UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended
September 30,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:
Securities registered pursuant to Section 12(g) of the Act:
Common Stock, par value $0.01 per share | ||
(Title of | ||
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).
Number of shares of common stock, par value $0.01 per share outstanding as of November 16, 2020:15, 2021: 12,693,514
Blue Dolphin Energy Company | September 30, 2021 │Page 1 |
Table of Contents |
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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS | 37 | |||
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Blue Dolphin Energy Company | September 30, |
Glossary of Terms | ||||
Glossary of Terms
Throughout this Quarterly Report on Form 10-Q, we have used the following terms:
Affiliate. Refers, either individually or collectively, to certain related parties, including Jonathan Carroll, Chairman and Chief Executive Officer of Blue Dolphin, and his affiliates (including Carroll & Company Financial Holdings, L.P., Ingleside, and Lazarus Capital, LLC) and/or LEH and its affiliates (including Lazarus Midstream Partners, L.P. and LTRI). Together, Jonathan Carroll and LEH owned approximately 82% of the Common Stock as of the filing date of this report.
Amended Pilot Line of Credit. Line of Credit Agreement dated May 3, 2019, between Pilot and NPS and subsequently amended on May 9, 2019, May 10, 2019, and September 3, 2019, the last amendment being Amendment No. 1; original line of credit amount was $13.0 million; effective October 4, 2021, NPS repaid all its obligations under the Amended Pilot Line of Credit.
Amended and Restated Operating Agreement. Affiliate agreement dated April 1, 2020, between Blue Dolphin, LE, LRM, NPS, BDPL, BDPC, BDSC, and LEH governing LEH’s operation and management of those companies’ assets.
ARO. Asset retirement obligations.
ASU. Accounting Standards Update.
AGO. Atmospheric gas oil 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.
BDEC Term Loan Due 2051. Loan Agreement dated May 4, 2021, between Blue Dolphin and the SBA in the original principal amount of $0.5 million.
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.
Blue Dolphin. Blue Dolphin Energy Company, one or more of its consolidated subsidiaries, or all of them taken as a whole.
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.
BOEM. U.S. Bureau of Ocean Energy Management.
BSEE. U.S. Bureau of Safety and Environmental Enforcement.
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. To calculate capacity utilization rate, divide total refinery throughput or total refinery production on a bpd basis by the crude distillation tower’s total capacity (currently 15,000 bpd).
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 2019–2021 coronavirus pandemic.
Common Stock. Blue Dolphin common stock, par value $0.01 per share. Blue Dolphin has 20,000,000 shares of Common Stock authorized, and 12,693,514 shares of Common Stock issued and outstanding.
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 produced in conjunction with natural gas. Although condensate is sometimes like crude oil, it is usually lighter.
Blue Dolphin Energy Company | September 30, |
Glossary of Terms |
Cost of goods sold. Crude oil and condensate costs, fuel use, and chemicals.
Crude distillation tower. A tall column-like vessel in which crude oil and condensate are heated and their vaporized components are distilled utilizing distillation trays. This process refines 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 density (light to heavy) and sulfur content (sweet to sour). Distillation must break crude oil into various components before these chemicals and compounds can be used as fuels or converted to more valuable products.
Depropanizer unit. A distillation column 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. 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; crude oil and condensate are heated at atmospheric pressure in the base of a distillation tower. As the temperature increases, the various compounds vaporize in succession at their respective 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.
DOT. U.S. Department of Transportation.
Downtime. Scheduled and unscheduled periods in which the crude distillation tower is not operating. Downtime may occur for various reasons, including bad weather, power failures, and preventive maintenance.
EIA. U.S. Energy Information Administration.
EIDL. Economic Injury Disaster Loan; provides economic relief to businesses that experienced a temporary loss of revenue due to COVID-19.
EPA. U.S. Environmental Protection Agency.
Eagle Ford Shale. Ahydrocarbon-producing geological formation that extends across South Texas from the Mexican border into East Texas.
Equipment Loan Due 2025. Installment sales contract dated October 13, 2020, between LE and Texas First to purchase a backhoe. LE previously rented the backhoe under a rent-to-own agreement that matured.
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 intermediate products; used as primary input materials in the refining process. Feedstocks are processed into one or more finished products.
Finished petroleum products. Materials or products at their final increments of value through processing; products held in inventory for delivery, sale, or use.
Freeport facility. Assets in Freeport, Texas; comprised of (i) crude oil and natural gas separation and dehydration units, (ii) natural gas processing, treating, and redelivery units, (iii) a vapor recovery unit, (iv) two onshore pipelines, and (v) 162 acres of land.
GAAP. Accounting principles generally accepted in the United States of America.
GEL. GEL Tex Marketing, LLC, a Delaware limited liability company and an affiliate of Genesis Energy, LLC; an arbitrator awarded GEL damages, attorney fees, and related expenses in August 2017; the parties fully resolved the dispute in August 2019.
Blue Dolphin Energy Company | September 30, |
Glossary of Terms |
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. U.S. Interior Board of Land Appeals.
INC. Incident of Noncompliance issued by BOEM and BSEE.
Ingleside. Ingleside Crude, LLC, an affiliate of Jonathan Carroll.
Intermediate petroleum products. A petroleum product that might require further processing before being offered for sale to a customer. Additional processing may be done by the producer or by another processor. Thus, an intermediate petroleum product might be a final product for one company and input for another company to further process.
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 an ownership change.
IRS. U.S. 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.
Kissick Debt. A loan agreement initially entered between LE and Notre Dame Investors, Inc. in the principal amount of $8.0 million. John Kissick currently holds the debt. In 2017, the parties amended the Kissick Debt to increase the principal amount by $3.7 million; LE used $3.6 million of the additional principal to reduce the arbitration award payable to GEL. The Kissick Debt matured in January 2018 and is currently in default. The Kissick Debt was previously disclosed as the Notre Dame Debt.
LE. Lazarus Energy, LLC, a wholly-owned subsidiary of Blue Dolphin.
LE Term Loan Due 2034. Loan Agreement dated June 22, 2015, between LE and Veritex in the original principal amount of $25.0 million; currently in default.
LE Term Loan Due 2050. Loan Agreement dated August 29, 2020, between LE and the SBA in the original principal amount of $0.15 million.
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 expenses, 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. Liquid petroleum that has a low density and flows freely at room temperature. Has a low viscosity, low specific gravity, and a high American Petroleum Institute gravity due to high proportion of light hydrocarbon fractions.
LRM. Lazarus Refining & Marketing, LLC, a wholly-owned subsidiary of Blue Dolphin.
LRM Term Loan Due 2034. Loan Agreement dated December 4, 2015, between LRM and Veritex in the original principal amount of $10.0 million; currently in default.
LTRI. Lazarus Texas Refinery I, an affiliate of LEH.
Naphtha. A refined or partly refined light distillate fraction of crude oil. When 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.
Blue Dolphin Energy Company | September 30, |
Glossary of Terms |
Nixon facility. Assets in Nixon, Texas; comprised of (i) a crude distillation tower, (ii) petroleum storage tanks, (iii) loading and unloading facilities, and (iv) 56 acres of land.
Nixon refinery. The 15,000-bpd crude distillation tower and associated processing units at the Nixon facility.
NPS. Nixon Product Storage, LLC, a wholly-owned subsidiary of Blue Dolphin.
NPS Term Loan Due 2050. Loan Agreement dated August 29, 2020, between NPS and the SBA in the original principal amount of $0.15 million.
NOL. Net operating losses.
Operating days. The number of days that the crude distillation tower was in use during a period. To calculate operating days, subtract downtime in a period from calendar days in the same period.
OPEC. Organization of Petroleum Exporting Countries.
OSHA. U.S. Occupational Safety and Health Administration.
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 and 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. Petroleum reflects both the naturally occurring, unprocessed crude oils and products 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 $0.10 per share. Blue Dolphin has 2,500,000 shares of Preferred Stock authorized, and no shares of Preferred Stock issued and outstanding.
Product slate. Type and quality of products produced.
Propane. A by-product of natural gas processing and petroleum refining. Propane is one of a group of liquified petroleum gases. Others include butane, propylene, butadiene, butylene, isobutylene, and mixtures thereof.
Refined products. Hydrocarbon compounds, such as jet fuel and residual fuel, that a refinery produces.
Refinery. In the oil and gas industry, a refinery is an industrial processing plant where crude oil, condensate, and intermediate feeds are separated and transformed into petroleum products.
Refining gross profit (deficit) per bbl. Calculated as refinery operations revenue less total cost of goods sold divided by the volume, in bbls, of refined products sold during the period; reflected as a dollar ($) amount per bbl.
ROU. Right-of-use.
SBA. U.S. Small Business Administration.
SEC. U.S. Securities and Exchange Commission.
Securities Act. The Securities Act of 1933, as amended.
Segment margin (deficit). For our refinery operations and tolling and terminaling business segments, represents net revenues (excluding intercompany fees and sales) attributable to the respective business segment less associated intercompany fees and sales less associated operation costs and expenses.
Stabilizer unit. A distillation column intended to remove the lighter boiling compounds, such as butane or propane, from a product.
Blue Dolphin Energy Company | September 30, 2021 │Page 6 |
Glossary of Terms |
Sulfur. Present at various levels of concentration in many hydrocarbon deposits, such as petroleum, coal, or natural gas. The process of removing sulfur-containing contaminants from natural gas and petroleum also produces sulfur as a by-product. Some of the most commonly used hydrocarbon deposits are categorized by their sulfur content. Lower sulfur fuels usually sell at a premium price; higher sulfur fuels sell at a discount.
Texas First. Texas First Rentals, LLC.
Throughput. Volume processed through a crude distillation tower or refinery or transported through a pipeline.
TMT. Texas margins tax; a form of business tax imposed on an entity’s gross profit rather than its net income.
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.
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.
Turnaround. Scheduled large-scale maintenance activity wherein an entire process unit is taken offline for a week or longer for a more comprehensive revamp and renewal.
USACOE. U.S. Army Corps of Engineers.
USDA. U.S. Department of Agriculture.
Veritex. Veritex Community Bank, successor in interest to Sovereign Bank by merger.
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 produced from crude oil and other feedstocks.
Blue Dolphin Energy Company | September 30, 2021 │Page 7 |
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 the use of the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will,” “would” and similar terms and phrases. Although weWe believe our assumptions concerning future events are reasonable,reasonable. However, several risks, uncertainties, and other factors could cause actual results and trends to differ materially from those projected, includingprojected. These include, but are not limited to:
Risks Related to the COVID-19 Pandemic
· | Continued adverse effects on our liquidity, business, financial condition, and results of operations due to the COVID-19 pandemic, which are expected to continue for the remainder of 2021 and into 2022. |
· | The persistence or worsening of market conditions related to the COVID-19 pandemic, which may require us to raise additional capital to operate our business or refinance existing debt on terms that are not acceptable to us or not at all. |
· | Continued or further deterioration in demand for our refined products could negatively affect our operations and financial condition. |
· | Potential impairment in the carrying value of long-lived assets, which could negatively affect our operating results. |
Business and Industry
· | Our going concern status. |
· | Inadequate liquidity to sustain operations due to defaults under our secured loan agreements, margin deterioration and volatility, and historical 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. |
· | Restrictive covenants in our debt instruments may limit our ability to undertake certain types of transactions. |
· | Affiliate common stock ownership and transactions that could cause conflicts of interest. |
· | Operational hazards inherent in transporting, processing, and storing crude oil and condensate and refined products. |
· | Geographical concentration of our assets and customers in West Texas. |
· | Competition from companies with more significant financial and other resources. |
· | Environmental laws and regulations may require us to make substantial capital improvements to remain compliant or remediate current or future contamination that could lead to material liabilities. |
· | Strict laws and regulations regarding personnel and process safety. |
· | Market changes in insurance that impact premium costs and available coverages. |
· | NOL carryforwards to offset future taxable income for U.S. federal income tax purposes that are subject to limitation. |
· | Industry technological developments that outpace our ability to keep up. |
· | Actual or threatened terrorist threats, activist incidents, cyber-security breaches, or acts of war that could affect our business. |
· | Adverse effects of |
· | Public health threats, pandemics, and epidemics, such as the ongoing outbreak of COVID-19, and the adverse impacts thereof on our business, financial condition, results of operations, and |
Blue Dolphin Energy Company | September 30, 2021 │Page 8 |
Important Information Regarding Forward Looking Statements |
Downstream and Midstream Operations
· | Commodity price | |
· | Crude oil, other feedstocks, and utility services price volatility. | |
· | Availability and | |
· | Equipment failure and maintenance, which lead to | |
· | Failure to effectively execute new business strategies, such as renewable fuels. | |
· | Adverse changes in | |
· | Critical personnel loss, labor | |
· | Market share loss, an unfavorable financial condition shift, or the bankruptcy or insolvency of | |
· | Increases in the cost or availability of third-party vessels, pipelines, trucks, and other means of delivering and transporting our 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. | |
· | Geographical concentration of our refining operations and customers within the Eagle Ford Shale. | |
· | Severe weather or other | |
· | Regulatory changes and other measures for the | |
· | Our ability to effect acquisitions. |
Pipeline and Facilities and Oil and Gas Assets
· | Assessment of civil penalties by BOEM for our failure to satisfy orders to provide additional financial assurance (supplemental pipeline bonds) within the time |
· | Assessment of civil penalties by BSEE for our failure to decommission pipeline and platform assets |
Common Stock
· | Fluctuations in our stock price that may result in a substantial investment loss. |
· | Declines in our stock price due to share sales by Affiliates. |
· | Dilution of |
· | The potential sale of shares in accordance with Rule 144, which |
· | The lack of |
· | Failure to maintain adequate internal controls under Section 404(a) of the Sarbanes-Oxley Act. |
See also the risk factors described in greater detail under “Item 1A.” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 and our Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2020 and June 30, 2020, as filed with the SEC.SEC and elsewhere in this filing. 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 ofdue to new information, future events, or otherwise.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Financial Statements |
PART I
ITEM 1.
Consolidated Balance Sheets (Unaudited)
September 30, | December 31, | |
2020 | 2019 | |
(in thousands except share amounts) | ||
| ASSETS | ||
| CURRENT ASSETS | ||
| Cash and cash equivalents | $275 | $72 |
| Restricted cash | 49 | 49 |
| Accounts receivable, net | 203 | 446 |
| Accounts receivable, related party | - | 1,364 |
| Prepaid expenses and other current assets | 1,617 | 2,276 |
| Deposits | 124 | 158 |
| Inventory | 862 | 1,645 |
| Refundable federal income tax | 100 | 65 |
| Total current assets | 3,230 | 6,075 |
| LONG-TERM ASSETS | ||
| Total property and equipment, net | 63,139 | 63,893 |
| Operating lease right-of-use assets, net | 538 | 649 |
| Restricted cash, noncurrent | 514 | 547 |
| Surety bonds | 230 | 230 |
| Deferred tax assets, net | - | 50 |
| Total long-term assets | 64,421 | 65,369 |
| TOTAL ASSETS | $67,651 | $71,444 |
| LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) | ||
| CURRENT LIABILITIES | ||
| Long-term debt less unamortized debt issue costs, current portion (in default) | $33,644 | $33,836 |
| Line of credit payable less unamortized debt issue costs (in default) | 9,621 | 11,464 |
| Long-term debt, related party, current portion (in default) | 12,173 | 6,001 |
| Interest payable (in default) | 5,615 | 3,814 |
| Interest payable, related party (in default) | 2,654 | 2,174 |
| Accounts payable | 3,240 | 1,877 |
| Accounts payable, related party | 155 | 149 |
| Current portion of lease liabilities | 251 | 251 |
| Asset retirement obligations, current portion | 2,386 | 2,565 |
| Accrued expenses and other current liabilities | 4,119 | 3,333 |
| Total current liabilities | 73,858 | 65,464 |
| LONG-TERM LIABILITIES | ||
| Long-term lease liabilities, net of current | 421 | 564 |
| Deferred revenues | 1,635 | 1,930 |
| Long-term debt, net of current portion | 300 | - |
| Total long-term liabilities | 2,356 | 2,494 |
| TOTAL LIABILITIES | 76,214 | 67,958 |
| Commitments and contingencies (Note 16) | ||
| STOCKHOLDERS' EQUITY (DEFICIT) | ||
| Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 and 12,327,365 | ||
| shares issued at September 30, 2020 and December 31, 2019, respectively) | 127 | 123 |
| Additional paid-in capital | 38,457 | 38,275 |
| Accumulated deficit | (47,147) | (34,912) |
| TOTAL STOCKHOLDERS' EQUITY (DEFICIT) | (8,563) | 3,486 |
| TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) | $67,651 | $71,444 |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands except share amounts) |
| |||||
|
|
|
|
|
|
| ||
ASSETS |
|
|
|
|
|
| ||
CURRENT ASSETS |
|
|
|
|
|
| ||
Cash and cash equivalents |
| $ | 2,177 |
|
| $ | 549 |
|
Restricted cash |
|
| 48 |
|
|
| 48 |
|
Accounts receivable, net |
|
| 63 |
|
|
| 214 |
|
Prepaid expenses and other current assets |
|
| 1,431 |
|
|
| 3,564 |
|
Deposits |
|
| 110 |
|
|
| 124 |
|
Inventory |
|
| 1,088 |
|
|
| 1,062 |
|
Total current assets |
|
| 4,917 |
|
|
| 5,561 |
|
|
|
|
|
|
|
|
|
|
LONG-TERM ASSETS |
|
|
|
|
|
|
|
|
Total property and equipment, net |
|
| 60,573 |
|
|
| 62,497 |
|
Operating lease right-of-use assets, net |
|
| 375 |
|
|
| 498 |
|
Restricted cash, noncurrent |
|
| 0 |
|
|
| 514 |
|
Surety bonds |
|
| 230 |
|
|
| 230 |
|
Total long-term assets |
|
| 61,178 |
|
|
| 63,739 |
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS |
| $ | 66,095 |
|
| $ | 69,300 |
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) |
|
|
|
|
|
|
|
|
CURRENT LIABILITIES |
|
|
|
|
|
|
|
|
Long-term debt less unamortized debt issue costs, current portion (in default) |
| $ | 33,788 |
|
| $ | 33,692 |
|
Line of credit payable (in default) |
|
| 4,754 |
|
|
| 8,042 |
|
Long-term debt, related party, current portion (in default) |
|
| 19,818 |
|
|
| 16,010 |
|
Interest payable (in default) |
|
| 8,384 |
|
|
| 6,408 |
|
Interest payable, related party (in default) |
|
| 3,294 |
|
|
| 2,814 |
|
Accounts payable |
|
| 2,583 |
|
|
| 3,274 |
|
Accounts payable, related party |
|
| 155 |
|
|
| 155 |
|
Current portion of lease liabilities |
|
| 209 |
|
|
| 194 |
|
|
|
| 2,370 |
|
|
| 2,370 |
|
Accrued expenses and other current liabilities |
|
| 9,361 |
|
|
| 4,882 |
|
Total current liabilities |
|
| 84,716 |
|
|
| 77,841 |
|
|
|
|
|
|
|
|
|
|
LONG-TERM LIABILITIES |
|
|
|
|
|
|
|
|
Long-term lease liabilities, net of current |
|
| 211 |
|
|
| 370 |
|
Deferred revenues |
|
| 1,313 |
|
|
| 1,520 |
|
Long-term debt, net of current portion |
|
| 843 |
|
|
| 355 |
|
Total long-term liabilities |
|
| 2,367 |
|
|
| 2,245 |
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES |
|
| 87,083 |
|
|
| 80,086 |
|
|
|
|
|
|
|
|
|
|
Commitments and contingencies (Note 16) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
STOCKHOLDERS' EQUITY (DEFICIT) |
|
|
|
|
|
|
|
|
Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 |
|
|
|
|
|
|
|
|
shares issued at September 30, 2021 and December 31, 2020) |
|
| 127 |
|
|
| 127 |
|
Additional paid-in capital |
|
| 38,457 |
|
|
| 38,457 |
|
Accumulated deficit |
|
| (59,572 | ) |
|
| (49,370 | ) |
TOTAL STOCKHOLDERS' EQUITY (DEFICIT) |
|
| (20,988 | ) |
|
| (10,786 | ) |
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) |
| $ | 66,095 |
|
| $ | 69,300 |
|
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Financial Statements |
Consolidated Statements of Operations (Unaudited)
Three Months Ended September 30, | Nine Months Ended September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| (in thousands, except share and per-share amounts) | ||||
| REVENUE FROM OPERATIONS | ||||
| Refinery operations | $41,929 | $77,537 | $120,185 | $222,652 |
| Tolling and terminaling | 1,001 | 1,096 | 3,214 | 3,253 |
| Total revenue from operations | 42,930 | 78,633 | 123,399 | 225,905 |
| COST OF GOODS SOLD | ||||
| Crude oil, fuel use, and chemicals | 41,789 | 74,163 | 118,292 | 213,714 |
| Other conversion costs | 2,611 | 2,066 | 7,872 | 6,587 |
| Total cost of goods sold | 44,400 | 76,229 | 126,164 | 220,301 |
| Gross profit (deficit) | (1,470) | 2,404 | (2,765) | 5,604 |
| COST OF OPERATIONS | ||||
| LEH operating fee | 169 | 144 | 506 | 477 |
| Other operating expenses | 58 | 52 | 164 | 165 |
| General and administrative expenses | 684 | 655 | 1,859 | 1,904 |
| Depletion, depreciation and amortization | 690 | 632 | 1,992 | 1,855 |
| Total cost of operations | 1,601 | 1,483 | 4,521 | 4,401 |
| Income (loss) from operations | (3,071) | 921 | (7,286) | 1,203 |
| OTHER INCOME (EXPENSE) | ||||
| Easement, interest and other income | 70 | 1 | 170 | 2 |
| Interest and other expense | (1,652) | (1,883) | (5,104) | (4,718) |
| Gain on extinguishment of debt | - | 9,128 | - | 9,128 |
| Total other income (expense) | (1,582) | 7,246 | (4,934) | 4,412 |
| Income (loss) before income taxes | (4,653) | 8,167 | (12,220) | 5,615 |
| Income tax expense | - | - | (15) | - |
| Net income (loss) | $(4,653) | $8,167 | $(12,235) | $5,615 |
| Income (loss) per common share: | ||||
| Basic | $(0.37) | $0.74 | $(0.98) | $0.51 |
| Diluted | $(0.37) | $0.74 | $(0.98) | $0.51 |
| Weighted average number of common shares outstanding: | ||||
| Basic | 12,693,514 | 10,975,514 | 12,534,493 | 10,975,514 |
