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
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: None
Securities registered pursuant to Section 12(g) of the Act:
Common Stock, par value $0.01 per share |
(Title of class) |
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 May 17,November 15, 2021: 12,693,514
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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, 2021 │Page 3 |
Glossary of |
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 |
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 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 |
· | 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 |
· | Affiliate common stock ownership and transactions that could cause conflicts of interest. |
· | Operational hazards inherent in |
· | Geographical concentration of our assets and customers in West Texas. |
· | Competition from companies |
· | Environmental laws and regulations |
· | Strict laws and regulations regarding personnel and process safety. |
· | Market changes in insurance 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 |
· | Actual or threatened terrorist |
· | Adverse effects of security threats. |
· | Public health threats, pandemics, and epidemics, such as the ongoing outbreak of COVID-19, and the adverse impacts thereof on our business, financial condition, results of operations, and liquidity. |
Blue Dolphin Energy Company | September 30, 2021 │Page 8 |
Important Information Regarding Forward Looking Statements |
Downstream and Midstream Operations
· | Commodity price and refined product demand volatility, which adversely |
· | Crude oil, other feedstocks, and fuel 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 |
· | 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 climate-related events |
· | Regulatory changes |
· | Our ability to effect and integrate potential 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 within the time |
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 equity of current stockholders and the potential decline of our stock price |
· | The potential sale of shares |
· | The lack of dividend payments. |
· | Failure to maintain |
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, 2020, as filed with the SEC and elsewhere in this report.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, 2021 │Page |
| Table of Contents |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands except share amounts) | ||
| ASSETS | ||
| CURRENT ASSETS | ||
| Cash and cash equivalents | $521 | $549 |
| Restricted cash | 48 | 48 |
| Accounts receivable, net | 170 | 214 |
| Prepaid expenses and other current assets | 1,060 | 3,564 |
| Deposits | 110 | 124 |
| Inventory | 1,099 | 1,062 |
| Total current assets | 3,008 | 5,561 |
| LONG-TERM ASSETS | ||
| Total property and equipment, net | 61,856 | 62,497 |
| Operating lease right-of-use assets, net | 458 | 498 |
| Restricted cash, noncurrent | - | 514 |
| Surety bonds | 230 | 230 |
| Total long-term assets | 62,544 | 63,739 |
| TOTAL ASSETS | $65,552 | $69,300 |
| LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) | ||
| CURRENT LIABILITIES | ||
| Long-term debt less unamortized debt issue costs, current portion (in default) | $33,724 | $33,692 |
| Line of credit payable less unamortized debt issue costs (in default) | 7,169 | 8,042 |
| Long-term debt, related party, current portion (in default) | 16,351 | 16,010 |
| Interest payable (in default) | 7,001 | 6,408 |
| Interest payable, related party (in default) | 2,974 | 2,814 |
| Accounts payable | 2,689 | 3,274 |
| Accounts payable, related party | 155 | 155 |
| Current portion of lease liabilities | 199 | 194 |
| Asset retirement obligations, current portion | 2,370 | 2,370 |
| Accrued expenses and other current liabilities | 4,689 | 4,882 |
| Total current liabilities | 77,321 | 77,841 |
| LONG-TERM LIABILITIES | ||
| Long-term lease liabilities, net of current | 319 | 370 |
| Deferred revenues | 1,523 | 1,520 |
| Long-term debt, net of current portion | 349 | 355 |
| Total long-term liabilities | 2,191 | 2,245 |
| TOTAL LIABILITIES | 79,512 | 80,086 |
| Commitments and contingencies (Note 16) | ||
| STOCKHOLDERS' DEFICIT | ||
| Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 | ||
| shares issued and outstanding at both March 31, 2021 and December 31, 2020) | 127 | 127 |
| Additional paid-in capital | 38,457 | 38,457 |
| Accumulated deficit | (52,544) | (49,370) |
| TOTAL STOCKHOLDERS' DEFICIT | (13,960) | (10,786) |
| TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) | $65,552 | $69,300 |
|
| 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, 2021 │Page |
| Table of Contents |
2021 | 2020 | |
(in thousands, except share and per-share amounts) | ||
| REVENUE FROM OPERATIONS | ||
| Refinery operations | $58,483 | $60,897 |
| Tolling and terminaling | 930 | 1,103 |
| Total revenue from operations | 59,413 | 62,000 |
| COST OF GOODS SOLD | ||
| Crude oil, fuel use, and chemicals | 57,783 | 59,720 |
| Other conversion costs | 1,840 | 2,368 |
| Total cost of goods sold | 59,623 | 62,088 |
| Gross deficit | (210) | (88) |
| COST OF OPERATIONS | ||
| LEH operating fee | 124 | 147 |
| Other operating expenses | 54 | 59 |
| General and administrative expenses | 658 | 644 |
| Depletion, depreciation and amortization | 693 | 633 |
| Total cost of operations | 1,529 | 1,483 |
| Loss from operations | (1,739) | (1,571) |
| OTHER INCOME (EXPENSE) | ||
| Easement, interest and other income | 2 | 20 |
| Interest and other expense | (1,480) | (1,774) |
| Gain on extinguishment of debt | 43 | - |
| Total other expense | (1,435) | (1,754) |
| Loss before income taxes | (3,174) | (3,325) |
| Income tax expense | - | (15) |
| Net loss | $(3,174) | $(3,340) |
| Loss per common share: | ||
| Basic | $(0.25) | $(0.27) |
| Diluted | $(0.25) | $(0.27) |
| Weighted average number of common shares outstanding: | ||
| Basic | 12,693,514 | 12,327,365 |
| Diluted | 12,693,514 | 12,327,365 |
|
| 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, 2021 │Page |
| Table of Contents |
Three Months Ended March 31, | ||
2021 | 2020 | |
| (in thousands) | ||
| OPERATING ACTIVITIES | ||
| Net loss | $(3,174) | $(3,340) |
| Adjustments to reconcile net loss to net cash | ||
| used in operating activities: | ||
| Depletion, depreciation and amortization | 693 | 633 |
| Deferred income tax | - | 15 |
| Amortization of debt issue costs | 32 | 220 |
| Guaranty fees paid in kind | 152 | 153 |
| Related-party interest expense paid in kind | 225 | 68 |
| Deferred revenues and expenses | 3 | (122) |
| Gain on extinguishment of debt | (43) | - |
| Changes in operating assets and liabilities | - | |
| Accounts receivable | 44 | (879) |
| Accounts receivable, related party | - | 1,364 |
| Prepaid expenses and other current assets | 2,504 | 1,496 |
| Deposits and other assets | 14 | (16) |
| Inventory | (37) | 832 |
| Accounts payable, accrued expenses and other liabilities | (40) | (683) |
| Net cash provided by (used in) operating activities | 373 | (259) |
| INVESTING ACTIVITIES | ||
| Capital expenditures | - | (198) |
| Net cash used in investing activities | - | (198) |
| FINANCING ACTIVITIES | ||
| Proceeds from debt | - | (696) |
| Payments on debt | (879) | - |
| Net activity on related-party debt | (36) | 1,350 |
| Net cash provided by (used in) financing activities | (915) | 654 |
| Net change in cash, cash equivalents, and restricted cash | (542) | 197 |
| CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD | 1,111 | 668 |
| CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD | $569 | $865 |
| Supplemental Information: | ||
| Non-cash investing and financing activities: | ||
| Interest paid | $287 | $361 |
| Income taxes paid (refunded) | $- | $- |
|
| 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, 2021 │Page |
| 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, withand 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”.
