554 
 $959 
Chemicals
  157 
  120 
AGO
  56 
  440 
Naphtha
  29 
  95 
Propane
  15 
  26 
LPG mix
  2 
  5 
 
 $813 
 $1,645 
 
At March 31, 2020 and December 31, 2019, we recorded a write-down of inventory to its net realizable value of approximately $0.2 million and $0.1 million, respectively.
 
 
25
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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:
 
 
 
  March 31,
 
 
  December 31,
 
 
 
2020    
 
 
2019  
 
 
 
  (in thousands)
 
Refinery and facilities
 $66,317 
 $66,317 
Land
  566 
  566 
Other property and equipment
  833 
  833 
 
  67,716 
  67,716 
 
    
    
  Less: Accumulated depletion, depreciation, and amortiation
  (13,321)
  (12,739)

  54,395 
  54,977 
 
    
    
CIP
  9,114 
  8,916 
 
 $63,509 
 $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 $0.7 million at both March 31, 2020 and December 31, 2019. Capital expenditures for expansion at the Nixon facility are funded by long-term debt from Veritex, revenue from operations, and working capital from Affiliates. Unused amounts for capital expenditures derived from 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 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:
 
 
 
  March 31,
 
 
  December 31,
 
 
 
2020    
 
 
2019  
 
 
 
  (in thousands)
 
Unearned revenue from contracts with customers
 $1,697 
 $1,990 
Unearned contract renewal income
  500 
  500 
Taxes payable
  252 
  183 
Insurance
  169 
  159 
Board of director fees payable
  123 
  263 
Other payable
  50 
  228 
Customer deposits
  10 
  10 
 
 $2,801 
 $3,333 
 
 
 
 
 
 
 
 
 
Remainder of Page Intentionally Left Blank
 
 
26
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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; reduce 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.
 
 
27
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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 March 31, 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 a stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and obligors were still in default under our other secured loan agreements with Veritex.
 
Financial Covenant Violations.  At March 31, 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.
 
 
28
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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:
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
USDA-Guaranteed Loans
 
 
 
 
 
 
First Term Loan Due 2034 (in default)
 $21,586 
 $21,776 
Second Term Loan Due 2034 (in default)
  8,953 
  9,031 
Notre Dame Debt (in default)
  8,816 
  8,617 
 
  39,355 
  39,424 
 
    
    
Less: Current portion of long-term debt, net
  (33,580)
  (33,836)
Less: Unamortized debt issue costs
  (1,845)
  (1,877)
Less: Accrued interest payable (in default)
  (3,930)
  (3,711)
 
 $- 
 $- 
 
Unamortized debt issue costs associated with USDA-guaranteed loans as of the dates indicated consisted of the following:
 
 
 
March 31,
 
 
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
  (597)
  (565)
 
 $1,845 
 $1,877 
 
Amortization expense was $0.03 million for both three-month periods ended March 31, 2020 and 2019.
 
 
29
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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:
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
Notre Dame Debt (in default)
 $3,838 
 $3,639 
USDA-Guaranteed Loans
    
    
First Term Loan Due 2034 (in default)
  41 
  25 
Second Term Loan Due 2034 (in default)
  51 
  47 
 
  3,930 
  3,711 
Less: Accrued interest payable (in default)
  (3,930)
  (3,711)
Long-term Interest Payable, Net of Current Portion
 $- 
 $- 
 
As a result of new ASU guidance related to leases, capital leases are now reported in “Note (13)” as finance leases. See “Note (1),” “Note (3),” and “Note (11”) to our consolidated financial statements for information related to third-party debt, related-party debt and debt obligations associated with Pilot.
 
(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 unpaid principal amount and all interest accrued and unpaid, and all other amounts owing or payable under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, all amounts outstanding under the Amended Pilot Line of Credit 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.
 
The borrower and guarantors are attempting to reach a negotiated settlement with Pilot, and Pilot hopes to continue to work with the borrower to settle its obligations under the Amended Pilot Line of Credit. Additionally, the borrower and guarantors are working with a lender on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. 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 were 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.
 
 
30
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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.
 