| Diluted | 12,693,514 | 10,975,514 | 12,534,493 | 10,975,514 |
|
| Three Months Ended September 30, |
|
| Nine Months Ended September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands, except share and per-share amounts) |
| |||||||||||||
REVENUE FROM OPERATIONS |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Refinery operations |
| $ | 79,466 |
|
| $ | 41,929 |
|
| $ | 206,467 |
|
| $ | 120,185 |
|
Tolling and terminaling |
|
| 924 |
|
|
| 1,001 |
|
|
| 2,777 |
|
|
| 3,214 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenue from operations |
|
| 80,390 |
|
|
| 42,930 |
|
|
| 209,244 |
|
|
| 123,399 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COST OF GOODS SOLD |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil, fuel use, and chemicals |
|
| 78,312 |
|
|
| 41,789 |
|
|
| 204,594 |
|
|
| 118,292 |
|
Other conversion costs |
|
| 1,802 |
|
|
| 2,611 |
|
|
| 5,609 |
|
|
| 7,872 |
|
Total cost of goods sold |
|
| 80,114 |
|
|
| 44,400 |
|
|
| 210,203 |
|
|
| 126,164 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit (loss) |
|
| 276 |
|
|
| (1,470 | ) |
|
| (959 | ) |
|
| (2,765 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COST OF OPERATIONS |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LEH operating fee |
|
| 126 |
|
|
| 169 |
|
|
| 381 |
|
|
| 506 |
|
Other operating expenses |
|
| 83 |
|
|
| 58 |
|
|
| 187 |
|
|
| 164 |
|
General and administrative expenses |
|
| 649 |
|
|
| 684 |
|
|
| 1,919 |
|
|
| 1,859 |
|
Depletion, depreciation and amortization |
|
| 693 |
|
|
| 690 |
|
|
| 2,079 |
|
|
| 1,992 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total cost of operations |
|
| 1,551 |
|
|
| 1,601 |
|
|
| 4,566 |
|
|
| 4,521 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations |
|
| (1,275 | ) |
|
| (3,071 | ) |
|
| (5,525 | ) |
|
| (7,286 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER INCOME (EXPENSE) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Easement, interest and other income |
|
| 0 |
|
|
| 70 |
|
|
| 2 |
|
|
| 170 |
|
Interest and other expense |
|
| (1,654 | ) |
|
| (1,652 | ) |
|
| (4,722 | ) |
|
| (5,104 | ) |
Gain on extinguishment of debt |
|
| 0 |
|
|
| 0 |
|
|
| 43 |
|
|
| 0 |
|
Total other expense |
|
| (1,654 | ) |
|
| (1,582 | ) |
|
| (4,677 | ) |
|
| (4,934 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss before income taxes |
|
| (2,929 | ) |
|
| (4,653 | ) |
|
| (10,202 | ) |
|
| (12,220 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| (15 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Loss |
| $ | (2,929 | ) |
| $ | (4,653 | ) |
| $ | (10,202 | ) |
| $ | (12,235 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss per common share: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic |
| $ | (0.23 | ) |
| $ | (0.37 | ) |
| $ | (0.80 | ) |
| $ | (0.98 | ) |
Diluted |
| $ | (0.23 | ) |
| $ | (0.37 | ) |
| $ | (0.80 | ) |
| $ | (0.98 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic |
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,534,493 |
|
Diluted |
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,534,493 |
|
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Financial Statements |
Consolidated Statements of Cash Flows (Unaudited)
Nine Months ended September 30, | ||
2020 | 2019 | |
| OPERATING ACTIVITIES | ||
| Net income (loss) | $(12,235) | $5,615 |
| Adjustments to reconcile net income (loss) to net cash | ||
| used in operating activities: | ||
| Depletion, depreciation and amortization | 1,992 | 1,855 |
| Deferred income tax | 15 | - |
| Amortization of debt issue costs | 316 | 409 |
| Guaranty fees paid in kind | 457 | 471 |
| Related-party interest expense paid in kind | 361 | 189 |
| Deferred revenues and expenses | (295) | - |
| Gain on extinguishment of debt | - | (9,128) |
| Gain on issuance of shares | (80) | - |
| Changes in operating assets and liabilities | ||
| Accounts receivable | 243 | 43 |
| Accounts receivable, related party | 1,364 | (321) |
| Prepaid expenses and other current assets | 659 | 522 |
| Deposits and other assets | 34 | 32 |
| Inventory | 783 | (224) |
| Accrued arbitration award | - | (12,000) |
| Accounts payable, accrued expenses and other liabilities | 4,184 | 1,689 |
| Accounts payable, related party | 6 | 513 |
| Net cash used in operating activities | (2,196) | (10,335) |
| INVESTING ACTIVITIES | ||
| Capital expenditures | (1,085) | (1,458) |
| Net cash used in investing activities | (1,085) | (1,458) |
| FINANCING ACTIVITIES | ||
| Proceeds from debt | 300 | 12,402 |
| Payments on debt | (2,351) | (1,312) |
| Net activity on related-party debt | 5,502 | 218 |
| Net cash provided by financing activities | 3,451 | 11,308 |
| Net change in cash, cash equivalents, and restricted cash | 170 | (485) |
| CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD | 668 | 1,665 |
| CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD | $838 | $1,180 |
| Supplemental Information: | ||
| Non-cash investing and financing activities: | ||
| Financing of capital expenditures via accounts payable and finance leases | $- | $86 |
| Issuance of shares to extinguish debt | $120 | $- |
| Conversion of related-party notes to common stock | $148 | $- |
| Line of credit closing costs included in principal balance | $- | $398 |
| Interest paid | $1,980 | $2,261 |
| Income taxes paid | $- | $- |
|
| Nine Months Ended September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
OPERATING ACTIVITIES |
|
|
|
|
|
| ||
Net loss |
| $ | (10,202 | ) |
| $ | (12,235 | ) |
Adjustments to reconcile net income (loss) to net cash |
|
|
|
|
|
|
|
|
used in operating activities: |
|
|
|
|
|
|
|
|
Depletion, depreciation and amortization |
|
| 2,079 |
|
|
| 1,992 |
|
Deferred income tax |
|
| 0 |
|
|
| 15 |
|
Amortization of debt issue costs |
|
| 96 |
|
|
| 316 |
|
Guaranty fees paid in kind |
|
| 456 |
|
|
| 457 |
|
Related-party interest expense paid in kind |
|
| 826 |
|
|
| 361 |
|
Deferred revenues and expenses |
|
| (207 | ) |
|
| (295 | ) |
Loss (gain) on issuance of shares |
|
| 0 |
|
|
| (80 | ) |
Gain on extinguishment of debt |
|
| (43 | ) |
|
| 0 |
|
Changes in operating assets and liabilities |
|
|
|
|
|
| ||
Accounts receivable |
|
| 151 |
|
|
| 243 |
|
Accounts receivable, related party |
|
| 0 |
|
|
| 1,364 |
|
Prepaid expenses and other current assets |
|
| 2,133 |
|
|
| 659 |
|
Deposits and other assets |
|
| 14 |
|
|
| 34 |
|
Inventory |
|
| (26 | ) |
|
| 783 |
|
Accounts payable, accrued expenses and other liabilities |
|
| 5,141 |
|
|
| 4,184 |
|
Accounts payable, related party |
|
| 0 |
|
|
| 6 |
|
Net cash used in operating activities |
|
| (418 | ) |
|
| (2,196 | ) |
|
|
|
|
|
|
|
|
|
INVESTING ACTIVITIES |
|
|
|
|
|
|
|
|
Capital expenditures |
|
| 0 |
|
|
| (1,085 | ) |
Net cash used in investing activities |
|
| 0 |
|
|
| (1,085 | ) |
|
|
|
|
|
|
|
|
|
FINANCING ACTIVITIES |
|
|
|
|
|
|
|
|
Proceeds from issuance of debt |
|
| 500 |
|
|
| 300 |
|
Payments on debt |
|
| (13 | ) |
|
| (2,351 | ) |
Net activity on related-party debt |
|
| 209 |
|
|
| 5,502 |
|
Net cash provided by financing activities |
|
| 696 |
|
|
| 3,451 |
|
Net change in cash, cash equivalents, and restricted cash |
|
| 1,114 |
|
|
| 170 |
|
|
|
|
|
|
|
|
|
|
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD |
|
| 1,111 |
|
|
| 668 |
|
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD |
| $ | 2,225 |
|
| $ | 838 |
|
|
|
|
|
|
|
|
|
|
Supplemental Information: |
|
|
|
|
|
|
|
|
Non-cash investing and financing activities: |
|
|
|
|
|
|
|
|
Financing of line of credit via related-party debt |
| $ | 2,317 |
|
| $ | 1,789 |
|
Line of credit financed by offsetting tank leases less interest |
| $ | 971 |
|
| $ | 273 |
|
Issuance of shares for services and/or to extinguish debt |
| $ | 0 |
|
| $ | 120 |
|
Conversion of related-party notes to common stock |
| $ | 0 |
|
| $ | 148 |
|
Interest paid |
| $ | 727 |
|
| $ | 1,980 |
|
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Notes to Consolidated Financial Statements
(1)
Overview
Blue Dolphin was formed in 1986 as a Delaware corporation. The company is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operateOperations primarily consist of a light sweet-crude, 15,000-bpd crude distillation tower, with more thanand 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 tradedtrades on the OTCQX under the ticker symbol “BDCO”. Blue Dolphin has 20.0 million shares of Common Stock and 2.5 million shares of Preferred Stock authorized. There are approximately 12.7 million shares of Common Stock and no shares of Preferred Stock issued and outstanding.
Assets are primarily organized in two segments: refinery operations‘refinery operations’ (owned by LE) and tolling‘tolling and terminaling servicesservices’ (owned by LRM and NPS). Subsidiaries that are reflected in corporate‘Corporate and other includeother’ includes 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 “Blue Dolphin,” “we,” “us,” “our,” or “ours,”“ours” refer to Blue Dolphin, one or more of its consolidatedBlue Dolphin’s subsidiaries, or all of them taken as a whole.
Affiliates
Affiliates controlcontrolled approximately 82% of the voting power of our Common Stock.Stock as of the filing date of this report. An Affiliate operates and manages all Blue Dolphin properties and has historically fundedfunds working capital requirements during periods of working capital deficits, anddeficits. In addition, 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.
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
Third-Party Defaults
· | Veritex Loans – For both three-month periods ended September 30, 2021, and 2020, principal and interest payments to Veritex totaled $0. For the nine-month periods ended September 30, 2021, and 2020, principal and interest payments to Veritex totaled $0 and $0.3 million, respectively. As of the filing date of this report, LE and LRM were in default related to required monthly payments under the LE Term Loan Due 2034 and LRM Term Loan Due 2034. Defaults under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights concerning collateral securing obligors’ obligations under these loan agreements, and exercise any other rights and remedies available. Any exercise by Veritex of its rights and remedies under these 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. These adverse market actions could lead to holders of our common stock losing their investment in its entirety. We cannot assure investors that: (i) our assets or cash flow will be sufficient to repay borrowings under our secured loan agreements with Veritex fully, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, or (iii) Veritex, as first lien holder, will provide future default waivers. Borrowers and Veritex maintain ongoing dialogue regarding potential restructuring and refinance opportunities related to this debt. |
· | Amended Pilot Line of Credit – On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. However, NPS was in default as of September 30, 2021, and December 31, 2020, for failure of the borrower or any guarantor to pay past-due obligations when due. The debt, which accrued interest at a default rate of fourteen percent (14%) per annum, was classified within the current portion of long-term debt on our consolidated balance sheets at September 30, 2021, and December 31, 2020. |
Due to NPS’ default under the Amended Pilot Line of Credit, Pilot applied payments owed to NPS under two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of Credit from June 2020 to September 2021. For both three-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $0.6 million. For the nine-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $1.7 million and $0.8 million, respectively. |
Blue Dolphin Energy Company | September 30, 2021 │Page 13 |
| Table of Contents |
Notes to Consolidated Financial Statements |
The amount of interest NPS incurred under the Amended Pilot Line of Credit totaled $0.2 million and $0.4 million, respectively, for the three months ended September 30, 2021, and | |
· | Kissick Debt – Under a 2015 subordination agreement, John Kissick agreed to subordinate his 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 LE Term Loan Due 2034. To date, LE has made no payments under the subordinated Kissick Debt. Mr. Kissick has taken no action due to the non-payment. |
Related-Party Defaults
As of the filing date of this report, Blue Dolphin was in default concerning past due payment obligations under the March Carroll Note, March Ingleside Note, and June LEH Note. As of the same date, BDPL was also in default related to past due payment obligations under the BDPL-LEH Loan Agreement. Affiliates controlled approximately 82% of the voting power of our Common Stock as of the filing date of this report, an Affiliate operates and manages all Blue Dolphin properties, an Affiliate is a significant customer of our refined products, and we areborrow from Affiliates during periods of working capital deficits.
Substantial Current Debt
As of September 30, 2021, and December 31, 2020, we had current on required monthly payments under ourdebt of $58.4 million and $57.7 million, respectively, consisting of bank debt, related party debt, and the line of credit payable to Pilot, although the Pilot debt was subsequently repaid. Substantial current debt is primarily the result of secured loan agreements with Veritex, but other defaults are ongoing as noted below.
Margin Volatility. Our refining margins generally improve in an environment 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, includinghigher crude oil and condensate procurementrefined product prices, and where the spread between crude oil prices and refined product prices widens. In early 2020, global and national measures taken to address the COVID-19 pandemic, including government-imposed temporary business closures and voluntary shelter-at-home directives, caused oil prices to decline sharply. In addition, actions by members of OPEC and other producer countries in 2020 concerning oil production and pricing significantly impacted supply and demand in global oil and gas markets. With the introduction and approval of COVID-19 vaccines and increased inoculation rates, global economic activity has shown signs of recovery in 2021. Current EIA forecasts show economic growth and mobility increases in the short term. Also, refinery margins are forecasted to improve during the winter months due to projected colder winter temperatures compared to 2020 and low distillates inventory levels. However, forecasts are subject to various factors that are subject to change, including the ongoing impact of COVID-19 and related variants. As a result, we are currently unable to estimate our customer relationships;future financial condition;position 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.
Historical Net Losses and Working Capital Deficits
Net Losses
. Net loss for the three months ended September 30,Working Capital Deficits
. We hadCash and cash equivalents totaled $2.2 million and $19.6$0.5 million at September 30, 20202021, and December 31, 2019,2020, respectively. We had cash and cash equivalents and restrictedRestricted cash (current portion) of $0.3 million andtotaled $0.05 million respectively,at both September 30, 2021, and December 31, 2020. Restricted cash, noncurrent totaled $0 and $0.5 million at September 30, 2020. Comparatively, we had cash2021, and cash equivalents and restricted cash (current portion) of $0.07 million and $0.05 million, respectively, at December 31, 2019.
Our financial health has been materially and adversely affected by defaults in our secured loan agreements, margin volatility, and historical net losses and working capital deficits. If Pilot terminates the crude supply agreement or terminal services agreement, our ability to acquire crude oil and condensate could be adversely affected. If producers experience crude supply constraints and increased transportation costs, our crude acquisition costs may rise, or we may not receive sufficient amounts to meet our needs. During the three-month periods ended September 30, 2021, and 2020, our refinery experienced 6 days and 8 days of downtime, respectively, due to crude deficiencies associated with COVID-19 related cash constraints. During the nine-month periods ended September 30, 2021, and 2020, our refinery experienced 11 days and 16 days of downtime, respectively.
Blue Dolphin Energy Company | September 30, 2021 │Page 14 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Operating Risks
Successful execution of our business strategy depends on several keycritical factors, including having adequate working capital to meet contractual, operational, needsregulatory, and regulatory requirements, maintaining safe and reliable operations at the Nixon facility, meeting contractual obligations,safety needs and having favorable margins on refined products. As discussed under “Note (1) – Going Concern” above and throughout this report, weWe are currently unable to estimate the impact the ongoing COVID-19 pandemic will have on our future financial position and results of operations. Under earlierEarlier state and federal mandates that regulated business closures due to COVID-19 deemed our business was deemed as an essential, and as such, haswe remained open. As U.S. federal, state, and local officials contemplate renewedIf future restrictive mandates due to resurging coronavirus cases,directives become necessary, we expect to continue operating. However, suchadditional governmental mandates while necessary to address the virus, will likely result in further business and operational disruptions, including demand destruction, liquidity strains, supply chain challenges, travel restrictions, controls on in-person gathering, and workforce availability.
Management believes that it has taken all prudentcontinues to take steps to mitigate risk, avoid business disruptions, manage cash flow, and remain competitive in a low oilvolatile commodity price environment. Steps include managing cash flow by Mitigation steps include: adjusting throughput and production based on market conditions, optimizing receivables and payables by prioritizing payments, managing inventory to avoid buildup, monitoring discretionary spending, and delaying capital expenditures. However, there To safeguard personnel, we adopted remote working where possible and social distancing, mask-wearing, and other site-specific precautionary measures where on-site operations are required. We also incentivize personnel to receive the COVID-19 vaccine.
We can beprovide no assurance thatguarantees 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 theirexercises its rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
(2)
Basis of Presentation
The accompanying unaudited consolidated financial statements, which includeincluding Blue Dolphin and its subsidiaries, have beenwere prepared in accordance withunder GAAP for interim consolidated financial information pursuantaccording 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 normallyusually included in our audited financial statements have beenwere condensed or omitted pursuantaccording to the SEC’s rules and regulations. Significant intercompany transactions have beenwere eliminated in the consolidation. In management’s opinion, consolidated financial statements include all necessary adjustments considered necessary for a fair presentation, have been included, disclosures are adequate, and the presented information is not misleading.
We derived the consolidated balance sheet as of December 31, 2019 was derived2020, from the audited financial statements at that date. The accompanyingWe recommend that investors read the consolidated financial statements should be readand notes in conjunctionthis report together with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 20192020, as filed with the SEC. Operating results for the threeOur financial and nine months ended September 30, 2020 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2020, or for any other period. As discussed further below within this “Note (2) – Significant Accounting Policies – Use of Estimates,” the ongoing COVID-19 pandemic has resulted in significant economic disruption globally. This disruption became more acute in the latter half of March 2020; therefore, our operating results for the three and nine months ended September 30, 2020 do2021, should not fully reflectbe exclusively relied upon to indicate our performance for the impact this disruption has had, and will likely continue to have, on us.
Significant Accounting Policies
The summary of Blue Dolphin’s significant accounting policies of Blue Dolphin is presented to assistassists investors 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. TheseWe consistently applied these accounting policies conform to GAAP and have been consistently applied in the preparation of our consolidated financial statements.
Use of Estimates
.Cash and Cash Equivalents
. Cash and cash equivalents represent liquid investments with an original maturity of three months or less.Restricted Cash
. Restricted cash, current portion primarily represents a payment reserve account held by Veritex as security for payments under a secured loan agreement. Restricted cash, noncurrent represents funds held in the Veritex disbursement account for payment ofBlue Dolphin Energy Company | September 30, 2021 │Page 15 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Accounts Receivable and Allowance for Doubtful Accounts
.Inventory
. Inventory primarily consists of refined products, crude oil,Property and Equipment
.Refinery and Facilities
. We typically make ongoing improvements to thePipelines and Facilities
.Oil and Gas Properties
.CIP
. CIP expendituresLeases.
WeFor operating leases, we record 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.
Revenue Recognition
.Refinery Operations Revenue
.We consider a variety of facts and circumstances in assessing the point of a 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,We include incurred transportation, shipping, and handling costs incurred are included in the cost of goods sold. ExciseWe do not include excise and other taxes that are collected from customers and remitted to governmental authorities are not included in revenue.
Blue Dolphin Energy Company | September 30, 2021 │Page 16 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Tolling and Terminaling Revenue
. Tolling and terminaling revenue represents feesWe typically satisfy performance obligations for tolling and terminaling operations with the passage ofover time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the term of the agreement.agreement term. We allocate the transaction price to the single performance obligation that exists under the agreement, and weagreement. 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 thecustomer. The fixed cost under the customer’s tank storage agreement. Ancillaryagreement does not include ancillary service fees. We consider ancillary services are consideredas a separate performance obligation by us under the tank storage agreement. TheWe satisfy the performance obligation is satisfiedand recognize the associated fee when we complete the requested service has been performed in the applicable period.
Deferred Revenue
.Income Taxes
.Management uses significant judgment is required in evaluating uncertain tax positions and determining itsthe provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to determineassess the realizability of deferred tax assets. We considerweigh whether itthere is a more likely than not that50% probability of realizing a portion or all the deferred tax assets will be realized, which is dependent uponassets. Realization depends on the generation of future taxable income prior tobefore 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 September 30, 2020. Such objective evidence limits the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recordedWe record a valuation allowance against deferred income tax assets if there is a more than 50% probability of not realizing some portion of the asset. We recognize an uncertain tax positions benefit in our financial statements if deferred tax assets for which realization was not deemed more likely than not as of September 30, 2020 and December 31, 2019. We expect to recover deferred tax assets related to AMT credit carryforwards. In addition, we have NOL carryforwards that remain available for future use.