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 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 and funds 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, 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. As discussed more fully below, theseThese factors include inadequate liquidity to sustain operations due to defaults under our secured loan agreements, margin deterioration and volatility, and historichistorical net losses and working capital deficits.deficits, as discussed more fully below. Our consolidated financial statements assume we will continue as a going concern and do not include any adjustments that might result from the outcome of this uncertainty. Our ability to continue as a going concern depends on sustained positive operating margins and havingadequate working capital for, amongst other requirements, purchasing crude oil and condensate and making payments on long-term debt. Without positive operating margins and working capital, our business will be jeopardized, and we may not be able to continue. If we are unable to process crude oil and condensate into sellable refined products or make required debt payments, we would likely have tomay consider other options. These options such asmight include selling assets, raising additional debt or equity capital, cutting costs, or otherwise reducing our cash requirements, restructuring debt obligations, or negotiating with our creditors to restructure our applicable obligations, including a potential bankruptcy filing.
Defaults Under Secured Loan Agreements
. We are currently in default under certain of our secured loan agreements with third parties and related 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 2020. For the nine months ended September 30, 2021, and 2020, interest was $0.7 million and $1.1 million, respectively. See “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. | |
· | 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 borrow from Affiliates during periods of working capital deficits.
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, 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 being in default. As a result, thethese debt associated with these obligations waswere classified within the current portion of long-term debt on our consolidated balance sheets at March 31,September 30, 2021, and December 31, 2020.
Margin Volatility. Our refining margins generally improve in an environment of higher crude oil and refined 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 future financial position and results of operations. Accordingly, we believe these factors could have a material adverse effect on our financial results for the remainder of 2021 and into 2022.
Historical Net Losses and Working Capital Deficits
Net Losses. Net loss for the three months ended September 30, 2021, 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, during the three months ended September 30, 2020. Net loss for the nine months ended September 30, 2021, 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, for the nine months ended September 30, 2020. The improvement between both comparative periods resulted from demand recovery, commodity price improvements, and encouraging trends in pandemic containment efforts.
Working Capital Deficits. 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 long-term debt, we had $26.2 million and $22.6 million in working capital deficits at September 30, 2021, and December 31, 2020, respectively.
Cash and cash equivalents totaled $2.2 million and $0.5 million at September 30, 2021, and December 31, 2020, respectively. Restricted cash (current portion) totaled $0.05 million at both September 30, 2021, and December 31, 2020. Restricted cash, noncurrent totaled $0 and $0.5 million at September 30, 2021, and December 31, 2020, respectively.
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 critical factors, including having adequate working capital to meet contractual, operational, regulatory, and safety needs and having favorable margins on refined products. We are currently unable to estimate the impact the COVID-19 pandemic will have on our future financial position and results of operations. Earlier state and federal mandates that regulated business closures due to COVID-19 deemed our business essential, and we remained open. If future restrictive directives become necessary, we expect to continue operating. However, additional governmental mandates will likely result in business and operational disruptions, including demand destruction, liquidity strains, supply chain challenges, travel restrictions, controls on in-person gathering, and workforce availability.
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, monitoring discretionary spending, and delaying capital expenditures. 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 fund our working capital needs when we experience working capital deficits, we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, we will be able to obtain additional financing on commercially reasonable terms or at all, or margins on our refined products will be favorable. Further, if Veritex exercises its rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
(2) Principles of Consolidation and Significant Accounting Policies
Basis of Presentation
The accompanying unaudited consolidated financial statements, including Blue Dolphin and its subsidiaries, were prepared under GAAP for interim consolidated financial information according 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 usually included in our audited financial statements were condensed or omitted according to the SEC’s rules and regulations. Significant intercompany transactions were eliminated in the consolidation. In management’s opinion, consolidated financial statements include all necessary adjustments for a fair presentation, disclosures are adequate, and the presented information is not misleading.
We derived the consolidated balance sheet as of December 31, 2020, from the audited financial statements at that date. We recommend that investors read the consolidated financial statements and notes in this report together with the consolidated financial statements and notes in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, as filed with the SEC. Our financial and operating results for the three and nine months ended September 30, 2021, should not be exclusively relied upon to indicate our performance for the fiscal year ending December 31, 2021, or any other period.
Significant Accounting Policies
The summary of Blue Dolphin’s significant accounting policies assists 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. We consistently applied these accounting policies in the preparation of our consolidated financial statements. Our accounting policies conform to GAAP.