Line of credit payable, which represents outstanding principal and accrued interest, as of the dates indicated was as follows:
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
 
 
 
 
 
 
 
Amended Pilot Line of Credit (in default)
 $11,378 
 $11,786 
 
    
    
Less: Unamortized debt issue costs
  (32)
  (219)
Less: Interest payable, short-term
  (103)
  (103)
 
 $11,243 
 $11,464 
 
 
31
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(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 dismantlement and abandonment in place 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 March 31, 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:
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
 
 
 
 
 
 
 
AROs, at the beginning of the period
 $2,565 
 $2,565 
Libilities settled
  (15)
  - 
 
  2,550 
  2,565 
Less: AROs, current portion
  (2,550)
  (2,565)
Long-term AROs, at the end of the period
 $- 
 $- 
 
 
32
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(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 March 31, 2020 and 2019. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.
 
Finance Lease
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 following table presents the lease-related assets and liabilities recorded on the consolidated balance sheet:
 
 
 
 
March 31,
 
 
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
  (174)
  (138)
 
  613 
  649 
 
    
    
Finance lease assets
 Property and equipment, net
  180 
  180 
Less: Accumulated amortization on finance lease assets
 Property and equipment, net
  (40)
  (34)
 
  140 
  146 
 
    
    
Total lease assets
 
  753 
  795 
 
    
    
Liabilities
 
    
    
Current
 
    
    
Operating lease
 Current portion of lease liabilities
  180 
  175 
Finance leases
 Current portion of lease liabilities
  70 
  76 
 
  250 
  251 
Noncurrent
 
    
    
Operating lease
 Long-term lease liabilities, net of current
  518 
  564 
Total lease liabilities
 
 $768 
 $815 
 
 
 
33
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
Weighted average remaining lease term in years
Operating lease
  3.42 
Finance leases
  0.17 
Weighted average discount rate
    
Operating lease
  8.25%
Finance leases
  8.25%
 
 
34
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
The following table presents information related to lease costs for operating and finance leases:
 
 
 
Three Months Ended
 
 
 
March 31,  
 
 
 
2020
 
 
2019
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Operating lease costs
 $51 
 $51 
Finance lease costs:
    
    
Depreciation of leased assets
  6 
  4 
Interest on lease liabilities
  2 
  1 
Total lease cost
 $59 
 $56 
 
The table below presents supplemental cash flow information related to leases as follows:
 
 
 
  Three Months Ended
 
 
 
  March 31,    
 
 
 
2020 
 
 
2019 
 
Cash paid for amounts included in the measurement of lease liabilities:
 
   
 
 
   
 
Operating cash flows for operating lease
 $88 
 $57 
Operating cash flows for finance leases
 $2 
 $1 
Financing cash flows for finance leases
 $6 
 $9 
 
 
 
35
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
As of March 31, 2020, maturities of lease liabilities for the periods indicated were as follows:
 
March 31,
 
Operating Lease
 
 
Financing Leases
 
 
Total
 
 
 
 (in thousands)  
 
 
 
 
 
 
   
 
 
   
 
 
 
 
2020
 $180 
 $70 
 $250 
2021
  199 
  - 
  199 
2022
  220 
  - 
  220 
2023
  99 
  - 
  99 
 
    
    
    
 
 $698 
 $70 
 $768 
 
Future minimum annual lease commitments that are non-cancelable:
 
 
 
Operating
 
March 31,
 
 Lease
 
 
 
 (in thousands)
 
2020
 $231 
2021
  234 
2022
  238 
2023
  101 
 
 $804 
 
 
36
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(14)
Income Taxes
 
Tax Provision
The provision for income tax benefit (expense) for the periods indicated was as follows:
 
 
 
Year Ended March 31,
 
Current
 
 
 
 
 
 
Federal
 $(15)
 $- 
State
  - 
  - 
Deferred
    
    
Federal
  698 
  (157)
State
  - 
    
Change in valuation allowance
  (698 )
  157  
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:
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
Deferred tax assets:
 
 
 
 
 
 
NOL and capital loss carryforwards
 $13,057 
 $12,463 
Business interest expense
  2,295 
  1,923 
Start-up costs (crude oil and condensate processing facility)
  573 
  594 
ARO liability/deferred revenue
  535 
  539 
AMT credit
  - 
  50 
Other
  5 
  11 
Total deferred tax assets
  16,465 
  15,580 
 