Impairment or Disposal of Long-Lived Assets
. We periodically evaluate our long-lived assets for impairment. Additionally, weCommodity price market volatility associated with the COVID-19 pandemic could have affectedaffect the value of certain of our long-lived assets, and management performed potential impairment testing ofassets. Management evaluated our refinery and facilities assets in 2019 and 2018. Upon completionfor impairment as of each testing, no impairment was deemed necessary. In addition, the market volatility of crude oil prices as a result of the ongoing COVID-19 pandemic could have affected the value of certain of our long-lived assets, and management performed impairment testing of our refinery and facilities assets at September 30, 2020. No impairment was deemed necessary based upon this testing, and we2021. 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 periodRefinery and Facilities.We believe 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 we cannot reasonably estimate the dates or ranges of dates upon which we would retire these assets. Management will record an asset retirement obligation for these assets cannot reasonably be estimated at this time. Whenwhen a legal or contractualdefinitive obligation to dismantle or remove the refinery and facilities assets arises and a date or range ofretirement dates can reasonably be estimated for the retirement of these assets, we willare evident.
Pipeline and Facilities; Oil and Gas Properties. Management uses significant judgment to estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
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 theNew Pronouncements Adopted
. The FASB issues ASUs to communicate changes to the FASB ASC, includingNew Pronouncements Issued, Not Yet Effective
.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.
(3)
Affiliate Operational Agreements Summary
Blue Dolphin and certain of its subsidiaries are partyparties to several operational agreements with Affiliates. Management believes that these related-party transactions were consummated on terms equivalent to those that prevail in arm's-lengthagreements are arm’s-length transactions. Related-party agreements related to Blue Dolphin’s operations consist of the following:
Agreement/Transaction | Parties | Effective Date | Key Terms |
Jet Fuel Sales Agreement | LEH LE | 04/01/ | 1-year term expiring earliest to occur of 03/31/ |
Office Sub-Lease Agreement | LEH BDSC | 01/01/2018 | 68-month term expiring 08/31/2023; office lease Houston, Texas; includes 6-month rent abatement period; rent approximately |
Amended and Restated Operating Agreement | LEH LE LRM NPS BDPL BDPC | 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 |
Working Capital
We have historically depended on Affiliates for financingfunding when revenue from operations and borrowingsavailability under bank facilities are insufficient to meet our liquidity and working capital needs. SuchWe reflect such borrowings are reflected in our consolidated balance sheets in accounts payable, related party, and/or long-term debt, related party.
Related-Party Long-Term Debt
Loan Description | Parties | Maturity Date | Interest Rate | Loan Purpose |
March Carroll Note | Jonathan Carroll Blue Dolphin | Jan 2019 | 8.00% | Blue Dolphin working capital; reflects amounts owed to Jonathan Carroll under the guaranty fee agreements |
March Ingleside Note | Ingleside Blue Dolphin | Jan 2019 | 8.00% | Blue Dolphin working capital |
June LEH Note | LEH Blue Dolphin | Jan 2019 | 8.00% | Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement |
BDPL-LEH Loan Agreement | LEH BDPL | Aug 2018 | 16.00% | Blue Dolphin working capital |
Amended and Restated Guaranty Fee Agreement(2) | Jonathan Carroll LE | -- | 2.00% | Tied to payoff of LE $25 million Veritex loan |
Amended and Restated Guaranty Fee Agreement(2) | Jonathan Carroll LRM | -- | 2.00% | Tied to payoff of LRM $10 million Veritex loan |
(1)
(2)
Guarantees, Security, and Security
Loan Description | Guarantees | Security | Event(s) of Default |
March Carroll Note (in default) | --- | --- | Borrower failure to pay past due payment obligations; loan matured January 2019 |
March Ingleside Note (in default) | --- | --- | Borrower failure to pay past due payment obligations; loan matured January 2019 |
June LEH Note (in default) | --- | --- | Borrower failure to pay past due payment obligations; loan matured January 2019 |
BDPL-LEH Loan Agreement | --- | Certain BDPL property | Borrower failure to pay past due payment obligations; loan matured August 2018 |
Blue Dolphin Energy Company | September 30, 2021 │Page 18 |
The BDPL-LEH Loan Agreement contains representations and warranties, affirmative and negative covenants, and events of default that we consider usual and customary for a credit facility of this type. There are no covenants associated with the March Carroll Note, March Ingleside Note, or June LEH Note.
Related-Party Financial Impact
Consolidated Balance Sheets
.Accounts payable, related party
. Accounts payable, related party to LTRI related to the purchase of refinery equipment totaled $0.2 million at both September 30,Long-term debt, related party, current portion (in default) and accrued interest payable, related party.
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| LEH | ||
| June LEH Note (in default) | $5,733 | $- |
| BDPL-LEH Loan Agreement | 6,654 | 6,174 |
| LEH Total | 12,387 | 6,174 |
| Ingleside | ||
| March Ingleside Note (in default) | 1,067 | 1,004 |
| Jonathan Carroll | ||
| March Carroll Note (in default) | 1,373 | 997 |
14,827 | 8,175 | |
| Less: Long-term debt, related party, current portion, in default | (12,173) | (6,001) |
| Less: Accrued interest payable, related party (in default) | (2,654) | (2,174) |
$- | $- | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
LEH |
|
|
|
|
|
| ||
June LEH Note (in default) |
| $ | 12,644 |
|
| $ | 9,446 |
|
BDPL-LEH Loan Agreement (in default) |
|
| 7,294 |
|
|
| 6,814 |
|
LEH Total |
|
| 19,938 |
|
|
| 16,260 |
|
Ingleside |
|
|
|
|
|
|
|
|
March Ingleside Note (in default) |
|
| 1,059 |
|
|
| 1,013 |
|
Jonathan Carroll |
|
|
|
|
|
|
|
|
March Carroll Note (in default) |
|
| 2,115 |
|
|
| 1,551 |
|
|
|
| 23,112 |
|
|
| 18,824 |
|
|
|
|
|
|
|
|
|
|
Less: Long-term debt, related party, current portion (in default) |
|
| (19,818 | ) |
|
| (16,010 | ) |
Less: Accrued interest payable, related party (in default) |
|
| (3,294 | ) |
|
| (2,814 | ) |
|
| $ | 0 |
|
| $ | 0 |
|
Consolidated Statements of Operations
.Total revenue from operations.
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||
2020 | 2019 | 2020 | 2019 | |||||
| (in thousands, except percent amounts) | ||||||||
| Refinery operations | ||||||||
| LEH | $11,942 | 27.8% | $25,034 | 31.8% | $34,244 | 27.8% | $70,016 | 31.0% |
| Third-Parties | 29,987 | 69.9% | 52,503 | 66.8% | 85,941 | 69.6% | 152,636 | 67.6% |
| Tolling and terminaling | ||||||||
| Third-Parties | 1,001 | 2.3% | 1,096 | 1.4% | 3,214 | 2.6% | 3,253 | 1.4% |
$42,930 | 100.0% | $78,633 | 100.0% | $123,399 | 100.0% | $225,905 | 100.0% | |
|
| Three Months Ended September 30, |
|
| Nine Months Ended September 30, |
| ||||||||||||||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||||||||||||||||||
|
| (in thousands, except percent amounts) |
|
| (in thousands, except percent amounts) |
| ||||||||||||||||||||||||||
Refinery operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
LEH |
| $ | 24,214 |
|
|
| 30.1 | % |
| $ | 11,942 |
|
|
| 27.8 | % |
| $ | 61,271 |
|
|
| 29.3 | % |
| $ | 34,244 |
|
|
| 27.8 | % |
Third-Parties |
|
| 55,252 |
|
|
| 68.7 | % |
|
| 29,987 |
|
|
| 69.9 | % |
|
| 145,196 |
|
|
| 69.4 | % |
|
| 85,941 |
|
|
| 69.6 | % |
Tolling and terminaling |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-Parties |
|
| 924 |
|
|
| 1.2 | % |
|
| 1,001 |
|
|
| 2.3 | % |
|
| 2,777 |
|
|
| 1.3 | % |
|
| 3,214 |
|
|
| 2.6 | % |
|
| $ | 80,390 |
|
|
| 100.0 | % |
| $ | 42,930 |
|
|
| 100.0 | % |
| $ | 209,244 |
|
|
| 100.0 | % |
| $ | 123,399 |
|
|
| 100.0 | % |
Interest expense.
Three Months Ended September 30, | Nine Months Ended September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| (in thousands) | ||||
| Jonathan Carroll | ||||
| Guaranty Fee Agreements | ||||
| First Term Loan Due 2034 | $108 | $110 | $324 | $333 |
| Second Term Loan Due 2034 | 45 | 46 | 134 | 138 |
| March Carroll Note (in default) | 23 | 33 | 66 | 86 |
| LEH | ||||
| BDPL-LEH Loan Agreement (in default) | 160 | 160 | 480 | 480 |
| June LEH Note (in default) | 102 | 17 | 245 | 40 |
| Ingleside | ||||
| March Ingleside Note (in default) | 15 | 12 | 50 | 63 |
$453 | $378 | $1,299 | $1,140 | |
|
| Three Months Ended September 30, |
|
| Nine Months Ended September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
Jonathan Carroll |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Guaranty Fee Agreements |
|
|
|
|
|
|
|
|
|
|
|
| ||||
First Term Loan Due 2034 |
| $ | 108 |
|
| $ | 108 |
|
| $ | 323 |
|
| $ | 324 |
|
Second Term Loan Due 2034 |
|
| 45 |
|
|
| 45 |
|
|
| 134 |
|
|
| 134 |
|
March Carroll Note (in default) |
|
| 33 |
|
|
| 23 |
|
|
| 94 |
|
|
| 66 |
|
LEH |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BDPL-LEH Loan Agreement (in default) |
|
| 160 |
|
|
| 160 |
|
|
| 480 |
|
|
| 480 |
|
June LEH Note (in default) |
|
| 293 |
|
|
| 102 |
|
|
| 690 |
|
|
| 245 |
|
Ingleside |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March Ingleside Note (in default) |
|
| 14 |
|
|
| 15 |
|
|
| 42 |
|
|
| 50 |
|
|
| $ | 653 |
|
| $ | 453 |
|
| $ | 1,763 |
|
| $ | 1,299 |
|
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Other.
The LEH operating fee totaled approximately $0.1 million and $0.2 million for the three-month periods ended September 30, 2021, and 2020, respectively. The LEH operating fee totaled approximately $0.4 million and 2019, respectively. Fees associated with the Dock Tolling Agreement with LMT totaled $0 and $0.4$0.5 million for the nine months ended September 30, 2021, and 2020, and 2019, respectively.
(4)
We have two reportable business segments: (i) refinery operations, focused on refining and marketing petroleum products at the Nixon facility, and (ii) tolling and terminaling. Refinery operations relate to the refiningterminaling, focused on tolling and marketing ofstoring 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 conductedfor third parties at the Nixon facility. Corporate and other includes BDSC, BDPL, and BDPC.
Revenue from Contracts with Customers
Disaggregation of Revenue
.Receivables from Contracts with Customers
.Contract Liabilities
. Our contract liabilitiesRemaining Performance Obligations
. Most of our customer contractsRemainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
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 September 30, | Nine Months Ended September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| (in thousands) | ||||
| Net revenue (excluding intercompany fees and sales) | ||||
| Refinery operations | $41,929 | $77,537 | $120,185 | $222,652 |
| Tolling and terminaling | 1,001 | 1,096 | 3,214 | 3,253 |
| Total net revenue | 42,930 | 78,633 | 123,399 | 225,905 |
| Intercompany fees and sales | ||||
| Refinery operations | (595) | (668) | (1,618) | (1,927) |
| Tolling and terminaling | 595 | 668 | 1,618 | 1,927 |
| Total intercompany fees | - | - | - | - |
Operation costs and expenses(1) | ||||
| Refinery operations | (43,691) | (76,088) | (124,942) | (219,766) |
| Tolling and terminaling | (709) | (285) | (1,222) | (1,012) |
| Corporate and other | (58) | (52) | (164) | (165) |
| Total operation costs and expenses | (44,458) | (76,425) | (126,328) | (220,943) |
| Segment contribution margin (deficit) | ||||
| Refinery operations | (2,357) | 781 | (6,375) | 959 |
| Tolling and terminaling | 887 | 1,479 | 3,610 | 4,168 |
| Corporate and other | (58) | (52) | (164) | (165) |
| Total segment contribution margin (deficit) | (1,528) | 2,208 | (2,929) | 4,962 |
General and administrative expenses(2) | ||||
| Refinery operations | (414) | (292) | (1,045) | (898) |
| Tolling and terminaling | (132) | (68) | (268) | (173) |
| Corporate and other | (307) | (295) | (1,052) | (833) |
| Total general and administrative expenses | (853) | (655) | (2,365) | (1,904) |
| Depreciation and amortization | ||||
| Refinery operations | (301) | (481) | (883) | (1,429) |
| Tolling and terminaling | (338) | (99) | (956) | (297) |
| Corporate and other | (51) | (52) | (153) | (129) |
| Total depreciation and amortization | (690) | (632) | (1,992) | (1,855) |
| Interest and other non-operating expenses, net | ||||
| Refinery operations | (679) | 8,329 | (2,171) | 6,723 |
| Tolling and terminaling | (599) | (824) | (1,985) | (1,599) |
| Corporate and other | (304) | (259) | (778) | (712) |
| Total interest and other non-operating expenses, net | (1,582) | 7,246 | (4,934) | 4,412 |
| Income (loss) before income taxes | ||||
| Refinery operations | (3,751) | 8,337 | (10,474) | 5,355 |
| Tolling and terminaling | (182) | 488 | 401 | 2,099 |
| Corporate and other | (720) | (658) | (2,147) | (1,839) |
| Total income (loss) before income taxes | (4,653) | 8,167 | (12,220) | 5,615 |
| Income tax expense | - | - | (15) | - |
| Net income (loss) | $(4,653) | $8,167 | $(12,235) | $5,615 |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
Net revenue (excluding intercompany fees and sales) |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Refinery operations |
| $ | 79,466 |
|
| $ | 41,929 |
|
| $ | 206,467 |
|
| $ | 120,185 |
|
Tolling and terminaling |
|
| 924 |
|
|
| 1,001 |
|
|
| 2,777 |
|
|
| 3,214 |
|
Total net revenue |
|
| 80,390 |
|
|
| 42,930 |
|
|
| 209,244 |
|
|
| 123,399 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intercompany fees and sales |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (650 | ) |
|
| (595 | ) |
|
| (1,797 | ) |
|
| (1,618 | ) |
Tolling and terminaling |
|
| 650 |
|
|
| 595 |
|
|
| 1,797 |
|
|
| 1,618 |
|
Total intercompany fees |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operation costs and expenses(1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (79,593 | ) |
|
| (43,691 | ) |
|
| (208,936 | ) |
|
| (124,942 | ) |
Tolling and terminaling |
|
| (521 | ) |
|
| (709 | ) |
|
| (1,267 | ) |
|
| (1,222 | ) |
Corporate and other |
|
| (83 | ) |
|
| (58 | ) |
|
| (187 | ) |
|
| (164 | ) |
Total operation costs and expenses |
|
| (80,197 | ) |
|
| (44,458 | ) |
|
| (210,390 | ) |
|
| (126,328 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment contribution margin (deficit) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (777 | ) |
|
| (2,357 | ) |
|
| (4,266 | ) |
|
| (6,375 | ) |
Tolling and terminaling |
|
| 1,053 |
|
|
| 887 |
|
|
| 3,307 |
|
|
| 3,610 |
|
Corporate and other |
|
| (83 | ) |
|
| (58 | ) |
|
| (187 | ) |
|
| (164 | ) |
Total segment contribution margin (deficit) |
|
| 193 |
|
|
| (1,528 | ) |
|
| (1,146 | ) |
|
| (2,929 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expenses(2) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (282 | ) |
|
| (414 | ) |
|
| (848 | ) |
|
| (1,045 | ) |
Tolling and terminaling |
|
| (70 | ) |
|
| (132 | ) |
|
| (206 | ) |
|
| (268 | ) |
Corporate and other |
|
| (423 | ) |
|
| (307 | ) |
|
| (1,246 | ) |
|
| (1,052 | ) |
Total general and administrative expenses |
|
| (775 | ) |
|
| (853 | ) |
|
| (2,300 | ) |
|
| (2,365 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (302 | ) |
|
| (301 | ) |
|
| (906 | ) |
|
| (883 | ) |
Tolling and terminaling |
|
| (340 | ) |
|
| (338 | ) |
|
| (1,020 | ) |
|
| (956 | ) |
Corporate and other |
|
| (51 | ) |
|
| (51 | ) |
|
| (153 | ) |
|
| (153 | ) |
Total depreciation and amortization |
|
| (693 | ) |
|
| (690 | ) |
|
| (2,079 | ) |
|
| (1,992 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest and other non-operating expenses, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (747 | ) |
|
| (679 | ) |
|
| (2,053 | ) |
|
| (2,171 | ) |
Tolling and terminaling |
|
| (384 | ) |
|
| (599 | ) |
|
| (1,284 | ) |
|
| (1,985 | ) |
Corporate and other |
|
| (523 | ) |
|
| (304 | ) |
|
| (1,340 | ) |
|
| (778 | ) |
Total interest and other non-operating expenses, net |
|
| (1,654 | ) |
|
| (1,582 | ) |
|
| (4,677 | ) |
|
| (4,934 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refinery operations |
|
| (2,108 | ) |
|
| (3,751 | ) |
|
| (8,073 | ) |
|
| (10,474 | ) |
Tolling and terminaling |
|
| 259 |
|
|
| (182 | ) |
|
| 797 |
|
|
| 401 |
|
Corporate and other |
|
| (1,080 | ) |
|
| (720 | ) |
|
| (2,926 | ) |
|
| (2,147 | ) |
Total loss before income taxes |
|
| (2,929 | ) |
|
| (4,653 | ) |
|
| (10,202 | ) |
|
| (12,220 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| (15 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss |
| $ | (2,929 | ) |
| $ | (4,653 | ) |
| $ | (10,202 | ) |
| $ | (12,235 | ) |
(1)
(2)
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Nine Months Ended | ||
September 30, | ||
2020 | 2019 | |
(in thousands) | ||
| Capital expenditures | ||
| Refinery operations | $295 | $1,375 |
| Tolling and terminaling | 790 | 83 |
| Corporate and other | - | - |
| Total capital expenditures | $1,085 | $1,458 |
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Identifiable assets | ||
| Refinery operations | $47,169 | $51,317 |
| Tolling and terminaling | 18,815 | 18,401 |
| Corporate and other | 1,667 | 1,726 |
| Total identifiable assets | $67,651 | $71,444 |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
Capital expenditures |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Refinery operations |
| $ | 0 |
|
| $ | 3 |
|
| $ | 0 |
|
| $ | 295 |
|
Tolling and terminaling |
|
| 0 |
|
|
| 174 |
|
|
| 0 |
|
|
| 790 |
|
Corporate and other |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
Total capital expenditures |
| $ | 0 |
|
| $ | 177 |
|
| $ | 0 |
|
| $ | 1,085 |
|
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Identifiable assets |
|
|
|
|
|
| ||
Refinery operations |
| $ | 44,939 |
|
| $ | 48,521 |
|
Tolling and terminaling |
|
| 19,878 |
|
|
| 18,722 |
|
Corporate and other |
|
| 1,278 |
|
|
| 2,057 |
|
Total identifiable assets |
| $ | 66,095 |
|
| $ | 69,300 |
|
(5)
Bank Accounts
Financial instruments that potentially subject us to risk concentrations of risk consist primarily of cash, trade receivables, and accounts 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 September 30, 20202021, and December 31, 2019,2020, we had cash balances (including restricted cash) that exceeded the FDIC insurance limit per depositor of approximately $0.3 million.
Key Supplier
The 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 theThe volume-based crude supply agreement expires when Pilot will sellsells us approximately 24.8 million net bbls of crude oil. Thereafter,After that, the crude supply agreement will continue onautomatically renews for successive one-year terms (each such term, a one-year evergreen basis.“Renewal Term”). Either party may provide the other with notice of non-renewal at least 60 days before the expiration of any Renewal Term. Effective March 1,June 30, 2020, Pilot assigned its rights, title, interest, and obligations in the crude supply agreement to Tartan Oil LLC, a Pilot affiliate. Either party may terminateAs of September 30, 2021, the total volume we received under the crude supply agreement by providing the other party 60 days prior written notice. was approximately 7.9 million bbls.
Pilot also stores crude oil at the Nixon facility under two terminal services agreements. Under the terminal services agreements, Pilot stores crude oil at the Nixon facility at a specified rate per bbl of the storage tank’s shell capacity. Although the initial term of the terminal services agreement expired April 30, 2020, the agreement renewedrenews 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 behas been materially and adversely affected by defaults in our secured loan agreements, margin deteriorationvolatility, and volatility, historichistorical net losses and working capital deficits, as well as termination ofdeficits. If Pilot terminates the crude supply agreement or terminal services agreement, with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, sustained periods of lowcondensate could be adversely affected. If producers experience crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. A failurecosts, our crude acquisition costs may rise, or we may not receive sufficient amounts to acquire crude oil and condensate when needed will have a material effect onmeet our business results and operations.needs. During the three-three-month periods ended September 30, 2021, and 2020, our refinery experienced 6 days and 8 days of downtime, respectively, due to crude deficiencies associated with COVID-19 related cash constraints. During the nine-month periods ended September 30, 2021, and 2020, our refinery experienced 11 days and 16 days of downtime, as a resultrespectively.
Due to NPS’ default under the Amended Pilot Line of lackCredit, Pilot applied payments owed to NPS under two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of crude dueCredit from June 2020 to cash constraints.
The amount of interest NPS incurred under the Amended Pilot Line of Credit totaled $0.2 million and $0.4 million, respectively, for the three months ended September 30, 2021, and 2020. For the nine months ended September 30, 2021, and 2020, interest was $0.7 million and $1.1 million, respectively. See “Note (1) Organization – Going Concern,” “Note (11) Line of Credit Payable,” and “Note (17) Subsequent Events” to our consolidated financial statements for additional disclosures related to the Amended Pilot Line of Credit.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Significant Customers
We routinely assess the financial strength of our customers andcustomers. To date, we have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.