Use of Estimates. Preparing our financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses, and related disclosures. Actual results could differ from those estimates. The ongoing COVID-19 pandemic and corresponding governmental responses, volatility in commodity prices, and severe weather resulting from climate change have impacted and likely will continue to impact 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, 2021, and through the filing date of this report. The accounting matters assessed included but were not limited to our allowance for doubtful accounts, inventory and related reserves, and the carrying value of long-lived assets.
Cash and Cash Equivalents. Cash and cash equivalents represent liquid investments with an original maturity of three months or less. We maintain cash balances in depository and overnight investment accounts with financial institutions that, at times, may exceed insured deposit limits. We monitor the financial condition of the financial institutions and, to date, have experienced no losses associated with these accounts.
Restricted Cash. Restricted cash, current portion primarily represents a payment reserve account held by Veritex as security for payments under a secured loan agreement. Restricted cash, noncurrent represents funds held in the Veritex disbursement account for payment of construction-related expenses for completion of new petroleum storage tanks.
Blue Dolphin Energy Company | September 30, 2021 │Page 15 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Accounts Receivable and Allowance for Doubtful Accounts. We present accounts receivable net of any necessary allowance(s) for doubtful accounts. Receivables are recorded at the invoiced amount and generally do not bear interest. Management establishes or adjusts an allowance for doubtful accounts based on a customer’s current aging status, collection history, and financial condition. At September 30, 2021, and December 31, 2020, we had an allowance for doubtful accounts of $0 and $0.1 million, respectively.
Inventory. Inventory primarily consists of refined products, crude oil, condensate, and chemicals. We value inventory at the lower of cost or net realizable value with cost determined by the average cost method and net realizable value determined based on estimated selling prices less associated delivery costs. We record a write-down of inventory and an associated adjustment to the cost of goods sold if the net realizable value of our refined products inventory declines to an amount that is less than our average cost. See “Note (7)” to our consolidated financial statements for additional disclosures related to inventory.
Property and Equipment.
Refinery and Facilities. We typically make ongoing improvements to the Nixon facility based on operational needs, technological advances, and safety and regulatory requirements. We capitalize additions to refinery and facilities assets, and we expense costs for repairs and maintenance as incurred. We record refinery and facilities at cost less any adjustments for depreciation or impairment. We adjust the asset and the related accumulated depreciation accounts for the refinery and facilities asset’s retirement and disposal, with the resulting gain or loss included in the consolidated statements of operations. For financial reporting purposes, we compute refinery and facilities assets depreciation using the straight-line method with an estimated useful life of 25 years; we depreciate refinery and facilities assets when placed in service. We did not record any impairment of our refinery and facilities assets for the periods presented.
Pipelines and Facilities. We record our pipelines and facilities at cost less any adjustments for depreciation or impairment. We computed depreciation using the straight-line method over estimated useful lives ranging from 10 to 22 years. Per FASB ASC guidance, we performed impairment testing of our pipeline and facilities assets in 2016. Upon completion of testing, we fully impaired our pipeline assets at December 31, 2016. Our pipelines and facilities assets are inactive. Although we planned to decommission the offshore pipelines and platform assets during 2020, decommissioning of these assets was delayed due to cash constraints associated with the ongoing impact of COVID-19. We cannot currently estimate when decommissioning may occur.
Oil and Gas Properties. We account for our oil and gas properties using the full-cost method of accounting. Under this method, all costs associated with the acquisition, exploration, and development of oil and gas properties, including directly related internal costs, are capitalized on a cost center basis. Amortization expenses and estimated future development costs are determined using the unit-of-production method. All leases associated with our oil and gas properties have expired. We fully impaired our oil and gas properties at December 31, 2011.
CIP. CIP expenditures relate to construction and refurbishment activities and equipment for the Nixon facility. We capitalize these expenditures as incurred. We depreciate CIP when placed in service. See “Note (8)” to our consolidated financial statements for additional disclosures related to our refinery and facilities assets, oil and gas properties, pipelines and facilities assets, and CIP.
Leases. We determine whether a contract or agreement is or contains a lease at inception. If the contract is or includes a lease and has a term greater than one year, we recognize a ROU asset and lease liability as of the commencement date based on the present value of the lease payments over the lease term. We determine the present value of the lease payments by using the implicit rate when readily determinable. If the implicit rate is not defined, we use the incremental borrowing rate to discount lease payments to present value. We adjust lease terms to include options to extend or terminate the lease when it is reasonably certain that we will exercise those options.
For operating leases, we record lease rental payments on a straight-line basis over the lease term; we record lease expenses on the income statement based on the leased asset’s intended use. For finance leases (previously referred to under GAAP as capital leases), we amortize lease payments for the ROU asset on a straight-line basis over the lesser of the leased asset’s useful life or the lease term; we record amortization expenses on the income statement in ‘depreciation and amortization expense;’ we record interest expense on the income statement in ‘interest and other expense.’
Revenue Recognition.
Refinery Operations Revenue. We recognize revenue from refined products sales when we meet our performance obligation to the customer. We meet our performance obligation when the customer receives control of the product. The customer accepts control of the product when the product is lifted. When the product is not lifted immediately (bill and hold arrangements), the customer takes control of the product when added to the customer’s bulk inventory as stored at the Nixon facility. We allocate a transaction price to each separately identifiable refined product load.
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. We include incurred transportation, shipping, and handling costs in the cost of goods sold. We do not include excise and other taxes collected from customers and remitted to governmental authorities 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 fees under (i) tank storage agreements, whereby a customer agrees to pay a certain fee per tank based on tank size over time for the storage of products and (ii) tolling agreements, whereby a customer agrees to pay a certain fee per gallon or barrel for throughput volumes moving through the naphtha stabilizer unit and a fixed monthly reservation fee for the use of the naphtha stabilizer unit.
We typically satisfy performance obligations for tolling and terminaling operations over time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the agreement term. We allocate the transaction price to the single performance obligation that exists under the agreement. 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. The fixed cost under the customer’s tank storage agreement does not include ancillary service fees. We consider ancillary services as a separate performance obligation under the tank storage agreement. We satisfy the performance obligation and recognize the associated fee when we complete the requested service.