    
    
Deferred tax liabilities:
    
    
Basis differences in property and equipment
  (6,422)
  (6,183)
Total deferred tax liabilities
  (6,422)
  (6,183)
 
  10,043 
  9,397 
 
    
    
Valuation allowance
  (10,043)
  (9,347)
 
    
    
Deferred tax assets, net
 $- 
 $50 
 
 
37
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
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
  - 
  2,829 
  2,829 
 
    
    
    
Balance at March 31, 2020
 $9,614 
 $45,887 
 $55,501 
 
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 March 31, 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 March 31, 2020 and December 31, 2019.
 
 
38
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
(15)
Earnings Per Share
A reconciliation between basic and diluted income per share for the periods indicated was as follows:
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands, except share and per share amounts)
 
 
 
 
 
 
 
 
Net income (loss)
 $(3,340)
 $747 
 
    
    
Basic and diluted income (loss) per share
 $(0.27)
 $0.07 
 
    
    
Basic and Diluted
    
    
Weighted average number of shares of common stock outstanding and potential dilutive shares of common stock dilutive shares of common stock
  12,327,365 
  10,975,514 
 
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 months ended March 31, 2020 and 2019 was the same as basic EPS as there were no stock options or other dilutive instruments outstanding.
 
(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.
 
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.
 
 
39
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
Legal Matters
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 a 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 March 31, 2020 and December 31, 2019, the accrued arbitration award payable was $0.
 
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 the August 15, 2019 meeting may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (discussed within this “Note (16)” under ‘BSEE Offshore Pipelines and Platform Decommissioning’) prior to BSEE’s August 2020 deadline will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs.
 
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 March 31, 2020. At March 31, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.
 
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.
 
 
40
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Notes to Consolidated Financial Statements
 
Nixon Facility Expansion
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, installation of new and/or refurbished refinery process equipment, and completion of a petroleum storage tank.
 
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 BOEM and 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. In April 2020, BSEE issued an 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. Completion of the platform surveys are required by May 30, 2020 with associated reports due to BSEE by June 8, 2020. BDPL expects to complete approved, permitted decommissioning work by the BSEE August 2020 deadline.
 
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 March 31, 2020. As of March 31, 2020, we maintained $2.6 million in AROs related to abandonment of these assets.
 
(17)
Subsequent Events
 
Sales of Unregistered Securities
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 and subsequent to the three months ended March 31, 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.
 
Amended and Restated Operating Agreement
The Amended and Restated Operating Agreement was set to expire on April 1, 2020. However, the Amended and Restated Operating Agreement was renewed and approved by the Board on May 14, 2020 with an effective date of April 1, 2020. Key terms of the Amended and Restated Operating Agreement follow:
 
Term. The term begins on the effective date and expires upon the earliest to occur of the following: (a) upon the third anniversary of the effective date, which termination date shall be April 1, 2023, (b) upon written notice of either party upon the material breach of the agreement by the other party, or (c) upon 90 days’ notice by the Board if the Board determines that the Amended and Restated Operating Agreement is not in the best interest of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and/or BDSC.
 
Compensation. For services rendered: (a) Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC shall reimburse LEH at cost for all direct expenses, either paid directly by LEH or financed with LEH’s credit card. Amounts payable to LEH shall be invoiced by LEH weekly, but may be reimbursed sooner and (b) Blue Dolphin shall also pay to LEH a management fee equal to 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest.
 
The foregoing summarizes the material terms of the Amended and Restated Operating Agreement. This summary does not purport to be complete and is qualified in its entirety by reference to the full text of the agreement, which is filed as Exhibit 10.1 to this report.
 
Together, Jonathan Carroll and LEH own approximately 82% of Blue Dolphin’s Common Stock.
 
See “Note (3)” of our consolidated financial statements and “Part II, Item 5. Other Information” for additional disclosures related to Affiliate transactions, including the Amended and Restated Operating Agreement.
 
 
41
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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.  
 