Number Significant Customers | % Total Revenue from Operations | Portion of Accounts Receivable at Date Indicated | |
| Three Months Ended | |||
| September 30, 2020 | 4 | 80% | $0 |
| September 30, 2019 | 4 | 97% | $0.6 million |
| Nine Months Ended | |||
| September 30, 2020 | 4 | 82% | $0 |
| September 30, 2019 | 4 | 97% | $0.6 million |
Three Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at September 30, |
| |||
|
|
|
|
|
|
|
|
|
| |||
September 30, 2021 |
|
| 3 |
|
|
| 69 | % |
| $ | 0 |
|
September 30, 2020 |
|
| 4 |
|
|
| 80 | % |
| $ | 0 |
|
One of our significant customers is LEH, an Affiliate. TheDue to a HUBZone certification, 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. LEHterms. The Affiliate accounted for nearly30% and 28% and 32% of our total revenue from operations for the three months ended September 30, 2021, and 2020, respectively. The Affiliate represented $0 in accounts receivable at both September 30, 2021, and 2019,2020, respectively. LEH
Nine Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at September 30, |
| |||
|
|
|
|
|
|
|
|
|
| |||
September 30, 2021 |
|
| 3 |
|
|
| 72 | % |
| $ | 0 |
|
September 30, 2020 |
|
| 4 |
|
|
| 82 | % |
| $ | 0 |
|
The Affiliate accounted for nearly29% and 28% and 31% of our total revenue from operations for the nine months ended September 30, 2021, and 2020, and 2019, respectively. LEHThe Affiliate represented $0 in accounts receivable at both September 30, 2020. LEH represented $0.3 million in accounts receivable at September 30, 2019.
Outstanding amounts under certain related party agreements can significantly vary from period to period based on the timing of the related sales and payments received. The amounts are settled under normal business terms. Thepayments. Concerning the Amended and Restated Operating Agreement, we add any amount that remains outstanding at the end of the quarter to the June LEH Note. We classify the June LEH Note within long-term debt, related party, current portion (in default) on the consolidated balance sheets. At September 30, 2021, and December 31, 2020, the total amount we owed to LEH under the June LEH Note and the BDPL-LEH Loan Agreementlong-term debt, related-party agreements including accrued interest totaled $12.4$19.9 million and $6.2$16.3 million, at September 30, 2020 and December 31, 2019, respectively. See “Note“Notes (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to transactions with Affiliates.
Customer Concentration. All of Customers
Refined Product Sales
. Our market is the Gulf Coast region of the U.S., which the EIA represents as Petroleum Administration for Defense District 3 (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. Total refined product sales by distillation (from light to heavy) for the periods indicated consisted of the following:Three Months Ended September 30, | Nine Months Ended Ended September 30, | |||||||
2020 | 2019 | 2020 | 2019 | |||||
| (in thousands, except percent amounts) | ||||||||
| LPG mix | $- | 0.0% | $8 | 0% | $- | 0.0% | $17 | 0% |
| Naphtha | 7,847 | 18.7% | 14,147 | 18.2% | 22,523 | 18.7% | 43,358 | 19.5% |
| Jet fuel | 11,942 | 28.5% | 25,035 | 32.3% | 34,244 | 28.5% | 70,017 | 31.4% |
| HOBM | 12,196 | 29.1% | 17,044 | 22.0% | 31,077 | 25.9% | 49,951 | 22.5% |
| AGO | 9,944 | 23.7% | 21,303 | 27.5% | 32,341 | 26.9% | 59,309 | 26.6% |
$41,929 | 100.0% | $77,537 | 100.0% | $120,185 | 100.0% | $222,652 | 100.0% | |
|
| Three Months Ended September 30, |
|
| Nine Months Ended September 30, |
| ||||||||||||||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||||||||||||||||||
|
| (in thousands, except percent amounts) |
|
| (in thousands, except percent amounts) |
| ||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
LPG mix |
| $ | 9 |
|
|
| 0 | % |
| $ | 0 |
|
|
| 0 | % |
| $ | 21 |
|
|
| 0 | % |
| $ | 0 |
|
|
| 0 | % |
Naphtha |
|
| 20,440 |
|
|
| 22.3 | % |
|
| 7,847 |
|
|
| 18.7 | % |
|
| 49,928 |
|
|
| 23.2 | % |
|
| 22,523 |
|
|
| 18.7 | % |
Jet fuel |
|
| 24,212 |
|
|
| 30.6 | % |
|
| 11,942 |
|
|
| 28.5 | % |
|
| 61,271 |
|
|
| 29.2 | % |
|
| 34,244 |
|
|
| 28.5 | % |
HOBM |
|
| 17,607 |
|
|
| 23.4 | % |
|
| 12,196 |
|
|
| 29.1 | % |
|
| 49,282 |
|
|
| 24.9 | % |
|
| 31,077 |
|
|
| 25.9 | % |
AGO |
|
| 17,198 |
|
|
| 23.7 | % |
|
| 9,944 |
|
|
| 23.7 | % |
|
| 45,965 |
|
|
| 22.7 | % |
|
| 32,341 |
|
|
| 26.9 | % |
|
| $ | 79,466 |
|
|
| 100.0 | % |
| $ | 41,929 |
|
|
| 100.0 | % |
| $ | 206,467 |
|
|
| 100.0 | % |
| $ | 120,185 |
|
|
| 100.0 | % |
An Affiliate, LEH, purchases all of our jet fuel. See “Note“Notes (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate transactions.
Blue Dolphin Energy Company | September 30, 2021 │Page 23 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(6)
Prepaid expenses and other current assets as of the dates indicated consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Prepaid insurance | $1,099 | $417 |
| Prepaid crude oil and condensate | 374 | 1,651 |
| Prepaid easement renewal fees | 104 | 121 |
| Other prepaids | 40 | 87 |
$1,617 | $2,276 | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Prepaid insurance |
| $ | 935 |
|
| $ | 1,182 |
|
Prepaid crude oil and condensate |
|
| 360 |
|
|
| 2,249 |
|
Prepaid easement renewal fees |
|
| 82 |
|
|
| 99 |
|
Other prepaids |
|
| 54 |
|
|
| 34 |
|
|
| $ | 1,431 |
|
| $ | 3,564 |
|
(7)
Inventory as of the dates indicated consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Crude oil and condensate | $493 | $959 |
| Chemicals | 143 | 120 |
| AGO | 118 | 440 |
| Naphtha | 88 | 95 |
| Propane | 13 | 26 |
LPG mix | 7 | 5 |
$862 | $1,645 | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Crude oil and condensate |
| $ | 536 |
|
| $ | 463 |
|
AGO |
|
| 259 |
|
|
| 133 |
|
Naphtha |
|
| 142 |
|
|
| 120 |
|
Chemicals |
|
| 108 |
|
|
| 271 |
|
Propane |
|
| 27 |
|
|
| 15 |
|
LPG mix |
|
| 16 |
|
|
| 6 |
|
HOBM |
|
| 0 |
|
|
| 54 |
|
|
| $ | 1,088 |
|
| $ | 1,062 |
|
(8)
Property, plant and equipment, net, as of the dates indicated, consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Refinery and facilities | $71,855 | $66,317 |
| Land | 566 | 566 |
| Other property and equipment | 903 | 833 |
73,324 | 67,716 | |
| Less: Accumulated depletion, depreciation, and amortiation | (14,577) | (12,739) |
58,747 | 54,977 | |
| CIP | 4,392 | 8,916 |
$63,139 | $63,893 | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Refinery and facilities |
| $ | 72,184 |
|
| $ | 72,184 |
|
Land |
|
| 566 |
|
|
| 566 |
|
Other property and equipment |
|
| 903 |
|
|
| 903 |
|
|
|
| 73,653 |
|
|
| 73,653 |
|
|
|
|
|
|
|
|
|
|
Less: Accumulated depletion, depreciation, and amortiation |
|
| (17,145 | ) |
|
| (15,220 | ) |
|
|
| 56,508 |
|
|
| 58,433 |
|
|
|
|
|
|
|
|
|
|
CIP |
|
| 4,065 |
|
|
| 4,064 |
|
|
| $ | 60,573 |
|
| $ | 62,497 |
|
We capitalize the interest cost incurred on funds used to construct property, plant, and equipment. CapitalizedWe record capitalized interest is recorded as part of the asset it relates to, and is depreciatedwe depreciate the capitalized interest over the asset’s useful life. CapitalizedThe capitalized interest cost which is included in CIP was $0 and $0.7 million at September 30, 20202021, and December 31, 2019. Capital2020.
We funded capital expenditures for expansion at the Nixon facility were funded bythrough long-term debt from Veritex, revenue from operations, and working capital from Affiliates. At September 30, 2021, and December 31, 2020, unusedwe reflected Veritex-derived amounts not used for capital expenditures derived from Veritex loans were reflected in restricted cash (current and non-current portions) on our consolidated balance sheets. See “Note (10)” to our consolidated financial statements for additional disclosures related to working capital deficits and borrowings for capital spending.
Blue Dolphin Energy Company | September 30, 2021 │Page 24 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(9)
Accrued expenses and other current liabilities as of the dates indicated consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Unearned revenue from contracts with customers | $2,441 | $1,990 |
| Insurance | 525 | 159 |
| Unearned contract renewal income | 500 | 500 |
| Property, fuel and other taxes | 389 | 183 |
| Other payable | 186 | 228 |
| Board of director fees payable | 68 | 263 |
| Customer deposits | 10 | 10 |
$4,119 | $3,333 | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Unearned revenue from contracts with customers |
| $ | 7,713 |
|
| $ | 3,421 |
|
Unearned contract renewal income |
|
| 400 |
|
|
| 500 |
|
Insurance |
|
| 385 |
|
|
| 541 |
|
Other payable |
|
| 282 |
|
|
| 252 |
|
Taxes payable |
|
| 210 |
|
|
| 58 |
|
Board of director fees payable |
|
| 198 |
|
|
| 100 |
|
Customer deposits |
|
| 173 |
|
|
| 10 |
|
|
| $ | 9,361 |
|
| $ | 4,882 |
|
(10)
As of the filing date of this report, we are in default under our Veritex loans and the Kissick Debt. See ‘Defaults’ within this Note (10) for more information related to these defaults.
Loan Agreements Summary
| Loan Description | Parties | Original Principal Amount (in millions) | Maturity Date | Monthly Principal and Interest Payment | Interest Rate | Loan Purpose |
Veritex Loans(1) | ||||||
LE Term Loan Due 2034 (in default) | LE-Veritex | $25.0 | Jun 2034 | $0.2 million | WSJ Prime + 2.75% | Refinance loan; capital improvements |
LRM Term Loan Due 2034 (in default) | LRM-Veritex | $10.0 | Dec 2034 | $0.1 million | WSJ Prime + 2.75% | Refinance bridge loan; capital improvements |
Notre Dame Debt (in default)(2)(3) | LE-Kissick | $11.7 | Jan 2018 | No payments to date; payment rights subordinated | 16.00% | Working capital; reduced balance of GEL Final Arbitration Award |
| SBA EIDLs | ||||||
LE Term Loan Due 2050(4) | LE-SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
NPS Term Loan Due 2050(4) | NPS-SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
Loan Description |
Parties | Original Principal Amount (in millions) |
Maturity Date |
Monthly Principal and Interest Payment |
Interest Rate |
Loan Purpose |
Veritex Loans(1) |
|
|
|
|
|
|
LE Term Loan Due 2034 (in default) | LE Veritex | $25.0 | Jun 2034 | $0.2 million | WSJ Prime + 2.75% | Refinance loan; capital improvements |
LRM Term Loan Due 2034 (in default) | LRM Veritex | $10.0 | Dec 2034 | $0.1 million | WSJ Prime + 2.75% | Refinance bridge loan; capital improvements |
Kissick Debt (in default)(2)(3) | LE Kissick | $11.7 | Jan 2018 | No payments to date; payment rights subordinated | 16.00% | Working capital; reduced arbitration award payable to GEL |
SBA EIDLs |
|
|
|
|
|
|
BDEC Term Loan Due 2051(4) | Blue Dolphin SBA | $0.5 | Jun 2051 | $0.003 million | 3.75% | Working capital |
LE Term Loan Due 2050(5) | LE SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
NPS Term Loan Due 2050(5) | NPS SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
Equipment Loan Due 2025(6) | LE Texas First | $0.07 | Oct 2025 | $0.0013 million | 4.50% | Equipment Lease Conversion |
(1)
(2)
(3)
(4)
(5)For disaster loans made in 2020, the SBA EIDLsinitially deferred payments for the first twelve (12) months. The SBA later extended the payment deferral period from twelve (12) months to twenty-four (24) months; under the extension, the first payment is due in September 2022; interest accrues during the deferral period. The LE Term Loan Due 2050 and NPS Term Loan Due 2050 are not forgivable.
(6)In May 2019, LE entered into a 12-month equipment rental agreement with the option to purchase the backhoe at maturity. The equipment rental agreement matured in May 2020. In October 2020, LE entered into the Equipment Loan Due 2025 to finance the backhoe purchase. We use the backhoe at the Nixon facility.
Blue Dolphin Energy Company | September 30, 2021 │Page 25 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Outstanding Principal, Debt Issue Costs, and Accrued Interest
Third-party long-term debt (outstanding principal, accrued interest, and accrued interest)late fees), as of the dates indicated, was as follows:
September 30, | December 31, | |
2020 | 2019 | |
| (in thousands) | ||
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | $22,424 | $21,776 |
LRM Term Loan Due 2034 (in default) | 9,299 | 9,031 |
| SBA EIDLs | ||
| LE Term Loan Due 2050 | 150 | - |
| NPS Term Loan Due 2050 | 150 | - |
Notre Dame Debt (in default) | 9,214 | 8,617 |
41,237 | 39,424 | |
| Less: Current portion of long-term debt, net | (33,644) | (33,836) |
| Less: Unamortized debt issue costs | (1,781) | (1,877) |
Less: Accrued interest payable (in default) | (5,512) | (3,711) |
$300 | $- | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Veritex Loans |
|
|
|
|
|
| ||
LE Term Loan Due 2034 (in default) |
| $ | 23,827 |
|
| $ | 22,840 |
|
LRM Term Loan Due 2034 (in default) |
|
| 9,881 |
|
|
| 9,473 |
|
Kissick Debt (in default) |
|
| 10,011 |
|
|
| 9,413 |
|
SBA EIDLs |
|
|
|
|
|
|
|
|
BDEC Term Loan Due 2051 |
|
| 507 |
|
|
| 0 |
|
LE Term Loan Due 2050 |
|
| 155 |
|
|
| 152 |
|
NPS Term Loan Due 2050 |
|
| 155 |
|
|
| 152 |
|
Equipment Loan Due 2025 |
|
| 59 |
|
|
| 71 |
|
|
|
| 44,595 |
|
|
| 42,101 |
|
|
|
|
|
|
|
|
|
|
Less: Current portion of long-term debt, net |
|
| (33,788 | ) |
|
| (33,692 | ) |
Less: Unamortized debt issue costs |
|
| (1,653 | ) |
|
| (1,749 | ) |
Less: Accrued interest payable (in default) |
|
| (8,311 | ) |
|
| (6,305 | ) |
|
| $ | 843 |
|
| $ | 355 |
|
Unamortized debt issue costs associated with the Veritex loans as of the dates indicated consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | $1,674 | $1,674 |
LRM Term Loan Due 2034 (in default) | 768 | 768 |
| Less: Accumulated amortization | (661) | (565) |
$1,781 | $1,877 | |
|
| June 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Veritex Loans |
|
|
|
|
|
| ||
LE Term Loan Due 2034 (in default) |
| $ | 1,674 |
|
| $ | 1,674 |
|
LRM Term Loan Due 2034 (in default) |
|
| 768 |
|
|
| 768 |
|
|
|
|
|
|
|
|
|
|
Less: Accumulated amortization |
|
| (789 | ) |
|
| (693 | ) |
|
| $ | 1,653 |
|
| $ | 1,749 |
|
Amortization expense was $0.03 million for both three-month periods ended September 30, 20202021, and 2019.2020. Amortization expense was $0.09 million for both nine-month periods ended September 30, 20202021, and 2019.
Accrued interest and late fees 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:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
Notre Dame Debt (in default) | $4,236 | $3,639 |
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | 879 | 25 |
LRM Term Loan Due 2034 (in default) | 397 | 47 |
5,512 | 3,711 | |
| Less: Accrued interest payable (in default) | (5,512) | (3,711) |
| Long-term Interest Payable, Net of Current Portion | $- | $- |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Kissick Debt (in default) |
| $ | 5,033 |
|
| $ | 4,435 |
|
Veritex Loans |
|
|
|
|
|
|
|
|
LE Term Loan Due 2034 (in default) |
|
| 2,282 |
|
|
| 1,295 |
|
LRM Term Loan Due 2034 (in default) |
|
| 979 |
|
|
| 571 |
|
SBA EIDLs |
|
|
|
|
|
|
|
|
BDEC Term Loan Due 2051 |
|
| 7 |
|
|
| 0 |
|
LE Term Loan Due 2050 |
|
| 5 |
|
|
| 2 |
|
NPS Term Loan Due 2050 |
|
| 5 |
|
|
| 2 |
|
|
|
| 8,311 |
|
|
| 6,305 |
|
Less: Accrued interest payable (in default) |
|
| (8,311 | ) |
|
| (6,305 | ) |
Long-term Interest Payable, Net of Current Portion |
| $ | - |
|
| $ | - |
|
Blue Dolphin Energy Company | September 30, 2021 │Page 26 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Payment Deferments
Veritex Loans
. InSBA EIDLs. The deferment did not address LE’s requirement to replenish the $1.0 millionSBA EIDLs include a payment reserve account. Principal and interest payments resumed on July 22, 2020. As of the filing date of this report, we are current on required monthly payments under our secured loan agreements with Veritex, but other defaults are ongoing as noted below under “Defaults”.
Guarantees and Security
Loan Description | Guarantees | Security |
Veritex Loans(1) | ||
LE Term Loan Due 2034 (in default) | • 100% USDA-guarantee • Jonathan Carroll personal guarantee • LEH, LRM, and Blue Dolphin cross-guarantee | • First • 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 • $5.0 million life insurance policy on Jonathan Carroll |
LRM Term Loan Due 2034 (in default) | • 100% USDA-guarantee • Jonathan Carroll personal guarantee • LEH, LE, and Blue Dolphin cross-guarantee | • Second priority lien on rights of LE in crude distillation tower and other collateral of LE • First • First • First • All other collateral as described in the security documents |
Kissick Debt (in default)(2) | --- | • Subordinated deed of trust that encumbers the crude distillation tower and general assets of LE |
SBA EIDLs | ||
BDEC Term Loan Due | • Jonathan Carroll, personal guarantee • LEH guarantee | • Business assets (e.g., machinery and equipment, furniture, fixtures, etc.) as more fully described in the security agreement |
LE Term Loan Due 2050(3) | --- | • Business assets (e.g., machinery and equipment, furniture, fixtures, etc.) as more fully described in the security agreement |
NPS Term Loan Due 2050(3) | --- | • Business assets (e.g., machinery and equipment, furniture, fixtures, etc.) as more fully described in the security agreement |
Equipment Loan Due 2025 | --- | • First security interest in the equipment (backhoe). |
(1)
(2)
(3)In November 2020, Pilot notified NPS and guarantors that LE and NPS’ entry into the LE Term Loan Due 2050 and NPS Term Loan Due 2050 was a breach of the Amended Pilot Line of Credit; Pilot demanded full repayment of the Pilot Obligations, including through the use of SBA EIDL loan proceeds. Pilot also notified the SBA that the liens securing the LE Term Loan Due 2050 and NPS Term Loan Due 2050 were junior to liens securing the Pilot Obligations. While the SBA acknowledged this point and indicated a willingness to subordinate these loans to Pilot, Pilot has taken no further actions as of the filing date of this report.
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.lenders. 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. TheUSDA regulations require that Veritex, as 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. BothThe same collateral must secure both the guaranteed and unguaranteed portionsparts of the loan are to be secured by the same collateral with equal lien priority. TheBorrowers cannot pay or otherwise subordinate 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“Notes (3)” and “Note (16)” to our consolidated financial statements for additional disclosures related to Affiliate agreements and transactions, including long-term debt guarantees.
Covenants
The Veritex loans and SBA EIDLs contain representations and warranties, affirmative and negative covenants, and events of default that we consider usual and customary for credit facilities of this type. There are no covenants associated with the Notre Dame Debt.
Blue Dolphin Energy Company | September 30, 2021 │Page 27 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Defaults
Loan Description | Event(s) of Default | Covenant Violations |
Veritex Loans | ||
LE Term Loan Due 2034 (in default) | Failure to make required monthly payments; failure to replenish $1.0 million payment reserve account; events of default under other secured loan agreements with Veritex | Financial covenants: • debt service coverage ratio, current ratio, and debt to net worth ratio |
LRM Term Loan Due 2034 (in default) | Failure to make required monthly payments; events of default under other secured loan agreements with Veritex | Financial covenants: • debt service coverage ratio, current ratio, and debt to net worth ratio |
Kissick Debt (in default) | Failure of borrower to pay | --- |
Veritex Loans.As reflected in the table above and elsewhere in this report, we are in default underfiling, the LE Term Loan Due 2034 and LRM Term Loan Due 2034 and the Notre Dame Debt.are in default. Defaults under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights with respect toconcerning collateral securing obligors’ obligations under these loan agreements, and/orand exercise any other rights and remedies available. TheWe classified the debt associated with the LE Term Loan Due 2034 and LRM Term Loan Due 2034 and the Notre Dame Debt was classified within the current portion of long-term debt on our consolidated balance sheets at September 30, 20202021, and December 31, 2019.