Deferred Revenue. Deferred revenue represents a liability related to a revenue-producing activity as of the balance sheet date. We record unearned revenue, which usually consists of customer prepayments when we receive the cash payment. Once we satisfy the performance obligation, we recognize revenue in conformity with GAAP.
Income Taxes. We determine deferred income taxes based on: (i) temporary differences between carrying amounts and the actual income tax basis of our assets and liabilities and (ii) operating losses and tax credit carryforwards using currently enacted tax rates and laws in effect for the year in which we expect the differences to reverse. Our provision for income taxes consists of our current tax liability and the change in deferred income tax assets and liabilities.
Management uses significant judgment in evaluating uncertain tax positions and determining the provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to assess the realizability of deferred tax assets. We weigh whether there is a more than 50% probability of realizing a portion or all the deferred tax assets. Realization depends on the generation of future taxable income before the expiration of any NOL carryforwards. We 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 meet a minimum recognition threshold. First, we determine whether there is a more than 50% probability that our income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If we meet the criteria, we record a benefit in the financial statements equal to the largest amount greater than 50% likely to be realized upon settlement with taxing authorities. See “Note (14)” to our consolidated financial statements for more information related to income taxes.
Impairment or Disposal of Long-Lived Assets. We periodically evaluate our long-lived assets for impairment. Additionally, we re-assess our long-lived assets when events or circumstances indicate that the carrying value of these assets may not be recoverable. The carrying value is not recoverable if it exceeds the sum of the undiscounted cash flows expected from the use and eventual disposition of the asset or group of assets. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset or group of assets is recognized. Management uses significant judgment in forecasting future operating results and projected cash flows. If conditions or assumptions change, material impairment charges could be necessary.
Commodity price market volatility associated with the COVID-19 pandemic could affect the value of certain of our long-lived assets. Management evaluated our refinery and facilities assets for impairment as of September 30, 2021. We did not record any impairment of our refinery and facilities assets for the periods presented.
Asset Retirement Obligations. We record a liability for the discounted fair value of an ARO in the period incurred. We also capitalize the corresponding cost by increasing the carrying amount of the related long-lived asset. The liability is accreted towards its future value each period, and we depreciate the capitalized cost over the useful life of the related asset. We recognize a gain or loss if we settle the liability for an amount other than the amount recorded.
Refinery and Facilities. We believe we have 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 when a definitive obligation arises and retirement dates are evident.
Pipeline and Facilities; Oil and Gas Properties. Management uses significant judgment to estimate future asset retirement costs for our pipelines, related facilities, and oil and gas properties. These costs relate to dismantling and disposing certain physical assets, plugging and abandoning wells, and restoring land and seabeds. Factors considered include regulatory requirements, structural integrity, water depth, reservoir depth, equipment availability, and mobilization efforts. We review our assumptions and estimates of future abandonment costs on an annual basis. See “Note (12)” to our consolidated financial statements for additional information related to AROs.
Blue Dolphin Energy Company | September 30, 2021 │Page 17 |
| 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 the weighted average number of shares of common stock outstanding for the period. We calculate diluted EPS by dividing net income available to common stockholders by the diluted weighted average number of common shares outstanding. Diluted EPS includes the potential dilution that could occur if securities or other contracts to issue shares of common stock were converted to common stock that then shared in the entity’s earnings. The number of shares related to restricted stock included in diluted EPS is based on the “Treasury Stock Method.” We do not currently have issued options, warrants, or similar instruments. Convertible shares, if granted, are not included in the computation of earnings per share if anti-dilutive. See “Note (15)” to our consolidated financial statements for additional information related to EPS.
New Pronouncements Adopted. The FASB issues ASUs to communicate changes to the FASB ASC, including modifications to non-authoritative SEC content. During the three and nine months ended September 30, 2021, we did not adopt any ASUs.
New 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) Related-Party Transactions
Affiliate Operational Agreements Summary
Blue Dolphin and certain of its subsidiaries are parties to several operational agreements with Affiliates. Management believes that these related-party agreements are arm’s-length transactions.
Agreement/Transaction | Parties | Effective Date | Key Terms |
Jet Fuel Sales Agreement | LEH LE | 04/01/2021 | 1-year term expiring earliest to occur of 03/31/2022 plus 30-day carryover or delivery of maximum jet fuel quantity; LEH bids on jet fuel contracts under preferential pricing terms due to a HUBZone certification |
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 $0.01 million per month |
Amended and Restated Operating Agreement | LEH Blue Dolphin LE LRM NPS BDPL BDPC BDSC | 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 funding when revenue from operations and availability under bank facilities are insufficient to meet our liquidity and working capital needs. We reflect such borrowings in our consolidated balance sheets in accounts payable, related party, or long-term debt, related party.
Related-Party Long-Term Debt
Loan Description | Parties | Maturity Date | Interest Rate | Loan Purpose |
March Carroll Note (in default) | 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 (in default) | Ingleside Blue Dolphin | Jan 2019 | 8.00% | Blue Dolphin working capital |
June LEH Note (in default) | 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 (in default)(1) | 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) The original principal amount of the BDPL-LEH Loan Agreement was $4.0 million.
(2)As a condition for our secured loan agreements, Veritex required Jonathan Carroll to guarantee repayment of borrowed funds and accrued interest personally. Mr. Carroll receives guaranty fees under the guaranty fee agreements. Fees are payable 50% in cash and 50% in Common Stock. We accrue payment of the Common Stock portion quarterly. For the foreseeable future, management does not intend to pay Mr. Carroll the cash portion due to Blue Dolphin’s working capital deficits. The cash portion will continue to accrue and increase the outstanding principal balance owed to Mr. Carroll under the March Carroll Note.
Guarantees, Security, and Defaults
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 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Covenants
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, 2021, and December 31, 2020.
Long-term debt, related party, current portion (in default) and accrued interest payable, related party.
|
| 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, |
| ||||||||||||||||||||||||||
|
| 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, |
| ||||||||||
|
| 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, 2021 │Page 19 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Other.BDSC received sublease income from LEH totaling $0.01 million for both the three months ended September 30, 2021, and 2020. Sublease income totaled $0.03 million for both the nine-month periods ended September 30, 2021, and 2020.