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 approximately 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 recent outbreak of COVID-19 and its development into a pandemic in March 2020 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 that has restricted travel, public gatherings, and the overall level of individual movement and in-person interaction across the globe. This has, in turn, significantly reduced global economic activity and negatively impacted many businesses. Airlines have dramatically reduced flights and motor vehicle usage has significantly declined at a time when seasonal driving patterns typically result in an increase of consumer demand for certain refined petroleum products.
 
As a result of the COVID-19 pandemic, there has also been 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 have not declined despite lower demand and storage capacity constraints for crude oil and refined products, which has intensified the decline in crude oil prices and has 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 has resulted in a significant decrease in the price of refined petroleum products. The purchase price of crude oil and the selling price of refined products impact 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.
 
Many uncertainties remain with respect to COVID-19, including its resulting economic effects, and we are unable to predict the ultimate economic impacts from COVID-19 on our business and how quickly national economies can recover once the pandemic subsides. However, the adverse impact of the economic effects on us have been and will likely continue to be significant. We believe we have proactively addressed many of the known impacts of COVID-19 to the extent possible and we will strive to continue to do so, but there can be no assurance that these or other measures will be fully effective.
 
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 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.
 
 
42
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 a stipulation of dismissal of claims against LE. As of the date of this report, LE had not replenished the payment reserve account and obligors were still in default under our other secured loan agreements with Veritex.
 
At March 31, 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 March 31, 2020 and December 31, 2019. We were current on required monthly payments under our secured loan agreements with Veritex as of the filing date of this report.
 
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 under the Amended Pilot Line of Credit. Pursuant to the Amended Pilot Line of Credit, commencing on May 4, 2020, all amounts outstanding under the Amended Pilot Line of Credit 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.
 
The borrower and guarantors are attempting to reach a negotiated settlement with Pilot, and Pilot hopes to continue to work with the borrower to settle its obligations under the Amended Pilot Line of Credit. Additionally, the borrower and guarantors are working with a lender on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. 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 were 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.
 
 
43
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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 during the second quarter 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 loss for the three months ended March 31, 2020 was $3.3 million, or a loss of $0.27 per share, compared to net income of $0.7 million, or income of $0.07 per share, for the three months ended March 31, 2019. The significant decrease was the result of less favorable margins per bbl.
 
We had a working capital deficit of $62.4 million and $59.4 million at March 31, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $21.3 million and $19.6 million at March 31, 2020 and December 31, 2019, respectively. We had cash and cash equivalents and restricted cash (current portion) of $0.3 million and $0.05 million, respectively, at March 31, 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’ above 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.
 
Business Strategy
Our primary business objective is to improve our financial profile. However, as discussed above under ‘going concern’ and ‘operating risks,’ many uncertainties remain with respect to COVID-19 and the global oil markets, and it is difficult to accurately forecast and plan future business activities. We are executing the following strategies, modified as necessary, to reflect current economic and market conditions and other circumstances:
 
 
 
 
Optimizing Existing Asset Base
 
● Operating safely and enhancing health, safety and environmental systems.
● Planning and managing turnarounds and downtime.
 
 
 
 
 
 
Improving Operational Efficiencies
 
● Reducing or streamlining variable costs incurred in production.
● Increasing throughput capacity and optimizing product slate.
● Increasing tolling and terminaling revenue.
 
 
 
 
 
 
Seizing Market Opportunities
 
● Taking advantage of market opportunities as they arise.
 
 
 
 
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.
 
 
44
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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 alternatives. 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. Since 2015, the Nixon facility has been undergoing a capital improvement expansion project. Refinery operations capital improvements have primarily related to construction of new petroleum storage tanks. However, smaller efficiency improvements have been made as well. In the short-term, increased petroleum storage capacity has helped with de-bottlenecking the refinery. In the long-term, additional petroleum storage capacity will allow for increased refinery throughput of up to approximately 30,000 bpd.
 
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. Pilot may terminate the crude supply agreement at any time by providing us 60 days prior written notice. We may terminate the agreement upon the expiration of the initial term or at any time during a renewal term by giving Pilot 60 days prior written notice.
 
Pilot also stores crude oil at the Nixon facility under a terminal services agreement. 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.
 
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.
 
 
45
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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.
 