As the first lienholder, 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, whichdecrease. These adverse market actions could lead to holders of our common stock losing their investment in our common stockits entirety.
Kissick Debt. Under a 2015 subordination agreement, John Kissick agreed to subordinate his right to payments, as well as any security interest and liens on the Nixon facility’s business assets, in its entirety.
We can provide no assurancecannot assure investors that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements with Vertitex,Veritex and Mr. Kissick, either upon maturity or if accelerated, (ii) LE and LRMwe will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder,lenders will provide future default waivers. Defaults under our secured loan agreementsSee “Notes (1) 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.
(11)
On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. However, NPS was in default as of September 30, 2021, and December 31, 2020. This debt was classified within the current portion of long-term debt on our consolidated balance sheets at September 30, 2021, and December 31, 2020. See “Note (17)” for additional disclosures related to the Line of Credit Payable.
Line of Credit Agreement Summary
Line of Credit Description | Original Principal Amount (in millions) | Maturity Date | Monthly Principal and Interest Payment | Interest Rate | Loan Purpose |
Amended Pilot Line of Credit (in default) | $13.0 | May 2020 | ---- | 14.00% | GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital |
Line of Credit Description | Original 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% | Settlement payment to GEL, NPS purchase of crude oil from Pilot, and working capital |
Outstanding Principal, Debt Issue Costs, and Accrued Interest
Amounts owed under the Amended Pilot Line of credit payable,Credit, which represents outstanding principal and accrued interest, as of the dates indicated was as follows:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
Amended Pilot Line of Credit (in default) | $9,724 | $11,786 |
| Less: Unamortized debt issue costs | - | (219) |
| Less: Interest payable, short-term | (103) | (103) |
$9,621 | $11,464 | |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
Amended Pilot Line of Credit (in default) |
| $ | 4,827 |
|
| $ | 8,145 |
|
|
|
|
|
|
|
|
|
|
Less: Interest payable, short-term |
|
| (73 | ) |
|
| (103 | ) |
|
| $ | 4,754 |
|
| $ | 8,042 |
|
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Guarantees and Security
Loan Description | Guarantees | Security |
Amended Pilot Line of Credit | • 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. |
In an Agreement Regarding Attornment of Tank Leases dated April 30, 2019, 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 LE’s obligations under a certainparticular tank lease agreement if itVeritex were to foreclose on LE property that NPS was leasing from LE so long as LE met certain conditions were met.conditions. The effectiveness of the Agreement Regarding Attornment of Tank Leases was subject to certain conditions, including the agreement and concurrence of the USDA that the Agreement Regarding Attornment of Tank Leases does not impair or void the LE Term Loan Due 2034 and LRM Term Loan Due 2034 or any associated guarantees. Veritex used commercially reasonable efforts to obtain such USDA concurrence, however, as of the filingconcurrence. However, to date, of this report such USDA concurrence hadhas not been provided.
Covenants
The Amended Pilot Line of Credit contains customary affirmative and negative covenants and events of default.
Defaults
Loan Description | Event(s) of Default | Covenant Violations |
Amended Pilot Line of Credit (in default) | Failure of borrower or any guarantor to pay | --- |
NPS was in default under the Amended Pilot Line of Credit.Credit at September 30, 2021, and December 31, 2020. On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit.
In May 4, 2020, when NPS failed to pay off the Amended Pilot Line of Credit at maturity, Pilot sent NPS as borrower,(as borrower), and LRM, LEH, LE, and Blue Dolphin each(each a guarantor and collectively guarantors,guarantors), a notice demanding the immediate payment of the unpaid principal amount and all interest accrued and unpaid, and all other amounts owing or payable (the “Obligations”) under the Amended Pilot Line of Credit. Pursuant topayment. Under the Amended Pilot Line of Credit, commencing on May 4, 2020, the Pilot Obligations began to accrue interest at a default rate of fourteen percent (14%) per annum. Failure of the borrower or any guarantor to payof paying the past due Pilot 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.
Due to NPS’ default under the Amended Pilot Line of Credit, Pilot applied payments owed to NPS under two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of Credit from June 2020 to September 2021. For both three-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $0.6 million. For the nine-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $1.7 million and $0.8 million, respectively.
The amount of interest NPS incurred under the Amended Pilot Line of Credit totaled $0.2 million and $0.4 million, respectively, for the three months ended September 30, 2021, and 2020. For the nine months ended September 30, 2021, and 2020, interest was $0.7 million and $1.1 million, respectively. See “Note (1) Organization – Going Concern,” “Note (11) Line of Credit Payable,” and “Note (17) Subsequent Events” to our consolidated financial statements for additional disclosures related to the Amended Pilot Line of Credit.
In November 2020, Pilot notified NPS and guarantors that LE and NPS’ entry into the LE Term Loan Due 2050 and NPS Term Loan Due 2050 was a breach of the Amended Pilot Line of Credit; Pilot demanded full repayment of the Pilot Obligations, including through the use of SBA EIDL loan proceeds. Pilot also notified the SBA that the liens securing the LE Term Loan Due 2050 and NPS Term Loan Due 2050 were junior to liens securing the Pilot Obligations. While the SBA acknowledged this point and indicated a willingness to subordinate these loans to Pilot, Pilot has taken no further actions as of the filing date of this report.
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.
(12)
Refinery and Facilities
We believe we have no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Management believesFurther, we believe that the refinery and facilitiesthese assets have indeterminate lives under FASB ASC guidance for estimating AROs because we cannot reasonably estimate the dates or ranges of dates upon which we would retire these assets. Management will record an asset retirement obligation for these assets cannot reasonably be estimated at this time. Whenwhen a legal or contractualdefinitive obligation to dismantle or remove the refinery and facilities assets arises and a date or range ofretirement 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.
Blue Dolphin Energy Company | September 30, 2021 │Page 29 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Pipelines and Facilities and Oil and Gas Properties
We have AROs associated with the decommissioning of our pipelines and facilities assets as well as theand plugging and abandonment ofabandoning our oil and gas properties. WeWhen we placed these assets in service, we recorded a discounted liability for the fair value of anthe 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, andasset. Subsequently, 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. AtThe ARO liability was fully accreted at September 30, 20202021, and December 31, 2019, the liability was fully accreted.2020. 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:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| AROs, at the beginning of the period | $2,565 | $2,565 |
| Liabilities settled | (179) | - |
2,386 | 2,565 | |
| Less: AROs, current portion | (2,386) | (2,565) |
| Long-term AROs, at the end of the period | $- | $- |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
AROs, at the beginning of the period |
| $ | 2,370 |
|
| $ | 2,565 |
|
Liabilities settled |
|
| 0 |
|
|
| (195 | ) |
|
|
| 2,370 |
|
|
| 2,370 |
|
Less: AROs, current portion |
|
| (2,370 | ) |
|
| (2,370 | ) |
Long-term AROs, at the end of the period |
| $ | - |
|
| $ | - |
|
Liabilities settled reflects preparatoryreflect preparation costs in the period associated with decommissioning our offshore pipelines and platform assets.
(13)
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 August 2023. Under the lease, BDSC hasIn March 2021, BDSC defaulted on the office lease due to non-payment. In May 2021, BDSC and TR 801 Travis LLC (“Building Lessor”) reached an agreement to cure BDSC’s office lease default. Under the terms of the May arrangement, BDSC agreed to pay Building Lessor past due obligations, including rent installments and other charges totaling approximately $0.1 million (the “Past Due Obligations”), in equal monthly installments beginning in June 2021, and continuing through lease expiration The Past Due Obligations are subject to an annual percentage rate of 4.50%. As revised, BDSC’s monthly base rent plus the prorated portion of the Past Due Obligations is $0.02 million. BDSC made the June 2021 revised lease payment. However, as of the filing date of this report, BDSC was in default related to required monthly lease payments for July through November 2021. In an October 11, 2021, letter, Building Lessor notified BDSC of its new default under the office lease due to non-payment. Default under the office lease permits Building Lessor to declare the amounts owed under the office lease immediately due and payable, exercise its rights concerning collateral securing obligors’ obligations under the office lease, including property placed in or upon the leased premises, and exercise any other rights and remedies available. Although BDSC intends to cure the lease default, we can provide no assurance that our efforts will be successful.
An Affiliate, LEH, subleases a portion of thisthe Houston office space. SubleaseBDSC received sublease income received from LEH totaled approximatelytotaling $0.01 million for both the three months ended September 30, 20202021, and 2019.2020. Sublease income received from LEH totaled approximately $0.03 million for both the nine monthsnine-month periods ended September 30, 20202021, and 2019.2020. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Notes to Consolidated Financial Statements |
The following table presents the lease-related assets and liabilities recorded on the consolidated balance sheet:
September 30, | December 31, | ||
Balance Sheet Location | 2020 | 2019 | |
(in thousands) | |||
| Assets | |||
| Operating lease ROU assets | Operating lease ROU assets | $787 | $787 |
| Less: Accumulated amortization on operating lease assets | Operating lease ROU assets | (249) | (138) |
538 | 649 | ||
| Finance lease assets | Property and equipment, net | 86 | 180 |
| Less: Accumulated amortization on finance lease assets | Property and equipment, net | (16) | (34) |
70 | 146 | ||
| Total lease assets | 608 | 795 | |
| Liabilities | |||
| Current | |||
| Operating lease | Current portion of lease liabilities | 190 | 175 |
| Finance leases | Current portion of lease liabilities | 61 | 76 |
251 | 251 | ||
| Noncurrent | |||
| Operating lease | Long-term lease liabilities, net of current | 421 | 564 |
| Total lease liabilities | $672 | $815 | |
|
|
|
| September 30, |
|
| December 31, |
| |||
|
| Balance Sheet Location |
|
| 2021 |
|
| 2020 |
| ||
|
|
|
| (in thousands) |
| ||||||
Assets |
|
|
|
|
|
|
|
|
| ||
Operating lease ROU assets |
| Operating lease ROU assets |
|
| $ | 787 |
|
| $ | 787 |
|
Less: Accumulated amortization on operating lease assets |
| Operating lease ROU assets |
|
|
| (412 | ) |
|
| (289 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
Total lease assets |
|
|
|
|
| 375 |
|
|
| 498 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities |
|
|
|
|
|
|
|
|
|
|
|
Current |
|
|
|
|
|
|
|
|
|
|
|
Operating lease |
| Current portion of lease liabilities |
|
|
| 209 |
|
|
| 194 |
|
|
|
|
|
|
| 209 |
|
|
| 194 |
|
Noncurrent |
|
|
|
|
|
|
|
|
|
|
|
Operating lease |
| Long-term lease liabilities, net of current |
|
|
| 211 |
|
|
| 370 |
|
Total lease liabilities |
|
|
| $ | 420 |
|
| $ | 564 |
| |
Weighted average remaining lease term in years | ||||
Operating lease | 1.92 | |||
Weighted average discount rate | ||||
Operating lease | 8.25 | % | ||
Finance leases | 8.25 | % | ||
The following table presents information related to leaseleasing costs for operating and finance leases:
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
(in thousands) | ||||
| Operating lease costs | $51 | $51 | $154 | $154 |
| Finance lease costs: | ||||
| Depreciation of leased assets | 3 | 4 | 13 | 12 |
| Interest on lease liabilities | - | 2 | 3 | 4 |
| Total lease cost | $54 | $57 | $170 | $170 |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Operating lease costs |
| $ | 51 |
|
| $ | 51 |
|
| $ | 154 |
|
| $ | 154 |
|
Finance lease costs: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation of leased assets |
|
| 0 |
|
|
| 3 |
|
|
| 0 |
|
|
| 13 |
|
Interest on lease liabilities |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| 3 |
|
Total lease cost |
| $ | 51 |
|
| $ | 54 |
|
| $ | 154 |
|
| $ | 170 |
|
The table below presents supplemental cash flow information related to leases as follows:
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
(in thousands) | ||||
| Cash paid for amounts included in the measurement | ||||
| of lease liabilities: | ||||
| Operating cash flows for operating lease | $44 | $40 | $130 | $81 |
| Operating cash flows for finance leases | $- | $2 | $4 | $4 |
| Financing cash flows for finance leases | $5 | $13 | $17 | $35 |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
Cash paid for amounts included in the measurement |
|
|
|
|
|
|
|
|
|
|
|
| ||||
of lease liabilities: |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Operating cash flows for operating lease |
| $ | 49 |
|
| $ | 44 |
|
| $ | 148 |
|
| $ | 130 |
|
Operating cash flows for finance leases |
| $ | 0 |
|
| $ | 0 |
|
| $ | 0 |
|
| $ | 4 |
|
Financing cash flows for finance leases |
| $ | 0 |
|
| $ | 5 |
|
| $ | 0 |
|
| $ | 17 |
|
As of September 30, 2020,2021, maturities of lease liabilities for the periods indicated were as follows:
September 30, | Operating Lease | Financing Leases | Total |
(in thousands) | |||
| 2021 | $190 | $61 | $251 |
| 2022 | 209 | - | 209 |
| 2023 | 212 | - | 212 |
$611 | $61 | $672 | |
September 30, |
| Operating Lease |
| |
|
| (in thousands) |
| |
|
|
|
| |
2021 |
| $ | 209 |
|
2022 |
|
| 211 |
|
2023 |
|
| 0 |
|
|
|
|
|
|
|
| $ | 420 |
|
Blue Dolphin Energy Company | September 30, 2021 │Page 31 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Future minimum annual lease commitments that are non-cancelable:
Operating | |
| September 30, | Lease |
(in thousands) | |
| 2021 | $232 |
| 2022 | 236 |
| 2023 | 220 |
$688 |
|
| Operating |
| |
September 30, |
| Lease |
| |
|
| (in thousands) |
| |
2021 |
| $ | 236 |
|
2022 |
|
| 220 |
|
2023 |
|
| 0 |
|
|
| $ | 456 |
|
(14)
Tax Provision
The provision for income tax benefit (expense)expense for the periods indicated was as follows:
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| Current | ||||
| Federal | $- | $- | $(15) | $- |
| State | - | - | - | - |
| Deferred | ||||
| Federal | 975 | (1,833) | 2,566 | (1,190) |
| State | - | - | ||
| Change in valuation allowance | (975) | 1,833 | (2,566) | 1,190 |
| Total provision for income taxes | $- | $- | $(15) | $- |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
Current |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Federal |
| $ | 0 |
|
| $ | 0 |
|
| $ | 0 |
|
| $ | (15 | ) |
State |
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
|
| 0 |
|
Deferred |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal |
|
| 615 |
|
|
| 975 |
|
|
| 1,782 |
|
|
| 2,566 |
|
State |
|
| 0 |
|
|
|
|
|
|
| 0 |
|
|
|
|
|
Change in valuation allowance |
|
| (615 | ) |
|
| (975 | ) |
|
| (1,782 | ) |
|
| (2,566 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total provision for income taxes |
| $ | 0 |
|
| $ | 0 |
|
| $ | 0 |
|
| $ | (15 | ) |
GAAP treats TMT is treated aslike an income tax for financial reporting purposes.
Deferred income taxes as of the dates indicated consisted of the following:
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Deferred tax assets: | ||
| NOL and capital loss carryforwards | $14,854 | $12,463 |
| Business interest expense | 2,995 | 1,923 |
| Start-up costs (crude oil and condensate processing facility) | 530 | 594 |
| ARO liability/deferred revenue | 501 | 539 |
| AMT credit | - | 50 |
| Other | 1 | 11 |
| Total deferred tax assets | 18,881 | 15,580 |
| Deferred tax liabilities: | ||
| Basis differences in property and equipment | (6,968) | (6,183) |
| Total deferred tax liabilities | (6,968) | (6,183) |
11,913 | 9,397 | |
| Valuation allowance | (11,913) | (9,347) |
| Deferred tax assets, net | $- | $50 |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Deferred tax assets: |
|
|
|
|
|
| ||
NOL and capital loss carryforwards |
| $ | 16,646 |
|
| $ | 15,258 |
|
Business interest expense |
|
| 4,335 |
|
|
| 3,343 |
|
Start-up costs (crude oil and condensate processing facility) |
|
| 445 |
|
|
| 509 |
|
ARO liability/deferred revenue |
|
| 498 |
|
|
| 498 |
|
Other |
|
| 3 |
|
|
| 3 |
|
Total deferred tax assets |
|
| 21,927 |
|
|
| 19,611 |
|
|
|
|
|
|
|
|
|
|
Deferred tax liabilities: |
|
|
|
|
|
|
|
|
Basis differences in property and equipment |
|
| (7,765 | ) |
|
| (7,230 | ) |
Total deferred tax liabilities |
|
| (7,765 | ) |
|
| (7,230 | ) |
|
|
| 14,162 |
|
|
| 12,381 |
|
|
|
|
|
|
|
|
|
|
Valuation allowance |
|
| (14,162 | ) |
|
| (12,381 | ) |
|
|
|
|
|
|
|
|
|
Deferred tax assets, net |
| $ | 0 |
|
| $ | 0 |
|
Blue Dolphin Energy Company | September 30, 2021 │Page 32 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Deferred Income Taxes
Balances for deferred income tax balances reflectrepresent the effects of temporary differences between the carrying amounts and the actual income tax basis of our assets and liabilities and their tax basis, as well as fromliabilities; the balances also reflect NOL carryforwards. We state thoserecord the balances at the enactedbased on tax rates we expect willto 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 ofNOL Carryforwards
. NOL carryforwards thatNet 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 | - | 11,384 | 11,384 |
| Balance at September 30, 2020 | $9,614 | $54,442 | $64,056 |
|
| Net Operating Loss Carryforward |
|
|
|
| ||||||
|
| Pre-Ownership Change |
|
| Post-Ownership Change |
|
| Total |
| |||
|
| (in thousands) |
| |||||||||
|
|
|
|
|
|
|
|
|
| |||
Balance at December 31, 2019 |
|
| 9,614 |
|
|
| 43,058 |
|
|
| 52,672 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net operating losses |
|
| 0 |
|
|
| 13,306 |
|
|
| 13,306 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2020 |
| $ | 9,614 |
|
| $ | 56,364 |
|
| $ | 65,978 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net operating losses |
|
| 0 |
|
|
| 8,331 |
|
|
| 8,331 |
|
Expiration of net operating losses |
|
| (1,718 | ) |
|
| 0 |
|
|
| (1,718 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at September 30, 2021 |
| $ | 7,896 |
|
| $ | 64,695 |
|
| $ | 72,591 |
|
Valuation Allowance
. As of each reporting date, management considers new evidence, both positive and negative, to determine the realizability of deferred tax assets.We have NOL carryforwards that remain available for future use. At September 30, 2021, and December 31, 2020, there were no uncertain tax positions for which a reserve or liability was necessary.
Blue Dolphin Energy Company | September 30, 2021 │Page 33 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(15)
A reconciliation between basic and diluted income per share for the periods indicated was as follows:
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| Net income (loss) | $(4,653) | $8,167 | $(12,235) | $5,615 |
| Basic and diluted income (loss) per share | $(0.37) | $0.74 | $(0.98) | $0.51 |
| Basic and Diluted | ||||
| Weighted average number of shares of | ||||
| common stock outstanding and potential | ||||
| dilutive shares of common stock | 12,693,514 | 10,975,514 | 12,534,493 | 10,975,215 |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands, |
|
| (in thousands, |
| ||||||||||
|
| except share and per share amounts) |
|
| except share and per share amounts) |
| ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
Net loss |
| $ | (2,929 | ) |
| $ | (4,653 | ) |
| $ | (10,202 | ) |
| $ | (12,235 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted loss per share |
| $ | (0.23 | ) |
| $ | (0.37 | ) |
| $ | (0.80 | ) |
| $ | (0.98 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of shares of |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
common stock outstanding and potential |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
dilutive shares of common stock |
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,693,514 |
|
|
| 12,534,493 |
|
Diluted EPS is computed by dividing net income available to common stockholders by the weighted average number of shares of common stock outstanding. Diluted EPS for the three and nine months ended September 30, 20202021, and 20192020 was the same as basic EPS as there wereEPS; no stock options or other dilutive instruments were outstanding.
(16)
Amended and Restated Operating Agreement
See “Note (3)” to our consolidated financial statements for additional disclosures related to the operation and management of all Blue Dolphin properties by an Affiliate under the Amended and Restated Operating Agreement.
BSEE Offshore Pipelines and Platform Decommissioning
BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations.active. Until such structuresfacilities are abandoned or removed,decommissioned, lessees and rights-of-way holders are required tomust inspect and maintain the assets in accordance withthem per regulatory requirements.
In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE onin August 15, 2019 to address BDPL’s plans with respect toconcerning decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning along withand a safe boarding plan for the platform, withinplatform. BSEE imposed a deadline of six (6) months (no later than February 15,(February 2020), to submit the permit applications and develop and implement a safe boarding plan for submission with such permit applications.plan. Further, BSEE proposed thatmandated BDPL complete approved, permitted work within twelve (12) months (no later than August 15,(August 2020). BDPL timely submitted the permit applications for decommissioning of the subject offshore pipelines and platform assetssafe boarding plan to BOEM and BSEE on February 11, 2020 and2020; we submitted related permits to the USACOE on March 25, 2020. Decommissioning of theAlthough we planned decommissioning activities for 2020, offshore pipelinesweather conditions and platform assets is on hold due to financialcash constraints associated with COVID-19. We are also awaiting approval of regulatory permits on certain segments and/or fairways, which approvals are required priorthe ongoing COVID-19 pandemic led to work commencement.delays. We cannot currently estimate when decommissioning maywill occur.
In April 2020, BSEE issued another INC to BDPL for failure to perform the required structural surveys for the GA-288C Platform. BDPL requested an extension to comply with the INC, related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platformBDPL completed the structural surveys were completed, and resolved the INC was resolved in June 2020.