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 $0.5 million for the nine months ended September 30, 2021, and 2020, respectively. Decreases in both periods was the result of lower operating costs.
(4) Revenue and Segment Information
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, focused on tolling and storing petroleum products for third parties at the Nixon facility. Corporate and other includes BDSC, BDPL, and BDPC.
Revenue from Contracts with Customers
Disaggregation of Revenue. We present revenue in the table below under ‘Segment Information’ separated by business segment because management believes this presentation is beneficial to users of our financial information.
Receivables from Contracts with Customers. We present accounts receivable from contracts with customers as accounts receivable, net on our consolidated balance sheets.
Contract Liabilities. Our contract liabilities consist of unearned revenue from customers in the form of prepayments. We include unearned revenue in accrued expenses and other current liabilities on our consolidated balance sheets. See “Note (9)” to our consolidated financial statements for more information related to unearned revenue.
Remaining Performance Obligations. Most of our customer contracts are settled immediately and therefore have no remaining performance obligations.
Remainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | September 30, 2021 │Page 20 |
| 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 |
|
| 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) Operation costs and expenses include cost of goods sold. Also, operation costs and expenses within: (i) tolling and terminaling includes terminal operating expenses and an allocation of other costs (e.g., insurance and maintenance) and (ii) corporate and other includes expenses related to BDSC, BDPC, and BDPL.
(2)General and administrative expenses within refinery operations include the LEH operating fee.
Blue Dolphin Energy Company | September 30, 2021 │Page 21 |
| Table of Contents |
Notes to Consolidated Financial Statements |
|
| 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) Risk Concentration
Bank Accounts
Financial instruments that potentially subject us to risk concentrations 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 September 30, 2021, and December 31, 2020, we had cash balances (including restricted cash) that exceeded the FDIC insurance limit per depositor of $1.9 million and $0.6 million, respectively.
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. The volume-based crude supply agreement expires when Pilot sells us 24.8 million net bbls of crude oil. After that, the crude supply agreement automatically renews for successive one-year terms (each such term, a “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 June 30, 2020, Pilot assigned its rights, title, interest, and obligations in the crude supply agreement to Tartan Oil LLC, a Pilot affiliate. As of September 30, 2021, the total volume we received under the crude supply agreement 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 renews 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 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.
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.
Blue Dolphin Energy Company | September 30, 2021 │Page 22 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Significant Customers
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 “Notes (3) and (16)” to our consolidated financial statements for additional disclosures related to transactions with Affiliates.
Customer Concentration. All of our customers are refined petroleum product wholesalers. This customer concentration may impact our overall exposure to credit risk, either positively or negatively, as our customers are likely similarly affected by economic changes. Exposure risk includes, but is not limited to, uncertainties related to the COVID-19 pandemic and the volatility in the global oil markets. Historically, we have had no significant problems collecting our accounts receivable, including from many of our pre-pay 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 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 “Notes (3) and (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
Prepaid expenses and other current assets as of the dates indicated consisted of the following:
|
| 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
Inventory as of the dates indicated consisted of the following:
|
| 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
Property, plant and equipment, net, as of the dates indicated, consisted of the following:
|
| 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. We record capitalized interest as part of the asset it relates to, and we depreciate the capitalized interest over the asset’s useful life. The capitalized interest cost included in CIP was $0 at September 30, 2021, and December 31, 2020.
We funded capital expenditures for expansion at the Nixon facility through long-term debt from Veritex, revenue from operations, and working capital from Affiliates. At September 30, 2021, and December 31, 2020, we reflected Veritex-derived amounts not used for capital expenditures in restricted cash (current and non-current portions) on our consolidated balance sheets.
Blue Dolphin Energy Company | September 30, 2021 │Page 24 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(9) Accrued Expenses and Other Current Liabilities
Accrued expenses and other current liabilities as of the dates indicated consisted of the following:
|
| 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) Third-Party Defaults
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 |
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)Veritex placed proceeds in a disbursement account for the payment of construction-related expenses. We reflected the amounts held in the disbursement account as restricted cash (current portion) and restricted cash, noncurrent on our consolidated balance sheets. At September 30, 2021, restricted cash (current portion) was $0.05 million, and restricted cash, noncurrent, was $0. At December 31, 2020, restricted cash (current portion) was $0.05 million, and restricted cash, noncurrent, was $0.5 million.
(2)LE originally entered into a loan agreement with Notre Dame Investors, Inc. in the principal amount of $8.0 million. John Kissick currently holds this debt. Under a 2017 amendment, the parties amended the Kissick Debt to increase the principal amount by $3.7 million; LE used the additional principal to reduce the arbitration award payable to GEL by $3.6 million.
(3)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.
(4)For disaster loans made in 2021, the SBA initially deferred payments for the first twelve (12) months. The SBA later extended the payment deferral period from twelve (12) months to eighteen (18) months; under the extension, the first payment is due in December 2022; interest accrues during the deferral period. The BDEC Term Loan Due 2051 is not forgivable.
(5)For disaster loans made in 2020, the SBA initially 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 late fees), as of the dates indicated, was as follows:
|
| 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:
|
| 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, 2021, and 2020. Amortization expense was $0.09 million for both nine-month periods ended September 30, 2021, and 2020.
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, |
| ||
|
| 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 –. In 2020, LE and LRM were each granted a two-month payment deferment on their respective Veritex loans. The moratorium was from April 2020 to June 2020. LE and LRM were not required to make payments during the deferment period. However, interest continued to accrue at the stated rates of the loans. In July 2020, Veritex re-amortized the loans to recast principal and interest payments. Veritex also reinstated previous defaults. See ‘Defaults’ within this “Note (10) for additional disclosures related to defaults.
SBA EIDLs. The SBA EIDLs include a payment deferral period. Interest accrues during the deferral period. The deferral period for the BDEC Term Loan Due 2051 is the first eighteen (18) months; principal and interest payments begin in December 2022. The deferral period for the LE Term Loan Due 2051 and the NPS Term Loan Due 2050 is the first twenty-four (24) months; principal and interest payments begin in September 2022.