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 has been undergoing a capital improvement expansion project since 2015. Tolling and terminaling capital improvements have 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.
 
 
46
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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 months ended March 31, 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.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Remainder of Page Intentionally Left Blank
 
 
 
47
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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 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.
 
 
48
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
Consolidated Results.
 
Highlights (in millions)
 
 
 
 
Three Months Ended March 31, 2020 (“Q1 2020”) Versus March 31, 2019 (“Q1 2019”)
 
Overview. Net loss for Q1 2020 was $3.3 million, or a loss of $0.27 per share, compared to net income of $0.7 million, or income of $0.07 per share, Q1 2019. The significant decrease was the result of less favorable margins per bbl.
 
Total Revenue from Operations. Total revenue from operations for Q1 2020 decreased $6.9 million, or approximately 10%, to $62.0 million compared to $68.9 million for Q1 2019. The 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 in Q1 2020. Tolling and terminaling revenue increased approximately 3% as a result of increased tank rental storage fees and fees collected for ancillary services.
 
Total Cost of Goods Sold. Total cost of goods sold was $62.1 million for Q1 2020 compared to $65.5 million for Q1 2019. The $3.4 million, or 5%, decrease related to lower commodity prices per bbl for crude oil and chemicals due to market fluctuations associated with the COVID-19 pandemic in Q1 2020.
 
Gross Profit (Deficit). We had a gross deficit of $0.1 million for Q1 2020 compared to gross profit of $3.4 million for Q1 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 Q1 2020.
 
General and Administrative Expenses. General and administrative expenses for Q1 2020 compared to Q1 2019 were relatively flat at nearly $0.7 million and primarily consisted of insurance, taxes, and professional fees.
 
Depletion, Depreciation and Amortization. Depletion, depreciation and amortization expenses remained stable in Q1 2020 compared to Q1 2019 at approximately $0.6 million in both periods.
 
Total Other Income (Expense). Total other expense was $1.8 million in Q1 2020 compared to an expense of $1.2 million in Q1 2019. 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. Interest expense increased in Q1 2020 compared to Q1 2019 as a result of completion of certain CIP for which interest was no longer being capitalized and the addition of the line of credit with Pilot.
 
 
 
 
 
 
 
 
Remainder of Page Intentionally Left Blank
 
 
 
 
49
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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.
 
Highlights (in millions, except per bbl and throughput amounts)
 
 
 
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
(in thousands)
Refined product sales
 $60,897 
 $67,858 
Less: Total cost of goods sold
  (62,088)
  (65,516)
Gross profit (deficit)
  (1,191)
  2,342 
 
    
    
Sales (Bbls)
  1,141 
  1,029 
 
    
    
Gross Profit (Deficit) per Bbl
 $(1.04)
 $2.28 
 
 
 
Three Months Ended March 31,
 
 
 
2020  
 
 
2019  
 
 
 
(in thousands)
 
Net revenue (2)
 $60,897 
 $67,858 
 Intercompany fees and sales
  (617)
  (606)
Operation costs and expenses
  (61,833)
  (65,302)
Segment Contribution Margin (Deficit)
 $(1,553)
 $1,950 
 
 
50
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
 
 
 
 
 
 
Calendar
  91 
  90 
Operating
  (88)
  (79)
Refinery Downtime (Days)
  3 
  11 
 
    
    
 
    
    
Refinery Throughput
    
    
bpd
  13,452 
  13,254 
bbls
  1,183,746 
  1,047,059 
Capacity utilization rate
  89.7%
  88.4%
 
    
    
Refinery Production
    
    
bpd
  13,183 
  12,947 
bbls
  1,160,091 
  1,022,829 
Capacity utilization rate
  87.9%
  86.3%
 
(1) See “How We Evaluate Our Operations” and “Non-GAAP Reconciliations” within “Item 2.” for further information regarding this non-GAAP measure.
(2) Net revenue excludes intercompany crude sales.
 