Financial constraints do not relieve BDPL of its obligations to remedy the BSEE INCs or of BSEE’s authority to impose financial penalties. If BDPL fails to complete decommissioning of the offshore pipelines and platformfacilities assets and/or remedy the INCs within a timeframe determined to bedeemed prudent by BSEE, BDPL could be subject to regulatory oversight and enforcement, including but not limited to failure to correct an INC, civil penalties, and revocation of BDPL’s operator designation, whichdesignation. Such BSEE actions could 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 September 30, 2020.2021. At both September 30, 20202021, and December 31, 2019,2020, BDPL maintained $2.4 million and $2.6 million, respectively, in AROs related to abandonment ofdecommissioning these assets.
Defaults Under Secured Loan Agreements with Third Parties
See “Note“Notes (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.
Blue Dolphin Energy Company | September 30, 2021 │Page 34 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Financing Agreements and Guarantees
Indebtedness
. SeeGuarantees
. Affiliates provided guarantees on certainHealth, Safety and Environmental Matters
The operations of certain Blue Dolphin subsidiaries 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. OurThese operations also require numerous permits and authorizations under various environmental, health, and safety laws and regulations. Failure to obtain and comply with these permits or environmental, health, or safety laws generally could result in fines, penalties, or other sanctions, or a revocation of our permits.
Legal Matters
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
.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.rights-of-way. BDPL historically maintained $0.9 million in financial security. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Because the IBLA granted multiple extension requests that extendedis separate and independent from the agencies whose decisions it reviews, BDPL’s deadline for filing a statement of reasons forappeal to BOEM took considerable time to matriculate through the appeal withappeals process. Ultimately, the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that, BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. Decommissioning of these assets will significantly reduce or eliminateonce BDPL completes abandonment operations, the amount of financial assurance required by BOEM which may serve towill be significantly reduced or eliminated. In addition, BOEM’s INCs will be partially or fully resolveresolved. Although we planned decommissioning activities for 2020, offshore weather conditions and cash constraints associated with the INCs. See “Note (16) – BSEE Offshore Pipelinesongoing COVID-19 pandemic led to delays. We cannot currently estimate when decommissioning will occur. Further, we cannot currently estimate when we can provide additional financial assurance (supplemental pipeline bonds).
Financial constraints and Platform Decommissioning”.
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 September 30, 2020.2021. At both September 30, 20202021, and December 31, 2019,2020, 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 debt and office lease payment defaults, mechanic’s liens, contract-related disputes, and administrative proceedings. Management(17) Subsequent Event
NPS Term Loan Due 2031
NPS entered into a Loan Agreement with Greater Nevada Credit Union, as lender (“Lender”), for a term loan in the aggregate principal amount of Unregistered Securities)
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Notes to Consolidated Financial Statements |
NPS secured the NPS Loan by a deed of trust lien on approximately 56 acres of land and improvements owned by LE in Wilson County, Texas, a leasehold deed of trust lien on certain property leased by NPS from LE, an assignment of leases and rents, and certain personal property. The NPS Loan contains various customary terms and conditions, including representations and warranties, affirmative and negative covenants respecting the business of the parties to the NPS Loan, financial covenants respecting debt service coverage ratio, ratio of debt to net worth and ratio of current assets to current liabilities, and events of default.
NPS Repayment of Line of Credit Payable
On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. The payoff, which totaled approximately $5.0 million, included all outstanding principal and accrued interest . As a result of the payoff, the loan agreement and associated pledge agreement, subordination agreement, and guaranty agreement were terminated.
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Management’s Discussion and Analysis | ||||
ITEM 2.
Management’s Discussion and Analysis isprovides 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. Youprojected. Investors 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 the related notes included theretocontained in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 2020, and ourQuarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2020 2021, and June 30, 2020.
Overview
Blue Dolphin was formed in 1986 as a Delaware corporation. The company is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operateOperations primarily consist of a light sweet-crude, 15,000-bpd crude distillation tower, with more thanand approximately 1.2 million bbls of petroleum storage tank capacity in Nixon, Texas. Our assetsBlue Dolphin trades on the OTCQX under the ticker symbol “BDCO.”
Assets are primarily organized in two segments: refinery operations‘refinery operations’ (owned by LE) and tolling‘tolling and terminaling servicesservices’ (owned by LRM and NPS). Active subsidiaries that are reflected in corporate‘Corporate and other includeother’ includes 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 forFor more information related to our business segments, and properties.see “Part I, Item 1. Financial Statements – Note (4)”.
Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours,” refer to Blue Dolphin, was formed in 1986one or more of Blue Dolphin’s subsidiaries, or all of them taken as a Delaware corporation and is traded on the OTCQX under the ticker symbol “BDCO”.
Affiliates
Affiliates controlcontrolled approximately 82% of the voting power of our Common Stock.Stock as of the filing date of this report. An Affiliate operates and manages all Blue Dolphin properties and has historically fundedfunds working capital requirements during periods of working capital deficits, anddeficits. In addition, 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“Part I, Item 1. Financial Statements – 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
General Business Environment. In early 2020, global and national measures taken to address the COVID-19 pandemic, including government-imposed temporary business closures and voluntary shelter-at-home directives, caused oil prices to decline sharply. In addition, actions by members of OPEC and other producer countries in 2020 concerning oil production and pricing significantly impacted supply and demand in global oil and gas markets. With the introduction and approval of COVID-19 vaccines and increased inoculation rates, global economic activity has shown signs of recovery in 2021.
Our Business. Current EIA forecasts show economic growth and mobility increases in the short term. Also, refinery margins are forecasted to improve during the winter months due to projected colder winter temperatures compared to 2020 and low distillates inventory levels. However, forecasts are subject to various factors that are subject to change, including the ongoing impact of COVID-19 and related variants. Management continues to take steps to mitigate risk, avoid business disruptions, manage cash flow, and remain competitive in a volatile commodity price environment. Mitigation steps include: adjusting throughput and production based on market conditions, optimizing receivables and payables by prioritizing payments, managing inventory to avoid buildup, delaying capital spending, and monitoring discretionary spending and nonessential costs. To safeguard personnel, we adopted remote working where possible and social distancing, mask-wearing, and other site-specific precautionary measures where on-site operations are required. We also incentivize personnel to receive the COVID-19 vaccine.
We can provide no guarantees that: our business strategy will be successful, Affiliates will continue to proactively address the known impacts of COVID-19. Facility-dependent personnel, including those neededfund our working capital needs when we experience working capital deficits, we will meet regulatory requirements to maintain the Nixon facility, are reportingprovide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, we will be able to the facility under strict protocols that are designed to ensure personnel health and safety. We are also supporting non-facility-dependent personnel through remote work and virtual meeting technology, and we are encouragingobtain additional financing on commercially reasonable terms or at all, personnel to follow local guidance. All non-essential business travel and attendance at conferences, trainings, and other gatherings have been suspended.
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Management’s Discussion and Analysis | ||||
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
Third-Party Defaults
· | Veritex Loans – For both three-month periods ended September 30, 2021, and 2020, principal and interest payments to Veritex totaled $0. For the nine-months ended September 30, 2021, and 2020, principal and interest payments to Veritex totaled $0 and $0.3 million, respectively. As of the filing date of this report, LE and LRM were in default related to required monthly payments under the LE Term Loan Due 2034 and LRM Term Loan Due 2034. Defaults under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 permit Veritex to declare the amounts owed under these loan agreements immediately due and payable, exercise its rights concerning collateral securing obligors’ obligations under these loan agreements, and exercise any other rights and remedies available. Any exercise by Veritex of its rights and remedies under these 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. These adverse market actions could lead to holders of our common stock losing their investment in its entirety. We cannot assure investors that: (i) our assets or cash flow will be sufficient to repay borrowings under our secured loan agreements with Veritex fully, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, or (iii) Veritex, as first lien holder, will provide future default waivers. Borrowers and Veritex maintain ongoing dialogue regarding potential restructuring and refinance opportunities related to this debt. |
· | Amended Pilot Line of Credit – On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. However, NPS was in default as of September 30, 2021, and December 31, 2020, for failure of the borrower or any guarantor to pay past-due obligations when due. The debt, which accrued interest at a default rate of fourteen percent (14%) per annum, was classified within the current portion of long-term debt on our consolidated balance sheets at September 30, 2021, and December 31, 2020. |
| Due to NPS’ default under the Amended Pilot Line of Credit, Pilot applied payments owed to NPS under two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of Credit from June 2020 to September 2021. For both three-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $0.6 million. For the nine-month periods ended September 30, 2021, and 2020, the tank lease payment setoff totaled $1.7 million and $0.8 million, respectively. | |
| The amount of interest NPS incurred under the Amended Pilot Line of Credit totaled $0.2 million and $0.4 million, respectively, for the three months ended September 30, 2021, and 2020. For the nine months ended September 30, 2021, and 2020, interest was $0.7 million and $1.1 million, respectively. See “Part I, Item 1. Financial Statements – Note (11)” and “Note (17)” to our consolidated financial statements for more information related to the Amended Pilot Line of Credit. | |
· | Kissick Debt – Under a 2015 subordination agreement, John Kissick agreed to subordinate his 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 LE Term Loan Due 2034. To date, LE has made no payments under the subordinated Kissick Debt. Mr. Kissick has taken no action due to the non-payment. |
Related-Party Defaults under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 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. Veritex exercising its rights would also adversely impact the trading price of our common stock and the value of an investment in our common stock, which could lead to holders of our common stock losing their investment 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. The borrowers continue in active dialogue with Veritex.
As of the filing date of this report, paymentsBlue Dolphin was in default concerning past due payment obligations under the Veritex loans were current, but other defaults remain outstanding as noted in the table above.
Substantial Current Debt
As of September 30, 2021, and December 31, 2020, we had current debt of $58.4 million and $57.7 million, respectively, consisting of bank debt, related party debt, which is currently in default, represents such working capital borrowings.
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Management’s Discussion and Analysis |
Margin Volatility. Our refining margins generally improve in an environment of higher crude oil and refined product prices, demand, and production levelswhere the spread between crude oil prices and refined product prices widens. In early 2020, global and national measures taken to address the COVID-19 pandemic, including government-imposed temporary business closures and voluntary shelter-at-home directives, caused oil prices to decline sharply. Governmental mandatesIn addition, actions by members of OPEC and other producer countries in 2020 concerning oil production and pricing significantly impacted supply and demand in global oil and gas markets. With the introduction and approval of COVID-19 vaccines and increased inoculation rates, global economic activity has shown signs of recovery in 2021. Current EIA forecasts show economic growth and mobility increases in the short term. Also, refinery margins are forecasted to slowimprove during the spread of the virus included travel restrictions, stay-at-home orders, and public gathering bans. Beginning late in the
Historic Net Losses and Working Capital Deficits
.Net Losses
Net loss for the three months ended September 30, 20202021, was $2.9 million, or a loss of $0.23 per share, compared to a net loss of $4.7 million, or a loss of $0.37 per share, compared to net income of $8.2 million, or income of $0.74 per share, forduring the three months ended September 30, 2019. The increase in net loss was the result of less favorable margins per bbl and lower sales volume in the three-month period ended September 30, 2020 compared to the three-month period ended September 30, 2019.2020. Net loss for the nine months ended September 30, 20202021, was $10.2 million, or a loss of $0.80 per share, compared to a net loss of $12.2 million, or a loss of $0.98 per share, compared to net income of $5.6 million, or income of $0.51 per share, for the nine months ended September 30, 2019.2020. The significant increaseimprovement between both comparative periods resulted from demand recovery, commodity price improvements, and encouraging trends in net loss was the result of less favorable margins per bbl and lower sales volume in the nine-month period ended September 30, 2020 compared to the same period a year earlier. Both the three- and nine-month periods ended September 30, 2019 included a gain on the extinguishment of debt of $9.1 million.
Working Capital Deficits
We had a$79.8 million and $72.3 million in working capital deficit of $70.6 million and $59.4 milliondeficits at September 30, 20202021, and December 31, 2019,2020, respectively. Excluding the current portion of long-term debt, we had a$26.2 million and $22.6 million in working capital deficit of $24.8deficits at September 30, 2021, and December 31, 2020, respectively.
Cash and cash equivalents totaled $2.2 million and $19.6$0.5 million at September 30, 20202021, and December 31, 2019,2020, respectively. We had cash and cash equivalents and restrictedRestricted cash (current portion) of $0.3 million andtotaled $0.05 million respectively,at both September 30, 2021, and December 31, 2020. Restricted cash, noncurrent totaled $0 and $0.5 million at September 30, 2020. Comparatively, we had cash2021, and cash equivalents and restricted cash (current portion) of $0.07 million and $0.05 million, respectively, at December 31, 2019.
Our financial health has been materially and adversely affected by defaults in our secured loan agreements, margin volatility, and historical net losses and working capital deficits. If Pilot terminates the crude supply agreement or terminal services agreement, our ability to acquire crude oil and condensate could be adversely affected. If producers experience crude supply constraints and increased transportation costs, our crude acquisition costs may rise, or we may not receive sufficient amounts to meet our needs. During the three-month periods ended September 30, 2021, and 2020, our refinery experienced 6 days and 8 days of downtime, respectively, due to crude deficiencies associated with COVID-19 related cash constraints. During the nine-month periods ended September 30, 2021, and 2020, our refinery experienced 11 days and 16 days of downtime, respectively.
Operating Risks
Successful execution of our business strategy depends on several keycritical factors, including having adequate working capital to meet contractual, operational, needsregulatory, and regulatory requirements, maintaining safe and reliable operations at the Nixon facility, meeting contractual obligations,safety needs and having favorable margins on refined products. As discussed under “Going Concern” within this Management’s Discussion and Analysis of Financial Condition and Results of Operations and throughout this report, weWe are currently unable to estimate the impact the COVID-19 pandemic will have on our future financial position and results of operations. Under earlierEarlier state and federal mandates that regulated business closures due to COVID-19 deemed our business was deemed as an essential, business and as such, haswe remained open. As U.S. federal, state, and local officials contemplate renewedIf future restrictive mandates due to resurging coronavirus cases,directives become necessary, we expect to continue operating. However, suchadditional governmental mandates while necessary to address the virus, will likely result in further business and operational disruptions, including demand destruction, liquidity strains, supply chain challenges, travel restrictions, controls on in-person gathering, and workforce availability.
Management believes that it has taken all prudentcontinues to take steps to mitigate risk, avoid business disruptions, manage cash flow, and remain competitive in a low oilvolatile commodity price environment. Steps include managing cash flow byMitigation steps include: adjusting throughput and production based on market conditions, optimizing receivables and payables by prioritizing payments, managing inventory to avoid buildup, monitoring discretionary spending, and delaying capital expenditures. However, thereTo safeguard personnel, we adopted remote working where possible and social distancing, mask-wearing, and other site-specific precautionary measures where on-site operations are required. We also incentivize personnel to receive the COVID-19 vaccine.
We can beprovide no assurance thatguarantees 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 theirexercises its rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
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Business Strategy
Our primary business objective is to improve our financial profile by executing the uncertainty surroundingbelow strategies, modified as necessary, to reflect changing economic conditions and other circumstances:
Optimize Existing Asset Base | • Operate safely and enhance health, safety, and environmental systems. • Planning and managing turnarounds and downtime. | ||
Improve Operational Efficiencies | • Reduce or streamline variable costs incurred in production. • Increase throughput capacity and optimize product slate. • Increase tolling and terminaling revenue. | ||
Seize Market Opportunities | • Leverage existing infrastructure to engage in renewable energy projects. • Take advantage of market opportunities as they arise. |
Optimize Existing Asset Base. Throughout the COVID-19 pandemic, which has weakened the commodity price environment,third quarter of 2021, we remain focused onmaintained safe and reliable operations and cash conservation.
Improve Operational Efficiencies. Refinery throughput, production, and sales continued to improve year to date 2021 compared to 2020. Management process reviews led to improved efficiencies in inventory management, throughput and production levels, and cash management.
Seize Market Opportunities. We continue to explore renewable energy growth opportunities through commercial partnerships and repurposing our assets and facilities. In March 2021, we announced a pivot to explore renewable energy opportunities through an affiliate, Lazarus Energy Alternative Fuels LLC (“LEAF”). LEAF will explore potential options to position Blue Dolphin in the global oil markets,transition to cleaner, lower-carbon alternatives from traditional fossil fuels through collaboration and it is currently difficult to accurately forecast and plan future business activities. There can be no assurance thatinnovation.
Successful execution of our business strategy depends on several factors. These factors include (i) having adequate working capital to meet operational needs and regulatory requirements, (ii) maintaining safe and reliable operations at the Nixon facility, (iii) meeting contractual obligations, (iv) having favorable margins on refined products, and (v) collaborating with new partners to develop and finance clean energy projects. Our business strategy involves risks. Accordingly, we cannot assure investors that our plans will be successful, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. If Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
We regularly engage in discussions with third parties regarding possible joint ventures, asset sales, mergers, and other potential business combinations. However, we do not anticipate any material activities in the possible purchase of assets and operations that are strategic and complementary to our existing operations or to explore new business opportunities. As noted above, management hasforeseeable future. Management 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 historichistorical net losses and working capital deficits. A ‘going concern’ opinion could impairimpairs our ability to finance our operations through the sale ofby selling equity, incurring debt, or other financing alternatives. Our ability to continue as a going concern will dependdepends 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.long-term debt. If we are unable tocannot achieve these goals, our business would be jeopardized, and we may have
Downstream Operations
Our refinery operations business 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 |
Crude Oil and Condensate Supply
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Pilot also stores crude oil at the Nixon facility under two terminal services agreements. Under the terminal services agreements, Pilot stores crude oil at the Nixon facility at a specified rate per bbl of the storage tank’s shell capacity. Although the initial term of the terminal services agreement expired April 30, 2020, the agreement renewedrenews 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 behas been materially and adversely affected by defaults in our secured loan agreements, margin deteriorationvolatility, and volatility, historichistorical net losses and working capital deficits, as well as termination ofdeficits. If Pilot terminates the crude supply agreement or terminal services agreement, with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, sustained periods of lowcondensate could be adversely affected. If producers experience crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. A failurecosts, our crude acquisition costs may rise, or we may not receive sufficient amounts to acquire crude oil and condensate when needed will have a material effect onmeet our business results and operations.needs. During the three-three-month periods ended September 30, 2021, and 2020, our refinery experienced 6 days and 8 days of downtime, respectively, due to crude deficiencies associated with COVID-19 related cash constraints. During the nine-month periods ended September 30, 2021, and 2020, our refinery experienced 11 days and 16 days of downtime, as a resultrespectively.
Due to NPS’ default under the Amended Pilot Line of lackCredit, Pilot applied payments owed to NPS under two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of crude dueCredit from June 2020 to cash constraints.
The amount of interest NPS incurred under the Amended Pilot Line of Credit totaled $0.2 million and $0.4 million, respectively, for the three months ended September 30, 2021, and 2020. For the nine months ended September 30, 2021, and 2020, interest was $0.7 million and $1.1 million, respectively. See “Part I, Item 1. Financial Statements – Note (1) Organization – Going Concern,” “Note (11) Line of Credit Payable,” and “Note (17) Subsequent Events” to our consolidated financial statements for additional disclosures related to the Amended Pilot Line of Credit.
Products and Markets
. Our market is the Gulf Coast region of the U.S., whichThe Nixon refinery’s product slate is moderately adjusted based on current market demand. We currently produce a single finished product – jet fuel – and several intermediate products, including naphtha, HOBM, and AGO. OurWe sell our jet fuel is sold to an Affiliate, which is HUBZone certified. The product sales agreement with the Affiliate has a 1-year term expiring the earliest to occur of March 31, 2022, plus 30-day carryover or delivery of the maximum quantity of jet fuel. 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.
Customer
s.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 requireCompetition
.Many of our competitors are substantially larger thanSafety and Downtime
.The Nixon refinery periodically experiences planned and unplanned temporary shutdowns. We use planned turnarounds to repair, restore, refurbish, or replace refinery equipment. Unplanned shutdowns can occur for a variety ofvarious reasons, including voluntary regulatory compliance measures, cessation or suspension by regulatory authorities, disabled equipment, or disabled equipment.crude deficiencies due to cash constraints. However, in Texas the most typical reason is excessive heat or power outages from high winds and thunderstorms. Planned t
We are particularly vulnerable to operation disruptions in our operations because all our refining operations are conductedoccur at a single facility. Any scheduled or unscheduled downtime will resultresults in lost margin opportunity, reduced refined products inventory, and potential increased maintenance expense, and a reductionall of refined products inventory, which could reduce our ability to meet our payment obligations.
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Midstream Operations
Our tolling and terminaling business 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 |
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. StorageOperations Safety
.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 operationaloperational. We account for these inactive operations in ‘corporate 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 |
Pipeline and Facilities Safety
.Although our pipeline and facility assets are inactive, they require upkeep and maintenance andmaintenance. They are also subject to safety regulationsrequirements 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.
Results of Operations
We present below a discussion and analysis of the factors contributing to our consolidated financial results of operations is presented below. Theoperations. Investors should read this section in conjunction with our financial statements togetherin “Part I, Item 1. Financial Statements”. When combined with the following information, are intended tothe financial statements provide investors with a reasonable basis for assessing our historical operations, but theyoperations. However, this information should not serve as the only criteria for predicting our future performance.
Major Influences on Results of Operations
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How We Evaluate Our Operations
. Management usesSegment Contribution Margin (Deficit) and Refining Gross Profit (Deficit) per Bbl
We use segment contribution margin (deficit) is used to evaluate both refinery operationsthe performance of our downstream and tolling and terminaling whilemidstream operations. We use refining gross profit (deficit) per bbl isas a refinery operationsdownstream benchmark. Both measures supplement ourGAAP financial information presented in accordance with U.S. GAAP.presented. Management uses these non-GAAP measuressegment contribution margin (deficit) and refining gross profit (deficit) per bbl 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 ofconsidering potential capital investments. Non-GAAPThese non-GAAP measures have important limitations as analytical tools. These non-GAAP measures, which are defined in our glossary of terms,They 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 financial results. See “Non-GAAPthe “Glossary of Terms” for information on how to calculate these non-GAAP measures. See also “Results of Operations – Non-GAAP Reconciliations” within this “Item 2.”section and the financial statements within “Item“Part I, Item 1.” Financial Statements” for a reconciliation of these 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, management uses 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
Operation costs and utility costs. Expenses for refinery operations generally remain stable across broad rangesexpenses include cost of throughput volumes, but they can fluctuate from period to period depending ongoods sold. Also, operation costs and expenses within: (i) 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
Our refinery operations business segment primarilyrevenue depends on the volumes of crude oil andthroughput volumes, refined products that we handle through our processing assetsproduction volumes, and the volume sold to customers. These volumes are affected by thecustomer sales volumes. 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 resultresults in lost margin opportunity, reduced refined products inventory, and potential increased maintenance expense, and a reductionall of refined products inventory, which could reduce our ability to meet our payment obligations.