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 lien on Nixon facility’s business assets (excluding accounts receivable and inventory) • Assignment of all Nixon facility contracts, permits, and licenses • Absolute assignment of Nixon facility rents and leases, including tank rental income • $1.0 million payment reserve account held by Veritex • $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 lien on real property interests of LRM • First lien on all LRM fixtures, furniture, machinery, and equipment • First lien on all LRM contractual rights, general intangibles, and instruments, except for LRM rights in its leases of certain specified tanks for which Veritex has second priority lien • 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 2051 | • 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)Veritex required Jonathan Carroll personally guarantee repayment of borrowed funds and accrued interest for the LE Term Loan Due 2034 and LRM Term Loan Due 2034.
(2)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.
(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. 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. USDA regulations require that Veritex, as the lender, retain both the guaranteed and unguaranteed portions of the loan, service the entire underlying loan, and remain mortgage or secured party of record. The same collateral must secure both the guaranteed and unguaranteed parts of the loan with equal lien priority. Borrowers cannot pay or otherwise subordinate the USDA-guaranteed portion of a loan to the unguaranteed portion. See “Notes (3) and (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 Kissick Debt and the Equipment Loan Due 2025.
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 past-due obligations; loan matured January 2019 | --- |
Veritex Loans. As reflected in the table above and elsewhere in this filing, the LE Term Loan Due 2034 and LRM Term Loan Due 2034 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. AnyWe classified the debt associated with the LE Term Loan Due 2034 and LRM Term Loan Due 2034 within the current portion of long-term debt on our consolidated balance sheets at September 30, 2021, and December 31, 2020. 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 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. Veritex exercising its rights would also adversely impactIn such a case, the trading price of our common stock and the value of an investment in our common stock whichcould significantly decrease. These adverse market actions could lead to holders of our common stock losing their investment in its 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 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.
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 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. The borrowers continue in active dialogue with Veritex. AsSee “Notes (1) and (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 the filing dateoperations.
(11) Line of this report, paymentsCredit Payable
On October 4, 2021, NPS repaid all obligations owed to Pilot under the Veritex loans wereAmended 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 but other defaults remained outstanding.
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% | 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, – Upon maturitywhich represents outstanding principal and accrued interest, as of the dates indicated was as follows:
|
| 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, 2021 │Page 28 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Guarantees and Security
Loan Description | Guarantees | Security |
Amended Pilot Line of Credit (in default) | • Blue Dolphin pledged its equity interests in NPS to Pilot to secure NPS’ obligations; • Blue Dolphin, LE, LRM, and LEH have each guaranteed NPS’ obligations. | • NPS receivables; • NPS assets, including a tank lease (the “Tank Lease”); • LRM receivables. |
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 particular tank lease agreement if Veritex were to foreclose on LE property that NPS was leasing from LE so long as LE met certain 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, to date, such USDA concurrence has 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 past-due obligations; loan matured May 2020 | --- |
NPS was in default under the Amended Pilot Line of 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 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 “Pilot Obligations”). 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 of 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 a June 1, 2020 notice,NPS’ default under the Amended Pilot began applying Pilot’s payment obligationsLine of Credit, Pilot applied payments owed to NPS under each of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77, and 78), dated as of May 2019, between NPS and Pilot, and (b) the Terminal Services Agreement (covering Tank No. 56), dated as of June 1, 2019, between NPS and Pilot,two terminal services agreements against NPS’ payment obligations to Pilot under the Amended Pilot Line of Credit. Such tank lease setoff amounts only partially satisfy NPS’ obligations under the Amended Pilot Line of Credit and Pilot expressly retained and reserved all its rights and remedies availablefrom June 2020 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.September 2021. For theboth three-month periods ended March 31,September 30, 2021, and 2020, the tank lease payment setoff amounts totaled $0.6 million and $0, respectively.million. For the three-monthnine-month periods ended March 31,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 $0.3$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.
In November 23, 2020, Pilot notified NPS and guarantors received notice from Pilot that theLE and NPS’ entry into the SBA EIDLsLE Term Loan Due 2050 and NPS Term Loan Due 2050 was a breach of the Amended Pilot Line of Credit andCredit; Pilot demanded full repayment of the Pilot Obligations, including through the use of the proceeds of the SBA EIDLs.EIDL loan proceeds. Pilot also notified the SBA that the liens securing the SBA EIDLs areLE Term Loan Due 2050 and NPS Term Loan Due 2050 were junior to thoseliens securing the Pilot Obligations. While the SBA acknowledged this point and indicated a willingness to subordinate the SBA EIDLs,these loans to Pilot, Pilot has taken no further action has been taken by Pilotactions 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. NPS and guarantors continue in active dialogue with Pilot to reach a negotiated settlement, and we believe that Pilot hopes to continue working with NPS to settle the Pilot Obligations. NPS and guarantors are also working on the possible refinance of amounts owing and payable under the Amended Pilot Line of Credit. However, progress with potential lenders has been slow due to the ongoing COVID-19 pandemic. NPS’s ability to repay, refinance, replace or otherwise extend this credit facility is dependent on, among other things, business conditions, our financial performance, and the general condition of the financial markets. Given the current financial markets, we could be forced to undertake alternate financings, including a sale of additional common stock, negotiate for an extension of the maturity, or sell assets and delay capital expenditures in order to generate proceeds that could be used to repay such indebtedness. We can provide no assurance that we will be able to consummate any such transaction on terms that are commercially reasonable, on terms acceptable to us or at all. If new debt or other liabilities are added to the Company’s current consolidated debt levels, the related risks that it now faces could intensify. In the event we are unsuccessful in such endeavors, NPS may be unable to pay the amounts outstanding under the Amended Pilot Line of Credit, which may require us to seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, which could lead to holders of our common stock losing their investment in our common stock in its entirety.