Q1 2020 Versus Q1 2019
●
Refining gross deficit per bbl was $1.04 for Q1 2020 compared to a refining gross profit per bbl of $2.28 in Q1 2019, representing a decrease of $3.32 per bbl. The significant decrease related to lower margins due to market fluctuations including ones associated with the COVID-19 pandemic in Q1 2020.
●
Segment contribution margin decreased approximately $3.6 million to a loss of $1.6 million in Q1 2020 compared to a profit of $2.0 million in Q1 2019. The significant decrease related to lower margins per bbl due to market fluctuations associated with the COVID-19 pandemic in Q1 2020.
●
Refinery downtime in Q1 2020 improved by 8 days compared to Q1 2019; refinery downtime in 2020 related to a boiler repair while refinery downtime in Q1 2019 related to a maintenance turnaround and equipment repairs.
●
On a bpd basis, both refinery throughput and refinery production increased nearly 2% in Q1 2020 compared to Q1 2019. On a total bbls basis, refinery throughput and refinery production improved approximately 13% in Q1 2020 compared to Q1 2019. The improvement primarily related to less refinery downtime.
  
 
51
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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.
 
Highlights (in millions)
 
 
 
 
 
 
Three Months Ended March 31,
 
 
 
2020  
 
 
2019  
 
 
 
  (in thousands)
 
 
 
   
 
 
   
 
Net revenue (2)
 $1,103 
 $1,069 
Intercompany fees and sales
  617 
  606 
Operation costs and expenses
  (255)
  (364)
  Segment contribution margin 
 
 
 
 
 
 
 
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 $1,465 
 $1,311 
 
(1) See “How We Evaluate Our Operations” and “Non-GAAP Reconciliations” within “Item 2.” for further information regarding this non-GAAP measure.
(2) Net revenue excludes intercompany crude sales.
 
Q1 2020 Versus Q1 2019
●
Tolling and terminaling net revenue increased approximately 3% in Q1 2020 compared to Q1 2019 primarily as a result of increased tank storage rental fees and fees collected for ancillary services.
●
Intercompany fees and sales, which reflect fees associated with an intercompany tolling agreement tied to naphtha volumes, increased slightly in Q1 2020 compared to Q1 2019. Although naphtha sales volumes decreased, naphtha production volumes increased slightly in Q1 2020 compared to Q1 2019.
●
Segment contribution margin increased nearly $0.2 million, or nearly 12%, to approximately $1.5 million in Q1 2020 compared to approximately $1.3 million Q1 2019. The improvement in segment contribution margin related to increased tank storage rental fees and fees collected for ancillary services and lower operation costs and expenses.
 
 
52
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
Non-GAAP Reconciliations.
 
Reconciliation of Segment Contribution Margin (Deficit)
 
 
 
 
Three Months Ended March 31,
 
 
 
 
 
 
 
 
 
2020
 
 
2019
 
 
2020
 
 
2019
 
 
2020
 
 
2019
 
 
 
Refinery Operations
 
 
Tolling and Terminaling
 
 
Corporate and Other
 
 
 
(in thousands)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Segment contribution margin
 $(1,553)
 $1,950 
 $1,465 
 $1,311 
 $(59)
 $(57)
General and administrative expenses(1)
  (304)
  (332)
  (68)
  (43)
  (419)
  (295)
Depreciation and amortization
  (288)
  (465)
  (294)
  (99)
  (51)
  (26)
Interest and other non-operating income (expenses), net
  (741)
  (783)
  (770)
  (196)
  (243)
  (218)
Income (loss) before income taxes
  (2,886)
  370 
  333 
  973 
  (772)
  (596)
Income tax benefit
  - 
  - 
  - 
  - 
  (15)
  - 
Income (loss) before income taxes
 $(2,886)
 $370 
 $333 
 $973 
 $(787)
 $(596)
 
(1)            
General and administrative expenses within refinery operations include the LEH operating fee.
 
 
53
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
Capital Resources and Liquidity
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, (iii) servicing debt, and (iv) completing construction in progress. 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 $62.5 million and $59.4 million at March 31, 2020 and December 31, 2019, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $21.3 million and $19.6 million at March 31, 2020 and December 31, 2019, respectively. During Q1 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, 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.
 
Debt Overview.
 