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Consolidated Results
.Our consolidated results of operations include certainThree Months Ended September 30, 2020) | Nine Months Ended September 30, 2021 Versus September 30, 2020 (9 Months 2021 Versus 9 Months 2020) | |||
Overview. Net loss for Q3 | Overview. Net loss for 9 Months 2021 was $10.2 million, or a loss of $0.80 per share, compared to a net periods. | |||
Total Revenue from Operations. Total revenue from operations higher refined product prices, sales volume, and ancillary service fees (tank blending, lab testing, etc.). The increase was offset by lower tank rental revenue. | Total Revenue from Operations. Total revenue from operations increased significantly in 9 Months 2021 to $209.2 million compared to $123.4 million in 9 Months 2020. The increase between the periods related to higher refined product prices, sales volume, and ancillary service fees. The increase was offset by lower tank rental revenue. | |||
Total Cost of Goods Sold. Total cost of goods sold | Total Cost of Goods Sold. Total cost of goods sold increased significantly in 9 Months 2021 to $210.2 million compared to | |||
Gross Profit. Gross profit was $0.3 million for Q3 | Gross Deficit. Gross deficit improved significantly in 9 Months 2021 to $1.0 million compared to improvement resulted from more stable commodity prices and improved sales volumes from economic recovery. | |||
General and Administrative Expenses. General and administrative expenses were relatively flat at $0.7 million for both Q3 2020 due to cost management efforts. | General and Administrative Expenses. General and administrative expenses were relatively flat at $1.9 million for both 9 Months 2021 and 9 Months 2020 due to cost management efforts. | |||
Depletion, Depreciation, and Amortization. Depletion, depreciation, and amortization expenses were flat at $0.7 million for Q3 2021 and Q3 2020. Depletion, depreciation, and amortization expense primarily related to refinery assets. | Depletion, Depreciation, and Amortization. Depletion, depreciation, and amortization expenses totaled $2.1 million for 9 Months 2021 compared to $2.0 million for 9 Months 2020, | |||
Total Other Expense. Total other expense increased slightly in Q3 2021 to $1.7 million compared to | Total Other Expense. Total other |
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Downstream Operations
.Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| (in thousands) | ||||
| Refined product sales | $41,929 | $77,537 | $120,185 | $222,652 |
| Less: Total cost of goods sold | (44,400) | (76,229) | (126,164) | (220,301) |
| Gross profit (deficit) | (2,471) | 1,308 | (5,979) | 2,351 |
| Sales (Bbls) | 1,021 | 1,181 | 2,818 | 3,314 |
| Gross Profit (Deficit) per Bbl | $(2.42) | $1.11 | $(2.12) | $0.71 |
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
(in thousands) | ||||
Net revenue (1) | $41,929 | $77,537 | $120,185 | $222,652 |
| Intercompany fees and sales | (595) | (668) | (1,618) | (1,927) |
| Operation costs and expenses | (43,691) | (76,088) | (124,942) | (219,766) |
| Segment Contribution Margin (Deficit) | $(2,357) | $781 | $(6,375) | $959 |
|
| Three Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
Refined product sales |
| $ | 79,466 |
|
| $ | 41,929 |
|
Less: Total cost of goods sold |
|
| (80,114 | ) |
|
| (44,400 | ) |
Gross deficit |
|
| (648 | ) |
|
| (2,471 | ) |
|
|
|
|
|
|
|
|
|
Sales (Bbls) |
|
| 1,059 |
|
|
| 1,008 |
|
|
|
|
|
|
|
|
|
|
Gross Deficit per Bbl |
| $ | (0.61 | ) |
| $ | (2.45 | ) |
|
| Three Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 79,466 |
|
| $ | 41,929 |
|
Intercompany fees and sales |
|
| (650 | ) |
|
| (595 | ) |
Operation costs and expenses |
|
| (79,593 | ) |
|
| (43,691 | ) |
Segment Contribution Deficit |
| $ | (777 | ) |
| $ | (2,357 | ) |
(1)
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
| Calendar | 92 | 92 | 274 | 273 |
| Operating | (81) | (90) | (237) | (253) |
| Refinery Downtime (Days) | 11 | 2 | 37 | 20 |
| Refinery Throughput | ||||
| bpd | 11,407 | 13,312 | 12,178 | 13,357 |
| bbls | 923,930 | 1,198,102 | 2,886,073 | 3,379,266 |
| Capacity utilization rate | 76.0% | 88.7% | 81.2% | 89.0% |
| Refinery Production | ||||
| bpd | 11,144 | 12,997 | 11,885 | 13,023 |
| bbls | 902,641 | 1,169,745 | 2,816,746 | 3,294,914 |
| Capacity utilization rate | 74.3% | 86.6% | 79.2% | 86.8% |
Q3 20202021 Versus Q3 2019
· | Refining gross deficit per bbl was $0.61 for Q3 2021 compared to gross deficit per bbl |
· | Segment contribution deficit improved significantly in Q3 2021 compared to Q3 2020 due to the aforementioned economic recovery and less refinery downtime. |
· | Refinery downtime decreased to 6 days in Q3 2021 compared to 11 days in Q3 2020. Refinery downtime in Q3 2021 related to crude deficiencies associated with cash constraints. Refinery downtime in Q3 2020 was due to crude deficiencies associated with cash constraints and equipment repairs. |
|
| Nine Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
Refined product sales |
| $ | 206,467 |
|
| $ | 120,185 |
|
Less: Total cost of goods sold |
|
| (210,203 | ) |
|
| (126,164 | ) |
Gross deficit |
|
| (3,736 | ) |
|
| (5,979 | ) |
|
|
|
|
|
|
|
|
|
Sales (Bbls) |
|
| 2,995 |
|
|
| 2,818 |
|
|
|
|
|
|
|
|
|
|
Gross Deficit per Bbl |
| $ | (1.25 | ) |
| $ | (2.12 | ) |
|
| Nine Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 206,467 |
|
| $ | 120,185 |
|
Intercompany fees and sales |
|
| (1,797 | ) |
|
| (1,618 | ) |
Operation costs and expenses |
|
| (208,936 | ) |
|
| (124,942 | ) |
Segment Contribution Deficit |
| $ | (4,266 | ) |
| $ | (6,375 | ) |
(1) Net revenue excludes intercompany crude due to cash constraints, and an equipment repair while refinery downtime in Q3 2019 primarily related to equipment repairs. Significant refinery downtime in Q3 2020 negatively impacted refinery throughput, refinery production, and capacity utilization rate.
9 Months 20202021 Versus 9 Months 2019
· | Refining gross deficit per bbl was $1.25 for 9 Months 2021 compared to gross deficit per bbl of $2.12 in 9 Months 2020, representing an improvement of $0.87 per bbl. The improvement between the periods related to higher refining margins and slightly higher sales volume. Commodity prices and refined product demand experienced a recovery in 9 Months 2021 compared to 9 Months 2020 as more businesses resumed operations and pandemic-related restrictions lifted. For 9 Months 2021, the impact of Winter Storm Uri offset the economic recovery. |
· | Segment contribution deficit improved significantly in 9 Months 2021 compared to 9 Months 2020 due to the above referenced economic recovery. However, the impact of Winter Storm Uri offset the economic recovery. |
· | Refinery downtime decreased to 21 days in 9 Months 2021 compared to 37 days in 9 Months 2020. Two material events triggered significant refinery downtime in 9 Months 2021 compared to 9 Months 2020: (i) power outages from Winter Storm Uri and (ii) COVID-19-related shutdowns and market upheavals. The extensive shutdown period resulted in cash constraints that further impacted the acquisition of crude oil. During the 9 Months 2020, we capitalized on downtime to perform a maintenance turnaround. |
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Midstream Operations. LRM and Terminaling
Three Months Ended | Nine Months Ended | |||
September 30, | September 30, | |||
2020 | 2019 | 2020 | 2019 | |
(in thousands) | ||||
Net revenue (1) | $1,001 | $1,096 | $3,214 | $3,253 |
| Intercompany fees and sales | 595 | 668 | 1,618 | 1,927 |
| Operation costs and expenses | (709) | (285) | (1,222) | (1,012) |
| Segment Contribution Margin (Deficit) | $887 | $1,479 | $3,610 | $4,168 |
|
| Three Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 924 |
|
| $ | 1,001 |
|
Intercompany fees and sales |
|
| 650 |
|
|
| 595 |
|
Operation costs and expenses |
|
| (521 | ) |
|
| (709 | ) |
Segment Contribution Margin |
| $ | 1,053 |
|
| $ | 887 |
|
(1)
Q3 20202021 Versus Q3 2019
· | Tolling and terminaling net revenue decreased nearly 8% in Q3 2021 compared to Q3 2020 primarily as a result of lower tank rental fees. |
· | Intercompany fees and sales, which reflect fees associated with an intercompany tolling agreement tied to naphtha volumes, increased in Q3 2021 compared to Q3 2020. Naphtha sales volumes increased between the periods as a result of demand recovery. |
· | Segment contribution margin in Q3 2021 increased nearly 19% to $1.1 million compared to $0.9 million Q3 2020. The improvement in segment contribution margin related to lower operation costs and expenses. |
|
| Nine Months Ended |
| |||||
|
| September 30, |
| |||||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 2,777 |
|
| $ | 3,214 |
|
Intercompany fees and sales |
|
| 1,797 |
|
|
| 1,618 |
|
Operation costs and expenses |
|
| (1,267 | ) |
|
| (1,222 | ) |
Segment Contribution Margin |
| $ | 3,307 |
|
| $ | 3,610 |
|
(1) Net revenue decreased nearly 9% in Q3 2020 compared to Q3 2019 primarily as a result of decreased fees collected for ancillary services, such as in-tank and tank-to-tank blending.
9 Months 20202021 Versus 9 Months 2019
· | Tolling and terminaling net revenue decreased nearly 14% in 9 Months 2021 compared to 9 Months 2020 due to lower tank rental fees. |
· | Intercompany fees and sales, which reflect fees associated with an intercompany tolling agreement tied to naphtha volumes, increased in 9 Months 2021 compared to 9 Months 2020. Naphtha sales volumes increased between the periods as a result of demand recovery. |
· | Segment contribution margin in 9 Months 2021 decreased 8% to $3.3 million compared to $3.6 million in 9 Months 2020. The decrease in segment contribution margin related to lower revenue. |
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Non-GAAP Reconciliations
.Reconciliation of Segment Contribution Margin (Deficit) |
Three Months Ended September 30, | ||||||||
2020 | 2019 | 2020 | 2019 | 2020 | 2019 | 2020 | 2019 | |
Refinery Operations | Tolling and Terminaling | Corporate and Other | Total | |||||
(in thousands) | ||||||||
| Segment contribution margin | $(2,357) | $781 | $887 | $1,479 | $(58) | $(52) | $(1,528) | $2,208 |
General and administrative expenses(1) | (414) | (292) | (132) | (68) | (307) | (295) | $(853) | $(655) |
| Depreciation and amortization | (301) | (481) | (338) | (99) | (51) | (52) | $(690) | $(632) |
| Interest and other non-operating income (expenses), net | (679) | 8,329 | (599) | (824) | (304) | (259) | $(1,582) | $7,246 |
| Income (loss) before income taxes | (3,751) | 8,337 | (182) | 488 | (720) | (658) | (4,653) | 8,167 |
| Income tax benefit | - | - | - | - | - | - | - | - |
| Income (loss) before income taxes | $(3,751) | $8,337 | $(182) | $488 | $(720) | $(658) | $(4,653) | $8,167 |
Nine Months September June 30, | ||||||||
2020 | 2019 | 2020 | 2019 | 2020 | 2019 | 2020 | 2019 | |
Refinery Operations | Tolling and Terminaling | Corporate and Other | Total | |||||
(in thousands) | ||||||||
| Segment contribution margin | $(6,375) | $959 | $3,610 | $4,168 | $(164) | $(165) | $(2,929) | $4,962 |
General and administrative expenses(1) | (1,045) | (898) | (268) | (173) | (1,052) | (833) | $(2,365) | $(1,904) |
| Depreciation and amortization | (883) | (1,429) | (956) | (297) | (153) | (129) | $(1,992) | $(1,855) |
| Interest and other non-operating income (expenses), net | (2,171) | 6,723 | (1,985) | (1,599) | (778) | (712) | $(4,934) | $4,412 |
| Income (loss) before income taxes | (10,474) | 5,355 | 401 | 2,099 | (2,147) | (1,839) | (12,220) | 5,615 |
| Income tax benefit | - | - | - | - | (15) | - | (15) | - |
| Income (loss) before income taxes | $(10,474) | $5,355 | $401 | $2,099 | $(2,162) | $(1,839) | $(12,235) | $5,615 |
|
| Three Months Ended September 30, |
| |||||||||||||||||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||||||
|
| Refinery Operations |
|
| Tolling and Terminaling |
|
| Corporate and Other |
|
| Total |
| ||||||||||||||||||||
|
| (in thousands) |
| |||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
Segment contribution margin (deficit) |
| $ | (777 | ) |
| $ | (2,357 | ) |
| $ | 1,053 |
|
| $ | 887 |
|
| $ | (83 | ) |
| $ | (58 | ) |
| $ | 193 |
|
| $ | (1,528 | ) |
General and administrative expenses(1) |
|
| (282 | ) |
|
| (414 | ) |
|
| (70 | ) |
|
| (132 | ) |
|
| (423 | ) |
|
| (307 | ) |
|
| (775 | ) |
|
| (853 | ) |
Depreciation and amortization |
|
| (302 | ) |
|
| (301 | ) |
|
| (340 | ) |
|
| (338 | ) |
|
| (51 | ) |
|
| (51 | ) |
|
| (693 | ) |
|
| (690 | ) |
Interest and other non-operating expenses, net |
|
| (747 | ) |
|
| (679 | ) |
|
| (384 | ) |
|
| (599 | ) |
|
| (523 | ) |
|
| (304 | ) |
|
| (1,654 | ) |
|
| (1,582 | ) |
Income (loss) before income taxes |
|
| (2,108 | ) |
|
| (3,751 | ) |
|
| 259 |
|
|
| (182 | ) |
|
| (1,080 | ) |
|
| (720 | ) |
|
| (2,929 | ) |
|
| (4,653 | ) |
Income tax expense |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
Income (loss) |
| $ | (2,108 | ) |
| $ | (3,751 | ) |
| $ | 259 |
|
| $ | (182 | ) |
| $ | (1,080 | ) |
| $ | (720 | ) |
| $ | (2,929 | ) |
| $ | (4,653 | ) |
(1)
|
| Nine Months Ended September 30, |
| |||||||||||||||||||||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||||||
|
| Refinery Operations |
|
| Tolling and Terminaling |
|
| Corporate and Other |
|
| Total |
| ||||||||||||||||||||
|
| (in thousands) |
| |||||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||
Segment contribution margin (deficit) |
| $ | (4,266 | ) |
| $ | (6,375 | ) |
| $ | 3,307 |
|
| $ | 3,610 |
|
| $ | (187 | ) |
| $ | (164 | ) |
| $ | (1,146 | ) |
| $ | (2,929 | ) |
General and administrative expenses(1) |
|
| (848 | ) |
|
| (1,045 | ) |
|
| (206 | ) |
|
| (268 | ) |
|
| (1,246 | ) |
|
| (1,052 | ) |
|
| (2,300 | ) |
|
| (2,365 | ) |
Depreciation and amortization |
|
| (906 | ) |
|
| (883 | ) |
|
| (1,020 | ) |
|
| (956 | ) |
|
| (153 | ) |
|
| (153 | ) |
|
| (2,079 | ) |
|
| (1,992 | ) |
Interest and other non-operating expenses, net |
|
| (2,053 | ) |
|
| (2,171 | ) |
|
| (1,284 | ) |
|
| (1,985 | ) |
|
| (1,340 | ) |
|
| (778 | ) |
|
| (4,677 | ) |
|
| (4,934 | ) |
Income (loss) before income taxes |
|
| (8,073 | ) |
|
| (10,474 | ) |
|
| 797 |
|
|
| 401 |
|
|
| (2,926 | ) |
|
| (2,147 | ) |
|
| (10,202 | ) |
|
| (12,220 | ) |
Income tax expense |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| (15 | ) |
|
| - |
|
|
| (15 | ) |
Income (loss) |
| $ | (8,073 | ) |
| $ | (10,474 | ) |
| $ | 797 |
|
| $ | 401 |
|
| $ | (2,926 | ) |
| $ | (2,162 | ) |
| $ | (10,202 | ) |
| $ | (12,235 | ) |
(1) General and administrative expenses within refinery operations include the LEH operating fee.
Liquidity and Capital Resources
We had $79.8 million and $72.3 million in working capital deficits at September 30, 2021, and December 31, 2020, respectively. Excluding the current portion of Page Intentionally Left Blank
Our primary cash requirements relate to: (i) purchasing crude oil and condensate for the operation of the Nixon refinery, (ii) reimbursing LEH for direct operating expenses and paying the LEH operating fee under the Amended and Restated Operating Agreement and (iii) servicing debt. In instances whereDue to the adverse financial impact of COVID-19, we experience a workingare actively exploring financing, including potential financing options made available under the Coronavirus Aid, Relief, and Economic Security Act, also known as the CARES Act. However, we cannot assure success in raising additional capital deficit, we have historically relied on Affiliates to meet our liquidity needs. While we believeor 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 financingsuch additional funds will be available to uson acceptable terms, if at all. We may further default on certain of our existing debt obligations if we cannot raise sufficient additional capital in the future on acceptable terms.
How long and to what extent COVID-19 and related market developments will continue to affect our business and operations is unknown. With the introduction and approval of $70.6 millionCOVID-19 vaccines and $59.4 million at September 30,increased inoculation rates, global economic activity has shown signs of recovery in 2021. Current EIA forecasts show economic growth and mobility increases in the short term. Also, refinery margins are forecasted to improve during the winter months due to projected colder winter temperatures compared to 2020 and December 31, 2019, respectively. Excludinglow distillates inventory levels. However, forecasts are subject to various factors that are subject to change, including the current portionongoing impact of long-term debt, we had a working capital deficit of $24.8 millionCOVID-19 and $19.6 million at September 30, 2020 and December 31, 2019, respectively. During the three and nine-month periods ended September 30, 2020, we received two small loans totaling $0.3 million in the aggregate under federal or other governmental programs to support our operations asrelated variants. As a result, of the COVID-19 pandemic.
Our ability to continue as a going concern depends on sustained positive operating margins and working capital to sustain operations, will depend on future developments, including, among other things, volatility in the global capital markets, the ultimate geographic spread and severitypurchase 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.
Blue Dolphin Energy Company | September 30, 2021 │Page 47 |
| Table of Contents |
September 30, | December 31, | |
2020 | 2019 | |
(in thousands) | ||
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | $22,424 | $21,776 |
LRM Term Loan Due 2034 (in default) | 9,299 | 9,031 |
Amended Pilot Line of Credit (in default) | 9,724 | 11,786 |
Notre Dame Debt (in default) | 9,214 | 8,617 |
| Related-Party Debt | ||
BDPL Loan Agreement (in default) | 6,654 | 6,174 |
March Ingleside Note (in default) | 1,067 | 1,004 |
March Carroll Note (in default) | 1,373 | 997 |
June LEH Note (in default) | 5,733 | - |
| LE Term Loan Due 2050 | 150 | - |
| NPS Term Loan Due 2050 | 150 | - |
| Total Debt | 65,788 | 59,385 |
| Less: Current portion of long-term debt, net | (55,438) | (51,301) |
| Less: Unamortized debt issue costs | (1,781) | (2,096) |
Less: Accrued interest payable (in default) | (8,269) | (5,988) |
$300 | $- | |
Management’s Discussion and Analysis |
Debt Overview.
Total Debt and Accrued Interest |
|
| September 30, |
|
| December 31, |
| ||
|
| 2021 |
|
| 2020 |
| ||
|
| (in thousands) |
| |||||
Veritex Loans |
|
|
|
|
|
| ||
LE Term Loan Due 2034 (in default) |
| $ | 23,827 |
|
| $ | 22,840 |
|
LRM Term Loan Due 2034 (in default) |
|
| 9,881 |
|
|
| 9,473 |
|
Kissick Debt (in default) |
|
| 10,011 |
|
|
| 9,413 |
|
Amended Pilot Line of Credit (in default) |
|
| 4,827 |
|
|
| 8,145 |
|
Related-Party Debt |
|
|
|
|
|
|
|
|
June LEH Note (in default) |
|
| 12,644 |
|
|
| 9,446 |
|
BDPL Loan Agreement (in default) |
|
| 7,294 |
|
|
| 6,814 |
|
March Carroll Note (in default) |
|
| 2,115 |
|
|
| 1,551 |
|
March Ingleside Note (in default) |
|
| 1,059 |
|
|
| 1,013 |
|
BDEC Term Loan Due 2051 |
|
| 507 |
|
|
| - |
|
LE Term Loan Due 2050 |
|
| 155 |
|
|
| 152 |
|
NPS Term Loan Due 2050 |
|
| 155 |
|
|
| 152 |
|
Equipment Loan Due 2025 |
|
| 59 |
|
|
| 71 |
|
Total debt and accrued interest |
|
| 72,534 |
|
|
| 69,070 |
|
|
|
|
|
|
|
|
|
|
Less: Current portion of long-term debt, net |
|
| (58,360 | ) |
|
| (57,744 | ) |
Less: Unamortized debt issue costs |
|
| (1,653 | ) |
|
| (1,749 | ) |
Less: Accrued interest payable (in default) |
|
| (11,678 | ) |
|
| (9,222 | ) |
Long-term debt, net of current portion |
| $ | 843 |
|
| $ | 355 |
|
Due to cash provided by financing activities was $3.5constraints associated with COVID-19, payments on debt in 2021 were minimal totaling $0.004 million in Q3 2021 and $0.013 million in 9 Months 2020 compared to $11.3 million in 9 Months 2019. Net proceeds from the issuance of debt was $0.3 million in 9 Months 2020 compared to $12.4 million in 9 Months 2019.