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Cash and cash equivalents | $521 | $549 |
| Restricted cash (current portion) | 48 | 48 |
| Restricted cash, noncurrent | - | 514 |
| Total | $569 | $1,111 |
(12) AROs
Refinery and Facilities
We believe we safely completed a 5-year capital improvement expansion project of the Nixon facility that included construction of new storage tanks, smaller efficiency improvements, and the acquisition of refurbished refinery equipment for later deployment. We typically make ongoing improvements to the Nixon facility based on operational needs, technological advances, and safety and regulatory requirements. Additions to refinery and facilities assets are capitalized, and expenditures for repairs and maintenance are expensed as incurred. We record refinery and facilities at cost less any adjustments for depreciation or impairment. Adjustment of the asset and the related accumulated depreciation accounts are made for the refinery and facilities asset’s retirement and disposal, with the resulting gain or loss included in the consolidated statements of operations. For financial reporting purposes, depreciation of refinery and facilities assets is computed using the straight-line method using an estimated useful life of 25 years beginning when the refinery and facilities assets are placed in service. We did not record any impairment of our refinery and facilities assets for the periods presented.
Blue Dolphin Energy Company | September 30, 2021 │Page |
| Table of Contents |
Notes to Consolidated Financial Statements |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| LEH | ||
| June LEH Note (in default) | $9,588 | $9,446 |
| BDPL-LEH Loan Agreement | 6,974 | 6,814 |
| LEH Total | 16,562 | 16,260 |
| Ingleside | ||
| March Ingleside Note (in default) | 1,031 | 1,013 |
| Jonathan Carroll | ||
| March Carroll Note (in default) | 1,732 | 1,551 |
19,325 | 18,824 | |
| Less: Long-term debt, related party, current portion, in default | (16,351) | (16,010) |
| Less: Accrued interest payable, related party (in default) | (2,974) | (2,814) |
$- | $- | |
Three Months Ended March 31, | ||||
2021 | 2020 | |||
| (in thousands, except percents) | ||||
| Refinery operations | ||||
| LEH | $16,080 | 27.1% | $17,715 | 28.6% |
| Third-Parties | 42,403 | 71.3% | 43,182 | 69.6% |
| Tolling and terminaling | ||||
| Third-Parties | 930 | 1.6% | 1,103 | 1.8% |
$59,413 | 100.0% | $62,000 | 100.0% | |
Three Months Ended March 31, | ||
2021 | 2020 | |
| (in thousands) | ||
| Jonathan Carroll | ||
| Guaranty Fee Agreements | ||
| First Term Loan Due 2034 | $108 | $108 |
| Second Term Loan Due 2034 | 45 | 45 |
| March Carroll Note (in default) | 29 | 23 |
| LEH | ||
| BDPL-LEH Loan Agreement (in default) | 160 | 160 |
| June LEH Note (in default) | 182 | 25 |
| Ingleside | ||
| March Ingleside Note (in default) | 14 | 20 |
$538 | $381 | |
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Net revenue (excluding intercompany fees and sales) | ||
| Refinery operations | $58,483 | $60,897 |
| Tolling and terminaling | 930 | 1,103 |
| Total net revenue | 59,413 | 62,000 |
| Intercompany fees and sales | ||
| Refinery operations | (566) | (617) |
| Tolling and terminaling | 566 | 617 |
| Total intercompany fees | - | - |
Operation costs and expenses(1) | ||
| Refinery operations | (59,289) | (61,833) |
| Tolling and terminaling | (334) | (255) |
| Corporate and other | (54) | (59) |
| Total operation costs and expenses | (59,677) | (62,147) |
| Segment contribution margin (deficit) | ||
| Refinery operations | (1,372) | (1,553) |
| Tolling and terminaling | 1,162 | 1,465 |
| Corporate and other | (54) | (59) |
| Total segment contribution margin (deficit) | (264) | (147) |
General and administrative expenses(2) | ||
| Refinery operations | (301) | (304) |
| Tolling and terminaling | (68) | (68) |
| Corporate and other | (413) | (419) |
| Total general and administrative expenses | (782) | (791) |
| Depreciation and amortization | ||
| Refinery operations | (302) | (288) |
| Tolling and terminaling | (340) | (294) |
| Corporate and other | (51) | (51) |
| Total depreciation and amortization | (693) | (633) |
Interest and other non-operating expenses, net | ||
| Refinery operations | (598) | (741) |
| Tolling and terminaling | (452) | (770) |
| Corporate and other | (385) | (243) |
| Total interest and other non-operating expenses, net | (1,435) | (1,754) |
| Income (loss) before income taxes | ||
| Refinery operations | (2,573) | (2,886) |
| Tolling and terminaling | 302 | 333 |
| Corporate and other | (903) | (772) |
| Total loss before income taxes | (3,174) | (3,325) |
| Income tax expense | - | (15) |
| Net loss | $(3,174) | $(3,340) |
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Capital expenditures | ||
| Refinery operations | $- | $6 |
| Tolling and terminaling | - | 192 |
| Corporate and other | - | - |
| Total capital expenditures | $- | $198 |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Identifiable assets | ||
| Refinery operations | $45,186 | $48,521 |
| Tolling and terminaling | 18,527 | 18,722 |
| Corporate and other | 1,839 | 2,057 |
| Total identifiable assets | $65,552 | $69,300 |
Number Significant Customers | % Total Revenue from Operations | Portion of Accounts Receivable at March 31, | |
| (in thousands, except percents) | |||
| March 31, 2021 | 4 | 90% | $0 |
| March 31, 2020 | 4 | 94% | $0.6 million |
Three Months Ended March 31, | ||||
2021 | 2020 | |||
(in thousands, except percents) | ||||
| LPG mix | $6 | 0.0% | $- | 0% |
| Naphtha | 14,224 | 24.3% | 11,515 | 18.9% |
| Jet fuel | 16,080 | 27.5% | 17,715 | 29.1% |
| HOBM | 15,663 | 26.8% | 15,191 | 24.9% |
| AGO | 12,510 | 21.4% | 16,476 | 27.1% |
$58,483 | 100.0% | $60,897 | 100.0% | |
March 31, | December 31, | |
2021 | 2020 | |
| (in thousands) | ||
| Prepaid insurance | $556 | $1,182 |
| Prepaid crude oil and condensate | 383 | 2,249 |
| Prepaid easement renewal fees | 93 | 99 |
| Other prepaids | 28 | 34 |
$1,060 | $3,564 | |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Crude oil and condensate | $608 | $463 |
| Chemicals | 175 | 271 |
| Naphtha | 164 | 120 |