Total Debt
 
 
 
 
March 31,
 
 
December 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)
 
USDA-Guaranteed Loans
 
 
 
 
 
 
First Term Loan Due 2034 (in default)
 $21,586 
 $21,776 
Second Term Loan Due 2034 (in default)
  8,953 
  9,031 
Amended Pilot Line of Credit (in default)
  11,378 
  11,786 
Notre Dame Debt (in default)
  8,816 
  8,617 
Related-Party Debt
    
    
BDPL Loan Agreement (in default)
  6,334 
  6,174 
March Ingleside Note (in default)
  1,024 
  1,004 
March Carroll Note (in default)
  1,173 
  997 
June LEH Note (in default)
  1,375 
  - 
Total Debt
  60,639 
  59,385 
 
    
    
Less: Current portion of long-term debt, net
  (52,395)
  (51,301)
Less: Unamortized debt issue costs
  (1,877)
  (2,096)
Less: Accrued interest payable (in default)
  (6,367)
  (5,988)
 
 $- 
 $- 
 
 
54
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
Principal payments on long-term debt totaled $0.7 million in Q1 2020 compared to $0.3 million in Q1 2019. As of the filing date of this report, we were current on required monthly payments under our secured loan agreements with Veritex. No payments have been made under subordinated loan agreements.
 
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’ withing 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
03/312017
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
 
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.
 
 
 
 
 
 
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55
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
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 and 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 the August 15, 2019 meeting may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (discussed within this “Note (16)” under ‘BSEE Offshore Pipelines and Platform Decommissioning’) prior to BSEE’s August 2020 deadline will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs.
 
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 March 31, 2020. At March 31, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.
 
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 BOEM and 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. In April 2020, BSEE issued an 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. Completion of the platform surveys are required by May 30, 2020 with associated reports due to BSEE by June 8, 2020. BDPL expects to complete approved, permitted decommissioning work by the BSEE August 2020 deadline.
 
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 assets and/or structural surveys of the platform by the allowable deadlines, 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 March 31, 2020. As of March 31, 2020, we maintained $2.6 million in AROs related to abandonment of these assets.
 
 
56
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis
 
Sources and Use of Cash.
 
Components of Cash Flows
 
 
 
 
Three Months Ended March 31,
 
 
 
2020
 
 
2019
 
 
 
(in thousands)  
 
Cash Flows Provided By (Used In):
 
 
 
 
 
 
Operating activities
 $(327)
 $(31)
Investing activities
  (198)
  (123)
Financing activities
  722 
  169 
Increase (Decrease) in Cash and Cash Equivalents
 $197 
 $15 
 
Q1 2020 Versus Q1 2019
We had a cash flow deficit from operations of $0.3 million for Q1 2020 compared to cash flow deficit from operations of approximately $0.03 million for Q1 2019. The decrease in cash flow from operations primarily related to loss from operations.
 
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
Since 2015, the Nixon facility has been undergoing a capital improvement expansion project. Capital improvements have primarily related to construction of new petroleum storage tanks. However, smaller efficiency improvements have been made as well. In the short-term, increased petroleum storage capacity has helped with de-bottlenecking the refinery. In the long-term, additional petroleum storage capacity will allow for increased refinery throughput of up to approximately 30,000 bpd. Increased petroleum storage capacity for tolling and terminaling operations provides an opportunity to generate additional tolling and terminaling revenue.
 
Q1 2020 Capital Expenditures
During Q1 2020, capital expenditures totaled $0.7 million compared to $0.3 million during Q1 2019. Expenditures during Q1 2020 primarily related to work on a petroleum storage tank. Work on the remaining petroleum storage tank under the Nixon capital improvement expansion project is nearly complete.
 
Future Expected Capital Expenditures
For the next 12 to 18 months, we expect to continue to incur capital expenditures related to facility and land improvements, installation of new and/or refurbished refinery process equipment, and completion of an unfinished petroleum storage tank. Capital spending is being funded by cash flow from operations, Affiliates, and available funding under a loan from Veritex that was secured in 2015. 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.
 
 
57
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Management’s Discussion and Analysis and Internal Controls
 
Accounting Standards.
 