Debt Defaults
. The majority of our debt is in default. Defaults underContractual 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; reflects amounts owed to Jonathan Carroll |
March Ingleside Note (in default) | Ingleside Blue Dolphin | Debt | 03/31/2017 | 8.00% | Blue Dolphin working capital; matured 01/01/2019; interest still accruing |
June LEH Note (in default) | LEH Blue Dolphin | Debt | 03/31/2017 | 8.00% | Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; |
BDPL-LEH Loan 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 |
Blue Dolphin Energy Company | September 30, 2021 │Page 48 |
| Table of Contents |
Management’s Discussion and Analysis |
Related-Party Defaults
Loan Description | Event(s) of Default | Covenant Violations |
March Carroll Note (in default) | Failure of borrower to pay past due payment obligations; loan matured January 2019 | -- |
March Ingleside Note (in default) | Failure of borrower to pay past due payment obligations; loan matured January 2019 | --- |
June LEH Note (in default) | Failure of borrower to pay past due payment obligations; loan matured January 2019 | --- |
BDPL-LEH Loan Agreement (in default) | Failure of borrower to pay past due payment obligations; loan matured August 2018 | --- |
Third-Party Debt
Loan Description | Parties | Original Principal Amount (in millions) | Maturity Date | Monthly Principal and Interest Payment | Interest Rate | Loan Purpose |
Veritex Loans(1) | ||||||
LE Term Loan Due 2034 (in default) | LE-Veritex | $25.0 | Jun 2034 | $0.2 million | WSJ Prime + 2.75% | Refinance loan; capital improvements |
LRM Term Loan Due 2034 (in default) | LRM-Veritex | $10.0 | Dec 2034 | $0.1 million | WSJ Prime + 2.75% | Refinance bridge loan; capital improvements |
Notre Dame Debt (in default)(2)(3) | LE-Kissick | $11.7 | Jan 2018 | No payments to date; payment rights subordinated | 16.00% | Working capital; reduced balance of GEL Final Arbitration Award |
Amended Pilot Line of Credit (in default) | NPS-Pilot | $13.0 | May 2020 | --- | 14.00% | GEL Settlement Payment, NPS purchase of crude oil from Pilot, and working capital |
| SBA EIDLs | ||||||
LE Term Loan Due 2050(4) | LE-SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
NPS Term Loan Due 2050(4) | NPS-SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
Loan Description |
Parties | Original Principal Amount (in millions) |
Maturity Date |
Monthly Principal and Interest Payment |
Interest Rate |
Loan Purpose |
Veritex Loans(1) |
|
|
|
|
|
|
LE Term Loan Due 2034 (in default) | LE Veritex | $25.0 | Jun 2034 | $0.2 million | WSJ Prime + 2.75% | Refinance loan; capital improvements |
LRM Term Loan Due 2034 (in default) | LRM Veritex | $10.0 | Dec 2034 | $0.1 million | WSJ Prime + 2.75% | Refinance bridge loan; capital improvements |
Kissick Debt (in default)(2)(3) | LE Kissick | $11.7 | Jan 2018 | No payments to date; payment rights subordinated | 16.00% | Working capital; reduced balance of GEL arbitration award |
Amended Pilot Line of Credit (in default) | NPS Pilot | $13.0 | May 2020 | --- | 14.00% | GEL settlement payment, NPS purchase of crude oil from Pilot, and working capital |
SBA EIDLs |
|
|
|
|
|
|
BDEC Term Loan Due 2051(4) | Blue Dolphin SBA | $0.5 | Jun 2051 | $0.003 million | 3.75% | Working capital |
LE Term Loan Due 2050(5) | LE SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
NPS Term Loan Due 2050(5) | NPS SBA | $0.15 | Aug 2050 | $0.0007 million | 3.75% | Working capital |
Equipment Loan Due 2025(6) | LE Texas First | $0.07 | Oct 2025 | $0.0013 million | 4.50% | Equipment Lease Conversion |
(1)
(2)
(3)
(4)
(5)For disaster loans made in 2020, the SBA EIDLsinitially deferred payments for the first twelve (12) months. The SBA later extended the payment deferral period from twelve (12) months to twenty-four (24) months; under the extension, the first payment is due in September 2022; interest accrues during the deferral period. The LE Term Loan Due 2050 and NPS Term Loan Due 2050 are not forgivable.
(6) In May 2019, LE entered into a 12-month equipment rental agreement with the option to purchase the backhoe at maturity. The equipment rental agreement matured in May 2020. In October 2020, LE entered into the Equipment Loan Due 2025 to finance the backhoe purchase. We use the backhoe at the Nixon facility.
Third-Party Defaults
Loan Description | Event(s) of Default | Covenant Violations |
Veritex Loans | ||
LE Term Loan Due 2034 (in default) | Failure to make required monthly payments; failure to replenish $1.0 million payment reserve account; events of default under other secured loan agreements with Veritex | Financial covenants: • debt service coverage ratio, current ratio, and debt to net worth ratio |
LRM Term Loan Due 2034 (in default) | Events of default under other secured loan agreements with Veritex | Financial covenants: • debt service coverage ratio, current ratio, and debt to net worth ratio |
Amended Pilot Line of Credit (in default) | Failure of borrower or any guarantor to pay past due obligations; loan matured May 2020 | --- |
Kissick Debt (in default) | Failure of borrower to pay past due obligations; loan matured January 2019 | --- |
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Concentration of Customers Risk. We routinely assess the financial strength of our customers. To date, we have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.
Three Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at September 30, |
| |||
|
|
|
|
|
|
|
|
|
| |||
September 30, 2021 |
|
| 3 |
|
|
| 69 | % |
| $ | 0 |
|
September 30, 2020 |
|
| 4 |
|
|
| 80 | % |
| $ | 0 |
|
One of our significant customers is LEH, an Affiliate. Due to a HUBZone certification, the Affiliate purchases our jet fuel under a Jet Fuel Sales Agreement and bids on jet fuel contracts under preferential pricing terms. The Affiliate accounted for 30% and 28% of total revenue from operations for the three months ended September 30, 2021, and 2020, respectively. The Affiliate represented $0 in accounts receivable at both September 30, 2021, and 2020, respectively.
Nine Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at September 30, |
| |||
|
|
|
|
|
|
|
|
|
| |||
September 30, 2021 |
|
| 3 |
|
|
| 72 | % |
| $ | 0 |
|
September 30, 2020 |
|
| 4 |
|
|
| 82 | % |
| $ | 0 |
|
The Affiliate accounted for 29% and 28% of total revenue from operations for the nine months ended September 30, 2021, and 2020, respectively. The Affiliate represented $0 in accounts receivable at both September 30, 2021, and 2020, respectively.
Outstanding amounts under certain related party agreements can significantly vary from period to period based on the timing of sales and payments. Concerning the Amended and Restated Operating Agreement, we add any amount that remains outstanding at the end of the quarter to the June LEH Note. We classify the June LEH Note within long-term debt, related party, current portion (in default) on the consolidated balance sheets. At September 30, 2021, and December 31, 2020, the total amount we owed to LEH under long-term debt, related-party agreements including accrued interest totaled $19.9 million and $16.3 million, respectively. See “Part I, Item 1. Financial Statements – Notes (3) and (16)” for additional disclosures related to Affiliate agreements, arrangements, and risk.
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
Offshore lessees, operators, and rights-of-way holders operating in federal watersare required to provide BOEM with the financial assurance of the Gulf of Mexico, BOEM evaluates an operator’s financialtheir ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligationsabandonment obligations. Obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging andWhen the lessee, operator, or rights-of-way holder completes abandonment work, has been completed,BOEM releases the collateral backing the financial assurance is released by BOEM.
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.rights-of-way. BDPL historically maintained $0.9 million in financial security. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Because the IBLA granted multiple extension requests that extendedis separate and independent from the agencies whose decisions it reviews, BDPL’s deadline for filing a statement of reasons forappeal to BOEM took considerable time to matriculate through the appeal withappeals process. Ultimately, the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that, BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. Decommissioning of these assets will significantly reduce or eliminateonce BDPL completes abandonment operations, the amount of financial assurance required by BOEM which may serve towill be significantly reduced or eliminated. In addition, BOEM’s INCs will be partially or fully resolveresolved. Although we planned decommissioning activities for 2020, offshore weather conditions and cash constraints associated with the INCs. See “Note (16) – BSEE Offshore Pipelinesongoing COVID-19 pandemic led to delays. We cannot currently estimate when decommissioning will occur. Further, we cannot currently estimate when we can provide additional financial assurance (supplemental pipeline bonds).
Financial constraints and Platform Decommissioning”.
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 September 30, 2020.2021. At both September 30, 20202021, and December 31, 2019,2020, BDPL maintained approximately $0.9 million in credit and cash-backed pipeline rights-of-way bonds issued to BOEM.
Blue Dolphin Energy Company | September 30, 2021 │Page 50 |
| Table of Contents |
Management’s Discussion and Analysis |
BSEE Offshore Pipelines and Platform Decommissioning
BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations.active. Until such structuresfacilities are abandoned or removed,decommissioned, lessees and rights-of-way holders are required tomust inspect and maintain the assets in accordance withthem per regulatory requirements.
In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE onin August 15, 2019 to address BDPL’s plans with respect toconcerning decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning along withand a safe boarding plan for the platform, withinplatform. BSEE imposed a deadline of six (6) months (no later than February 15,(February 2020), to submit the permit applications and develop and implement a safe boarding plan for submission with such permit applications.plan. Further, BSEE proposed thatmandated BDPL complete approved, permitted work within twelve (12) months (no later than August 15,(August 2020). BDPL timely submitted the permit applications for decommissioning of the subject offshore pipelines and platform assetssafe boarding plan to BOEM and BSEE on February 11, 2020 and2020; we submitted related permits to the USACOE on March 25, 2020. Decommissioning of theAlthough we planned decommissioning activities for 2020, offshore pipelinesweather conditions and platform assets is on hold due to financialcash constraints associated with COVID-19. We are also awaiting approval of regulatory permits on certain segments and/or fairways, which approvals are required priorthe ongoing COVID-19 pandemic led to work commencement.delays. We cannot currently estimate when decommissioning maywill occur.
In April 2020, BSEE issued another INC to BDPL for failure to perform the required structural surveys for the GA-288C Platform. BDPL requested an extension to comply with the INC, related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platformBDPL completed the structural surveys were completed, and resolved the INC was resolved in June 2020.
Financial constraints do not relieve BDPL of its obligations to remedy the BSEE INCs or of BSEE’s authority to impose financial penalties. If BDPL fails to complete decommissioning of the offshore pipelines and platformfacilities assets and/or remedy the INCs within a timeframe determined to bedeemed prudent by BSEE, BDPL could be subject to regulatory oversight and enforcement, including but not limited to failure to correct an INC, civil penalties, and revocation of BDPL’s operator designation, whichdesignation. Such BSEE actions could 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 September 30, 2020.2021. At both September 30, 20202021, and December 31, 2019,2020, BDPL maintained $2.4 million and $2.6 million, respectively, in AROs related to abandonment ofdecommissioning these assets.
Sources and Use of Cash
.Components of Cash Flows |
Three Months Ended September 30, | Nine Months Ended September 30, | |||
2020 | 2019 | 2020 | 2019 | |
(in thousands) | ||||
| Cash Flows Provided By (Used In): | ||||
| Operating activities | $1,878 | $832 | $(2,196) | $(10,335) |
| Investing activities | (177) | (964) | (1,085) | (1,458) |
| Financing activities | (1,463) | (655) | 3,451 | 11,308 |
| Increase (Decrease) in Cash and Cash Equivalents | $238 | $(787) | $170 | $(485) |
|
| Three Months Ended |
|
| Nine Months Ended |
| ||||||||||
|
| September 30, |
|
| September 30, |
| ||||||||||
|
| 2021 |
|
| 2020 |
|
| 2021 |
|
| 2020 |
| ||||
|
| (in thousands) |
|
| (in thousands) |
| ||||||||||
| Cash Flows Provided By (Used In): |
|
|
|
|
|
|
|
|
|
|
|
| ||||
Operating activities |
| $ | 4,084 |
|
| $ | 1,658 |
|
| $ | (418 | ) |
| $ | (2,196 | ) |
Investing activities |
|
| - |
|
|
| (177 | ) |
|
| - |
|
|
| (1,085 | ) |
Financing activities |
|
| 1,916 |
|
| (1,243 | ) |
|
| 696 |
|
|
| 3,451 |
| |
Decrease in Cash and Cash Equivalents |
| $ | 2,168 |
|
| $ | 238 |
|
| $ | 1,114 |
|
| $ | 170 |
|
Cash Flow 2020 Compared to 2019
We had cash flow from operations of approximately $1.8$4.1 million for Q3 20202021 compared to cash flow of approximately $0.8$1.7 million for Q3 2019.2020. The approximate $1.0 million increaseimprovement in cash flow from operations between the three-month comparative periods primarily related to a declinean increase in inventory levels and increasesunearned revenue. We had cash flow from operations of approximately $0.4 million for 9 Months 2021 compared to approximately $2.2 million for 9 Months 2020. The improvement in accounts payable. The cash flow deficit for 9 Months 2020between the nine-month periods primarily related to loss from operations. The cash flow deficit from operations for 9 Months 2019 was primarily the result of payments toward the accrued arbitration award with GEL.
Capital Expenditures
During Q3 2020,2021, capital expenditures totaled $0.2 million$0 compared to $1.0$0.2 million during Q3 2019.2020. During 9 Months 2020,2021, capital expenditures totaled $1.1 million$0 compared to $1.5$1.1 million during 9 Months 2019. Expenditures2020. Capital expenditures during 2020 primarily related to completion of a petroleum storage tank and a maintenance turnaround. We completed the 5-year Nixon capital improvement expansion project during 9 Months 2020 primarily related to:
We account for our capital expenditures in accordance withper GAAP. We also classify capital expenditures as ‘maintenance’ if itthe expenditure maintains capacity or throughput or as ‘expansion’ if itthe expenditure increases capacity or throughput capabilities. Although classification is generally a straightforward process, in certain circumstances the determination is a matter of management judgment and discretion.
Blue Dolphin Energy Company | September 30, 2021 │Page 51 |
| Table of Contents |
Management’s Discussion and Analysis |
We identify and prioritize capital projects based on merits such as operational safety and efficiency, customer need, regulatory compliance, and economic benefits. We budget for maintenance capital expenditures throughout the year on a project-by-project basis. Projects are determined based on maintaining safe and efficient operations, meeting customer needs, complying with operating policies and applicable law, and producing economic benefits, such as increasing efficiency and/or lowering future expenses.
Off-Balance Sheet Arrangements
. None.Accounting Standards
.Critical Accounting Policies and Estimates
We describe our significant accounting policies and recent accounting developments are described in “Note“Part I, Item 1. Financial Statements – Note (2)” to our consolidated financial statements.. The ongoing COVID-19 pandemic and certain developmentsrelated governmental responses, volatility in the global oil marketscommodity prices, and severe weather resulting from climate change have impacted and likely will continue to impact our business. Our business was designated as an essential business and, as such, has remained open. We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through the remainder of the year and beyond. Given diminished expectations for the global economy, and speculation regarding a prolonged slowdown and recession, we are unable toAlthough management cannot predict the ultimate economic impact of COVID-19these factors will have on our business.
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 September 30, 20202021, and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.
New Accounting Standards and Disclosures
See “Part I, Item 1. Financial Statements – Note (2)” for a discussion of new accounting standards and disclosures are discussed in “Note (2)” to our consolidated financial statements.
Remainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | September 30, 2021 │Page 52 |
| Table of Contents |
Internal Controls |
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not applicable.
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
We evaluated 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 ReportBased 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 certainan identified material weaknesses and/orweakness and a significant deficienciesdeficiency as described below:
● | Significant |
● | Material |
We previously reported the significant deficiency and material weakness in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2021, andQuarterly Report on Form 10-Q for the quarterly period ended June 30, 2021.
Our disclosure controls and procedures remained ineffective as of the end of the period covered by this Quarterly Report. Management continuesreport. However, management has taken corrective actions to evaluate internalremedy both the significant deficiency and material weakness. Corrective actions included implementing formal end of month processes to take corrective actions. Corrective actions may include implementing formal policies, improving processes, documenting procedures,review manual journal entries and better defining segregation of dutiesidentify complex accounting transactions. In addition, any identified complex accounting transactions are reviewed and evaluated by senior management. Management expects 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,fully remediate the significant deficiency and our initiatives may not prove to be successful in fully remediating the identifiedmaterial weakness and deficiency.
Changes in Internal Control over Financial Reporting
We did not identify any new disclosure controls and procedures issues (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the three and nine months ended September 30, 2020 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.2021. 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
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Legal Proceedings and Risk Factors |
PART II
ITEM 1. LEGAL PROCEEDINGS
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
Offshore lessees, operators, and rights-of-way holders operating in federal watersare required to provide BOEM with the financial assurance of the Gulf of Mexico, BOEM evaluates an operator’s financialtheir ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligationsabandonment obligations. Obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging andWhen the lessee, operator, or rights-of-way holder completes abandonment work, has been completed,BOEM releases the collateral backing the financial assurance is released by BOEM.
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.rights-of-way. BDPL historically maintained $0.9 million in financial security. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Because the IBLA granted multiple extension requests that extendedis separate and independent from the agencies whose decisions it reviews, BDPL’s deadline for filing a statement of reasons forappeal to BOEM took considerable time to matriculate through the appeal withappeals process. Ultimately, the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, the solicitor’s office signaled that, BDPL’s adherence to the milestones identified in an August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. Decommissioning of these assets will significantly reduce or eliminateonce BDPL completes abandonment operations, the amount of financial assurance required by BOEM which may serve towill be significantly reduced or eliminated. In addition, BOEM’s INCs will be partially or fully resolveresolved. Although we planned decommissioning activities for 2020, offshore weather conditions and cash constraints associated with the INCs. See “Note (16) – BSEE Offshore Pipelinesongoing COVID-19 pandemic led to delays. We cannot currently estimate when decommissioning will occur. Further, we cannot currently estimate when we can provide additional financial assurance (supplemental pipeline bonds).
Financial constraints and Platform Decommissioning”.
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 September 30, 2020.2021. At both September 30, 20202021, and December 31, 2019,2020, 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 legal matterslawsuits, claims, and proceedings incidental to the routine operationconduct of our business. Such legal matters includebusiness, including debt and office lease payment defaults, mechanic’s liens, contract-related disputes, and administrative proceedings. As of the filing date of this report, we were involved in a contract-related disputeManagement communicates with a counter-party. Management is working to resolve the dispute amicably, however, the potential outcome is unknown. Managementall concerned parties and does not believe that the contract-related dispute or otherthese matters will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurancewe cannot assure that management's effortscommunications will result in a manageable outcome. If, for example, Veritex and/or Pilot exercise theirexercises its rights and remedies due to defaults under our secured loan agreements with them, our business, financial condition, and results of operations will be materially adversely affected.
ITEM 1A. RISK FACTORS
In addition to the other information set forthoutlined in this Quarterly Report, careful considerationinvestors should be given tocarefully consider the risk factors discussed under “Part I, Item 1A. Risk Factors” and elsewhere in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 and our Quarterly Reports for the three month periods ended March 31, 2020 and June 30, 2020 as filed with the SEC. TheseThe identified risks and uncertainties could materially and adversely affect our business, financial condition, and results of operations. Our operations could also be affected by additional unknown factors that are not presently known to us or by factors that we currently consider immaterial to our business. Except as notedfor the risk factor identified below, there have been no material changes in ourthe assessment of our risk factors from those set forthoutlined in our Annual Report for the fiscal year ended December 31, 2019,2020.
Our future results could be adversely affected if we cannot effectively execute new business strategies, such as well as our Quarterly Reports for the three month periods ended March 31, 2020 and June 30, 2020.
Our future results of operations partially depend on whether we can successfully execute new business strategies. In 2021, we implemented a new business strategy to explore renewable fuels opportunities. This strategy involves a multitude of uncertainties, many of which are beyond our control. Related risks include, but are not limited to, partisan politics that affect governmental policies, regulations, and cash flowsincentives; substantive upfront capital investments; permitting challenges; product market identification; competition; supply chain issues; environmental impact assessment requirements; construction and thoseimplementation delays; technology deployment failure; and environmental and ecological consequences. These risks and uncertainties could adversely affect anticipated results and benefits of our customers and suppliers.
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
Exhibits |
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
See “Part I, Item. 1. Financial Statements – NoteNotes (10)” and “Note (11)” for disclosures related to defaults on our debt.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5.
None.
ITEM 6. EXHIBITS
Exhibits Index
No. | Description | |
| 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. | |
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. |
*
Blue Dolphin Energy Company | September 30, |
| Table of Contents |
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) | |||||
November 15, 2021 | By: | ||||
/s/ JONATHAN P. CARROLL | |||||
Jonathan P. Carroll Chief Executive Officer, President, Assistant Treasurer and Secretary (Principal Executive Officer, Principal Financial Officer, and Principal Accounting Officer) | |||||
Blue Dolphin Energy Company | September 30, |