Critical Accounting Policies and Estimates
Our significant accounting policies, recent accounting developments are described in “Note (2)” to our 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 COVID-19 outbreak has impacted these estimates and assumptions and will continue to do so. Our estimates at the end of the first quarter assumed no material impact from the disruptions caused by COVID-19. While there was not a material impact to our consolidated financial statements as of and for the three months ended March 31, 2020, our future assessment of the magnitude and duration of COVID-19, as well as other factors, could result in material impacts to our consolidated financial statements in future reporting periods.
 
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 is currently evaluating internal processes in order 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 months ended March 31, 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.)
 
 
 
 
 
 
 
Remainder of Page Intentionally Left Blank
 
 
 
58
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Legal Proceedings
 
PART II
 
ITEM 1.  LEGAL PROCEEDINGS
 
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 a 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 March 31, 2020 and December 31, 2019, accrued arbitration award payable was $0.
 
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 the August 15, 2019 meeting may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completion of its decommissioning obligations (discussed within this “Note (16)” under ‘BSEE Offshore Pipelines and Platform Decommissioning’) prior to BSEE’s August 2020 deadline will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs.
 
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 March 31, 2020. At March 31, 2020 and December 31, 2019, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.
 
 
59
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Legal Proceedings 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 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.
 
The recent outbreak of COVID-19 and certain developments in the global oil markets have had, and may 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 recent outbreak of COVID-19 and the responses of governmental authorities and companies and the self-imposed restrictions by many individuals across the world to stem the spread of the virus have significantly reduced global economic activity, as there has been a dramatic decrease in the number of businesses open for operation and substantially fewer people across the world traveling to work or leaving their home to purchase goods and services. This has also resulted in, for example, a dramatic reduction in airline flights and has reduced the number of automobiles on the road. As a result, there has been a decline in the demand for the refined products that we produce and sell.
 
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.
 
 
60
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Unregistered Sales of Equity Securities, Defaults upon Senior Securities and Other Information
 
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 and subsequent to the three months ended March 31, 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
 
Amended and Restated Operating Agreement
The Amended and Restated Operating Agreement was set to expire on April 1, 2020. However, the Amended and Restated Operating Agreement was renewed and approved by the Board on May 14, 2020 with an effective date of April 1, 2020. Key terms of the Amended and Restated Operating Agreement follow:
 
Term. The term begins on the effective date and expires upon the earliest to occur of the following: (a) upon the third anniversary of the effective date, which termination date shall be April 1, 2023, (b) upon written notice of either party upon the material breach of the agreement by the other party, or (c) upon 90 days’ notice by the Board if the Board determines that the Amended and Restated Operating Agreement is not in the best interest of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and/or BDSC.
 
Compensation. For services rendered: (a) Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC shall reimburse LEH at cost for all direct expenses, either paid directly by LEH or financed with LEH’s credit card. Amounts payable to LEH shall be invoiced by LEH weekly, but may be reimbursed sooner and (b) Blue Dolphin shall also pay to LEH a management fee equal to 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization and interest.
 
The foregoing summarizes the material terms of the Amended and Restated Operating Agreement. This summary does not purport to be complete and is qualified in its entirety by reference to the full text of the agreement, which is filed as Exhibit 10.1 to this report.
 
Together, Jonathan Carroll and LEH own approximately 82% of Blue Dolphin’s Common Stock.
 
See “Note (3)” and “Note 17”) of our consolidated financial statements for additional disclosures related to the Amended and Restated Operating Agreement.
 
 
61
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
Exhibits
 
ITEM 6.  EXHIBITS
 
Exhibits Index
 
No. 
Description 
 
10.1
Amended and Restated Operating Agreement effective as of April 1, 2020, between Lazarus Energy Holdings, LLC, Blue Dolphin Energy Company, Lazarus Energy, LLC, Lazarus Refining & Marketing, LLC, Nixon Product Storage, LLC, Blue Dolphin Pipe Line Company, Blue Dolphin Petroleum Company, and Blue Dolphin Services Co.
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
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Remainder of Page Intentionally Left Blank
 
 
 
 
62
BLUE DOLPHIN ENERGY COMPANY
 
FORM 10-Q 3/31/20
 
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)
 
 
 
 
 
 
 
 
 
 
 
 
May 15, 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)
 
 
 

 
63
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