| AGO | 121 | 133 |
| Propane | 25 | 15 |
| LPG mix | 6 | 6 |
| HOBM | - | 54 |
$1,099 | $1,062 | |
March 31, | December 31, | |
2021 | 2019 | |
(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 | (15,861) | (15,220) |
57,792 | 58,433 | |
| CIP | 4,064 | 4,064 |
$61,856 | $62,497 | |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Unearned revenue from contracts with customers | $3,489 | $3,421 |
| Unearned contract renewal income | 400 | 500 |
| Insurance | 181 | 541 |
| Other payable | 176 | 252 |
| Customer deposits | 173 | 10 |
| Taxes payable | 137 | 58 |
| Board of director fees payable | 133 | 100 |
$4,689 | $4,882 | |
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 arbitration award payable to GEL | |
| 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 | |
Equipment Loan Due 2025(5) | LE-Texas First | $0.07 | Oct 2025 | $0.0013 million | 4.50% | Equipment Lease Conversion | |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | $23,104 | $22,840 |
LRM Term Loan Due 2034 (in default) | 9,601 | 9,473 |
| Notre Dame Debt (in default) | 9,613 | 9,413 |
| SBA EIDLs | ||
| LE Term Loan 2050 | 153 | 152 |
| NPS Term Loan 2050 | 153 | 152 |
| Equipment Loan Due 2025 | 65 | 71 |
42,689 | 42,101 | |
| Less: Current portion of long-term debt, net | (33,724) | (33,692) |
| Less: Unamortized debt issue costs | (1,718) | (1,749) |
Less: Accrued interest payable (in default) | (6,898) | (6,305) |
$349 | $355 | |
March 31, | 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 | (724) | (693) |
$1,718 | $1,749 | |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
Notre Dame Debt (in default) | $4,635 | $4,435 |
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | 1,559 | 1,295 |
LRM Term Loan Due 2034 (in default) | 698 | 571 |
| SBA EIDLs | ||
| LE Term Loan 2050 | 3 | 2 |
| NPS Term Loan 2050 | 3 | 2 |
6,898 | 6,305 | |
Less: Accrued interest payable (in default) | (6,898) | (6,305) |
| Long-term Interest Payable, Net of Current Portion | $- | $- |
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 |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
Amended Pilot Line of Credit (in default) | $7,272 | $8,145 |
| Less: Interest payable, short-term | (103) | (103) |
$7,169 | $8,042 | |
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. At March 31,The ARO liability was fully accreted at September 30, 2021, and December 31, 2020, 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:
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| AROs, at the beginning of the period | $2,370 | $2,565 |
| Liabilities settled | - | (195) |
2,370 | 2,370 | |
| Less: AROs, current portion | (2,370) | (2,370) |
| 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 a letter dated March 29,non-payment. In May 2021, BDSC and TR 801 Travis LLC a Delaware limited partnership, informed(“Building Lessor”) reached an agreement to cure BDSC’s office lease default. Under the terms of the May arrangement, BDSC that it was in default under its office lease. BDSC’s failureagreed to pay Building Lessor past due obligations, including rent installments and other charges constitutedtotaling 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 eventannual percentage rate of default. The parties reached4.50%. 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 agreementOctober 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 default. See “Note (17) Subsequent Events” tolease default, we can provide no assurance that our consolidated financial statements for additional disclosures related to the Houston office lease.
An Affiliate, LEH, subleases a portion of the Houston office space. SubleaseBDSC received sublease income received from LEH totaled approximatelytotaling $0.01 million for both the three months ended March 31,September 30, 2021, and 2020. Sublease income totaled $0.03 million for both nine-month periods ended September 30, 2021, and 2020. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.
Blue Dolphin Energy Company | September 30, 2021 │Page 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:
March 31, | 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 | (329) | (289) |
| Total lease assets | 458 | 498 | |
| Liabilities | |||
| Current | |||
| Operating lease | Current portion of lease liabilities | 199 | 194 |
199 | 194 | ||
| Noncurrent | |||
| Operating lease | Long-term lease liabilities, net of current | 319 | 370 |
| Total lease liabilities | $518 | $564 | |
|
|
|
| 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 | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Operating lease costs | $51 | $51 |
| Finance lease costs: | ||
| Depreciation of leased assets | - | 6 |
| Interest on lease liabilities | - | 2 |
| Total lease cost | $51 | $59 |
|
| 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 | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Cash paid for amounts included in the measurement | ||
| of lease liabilities: | ||
| Operating cash flows for operating lease | $47 | $88 |
| Operating cash flows for finance leases | $- | $2 |
| Financing cash flows for finance leases | $- | $6 |
|
| 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 March 31,September 30, 2021, maturities of lease liabilities for the periods indicated were as follows:
| March 31, | Operating Lease |
(in thousands) | |
| 2021 | $199 |
| 2022 | 220 |
| 2023 | 99 |
$518 |
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 | |
| March 31, | Lease |
(in thousands) | |
| 2021 | $233 |
| 2022 | 237 |
| 2023 | 101 |
$571 |
|
| Operating |
| |
September 30, |
| Lease |
| |
|
| (in thousands) |
| |
2021 |
| $ | 236 |
|
2022 |
|
| 220 |
|
2023 |
|
| 0 |
|
|
| $ | 456 |
|
(14)
Tax Provision
The provision for income tax expense for the periods indicated was as follows:
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Current | ||
| Federal | $- | $(15) |
| State | - | - |
| Deferred | ||
| Federal | 667 | 698 |
| State | - | |
| Change in valuation allowance | (667) | (698) |
| 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:
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Deferred tax assets: | ||
| NOL and capital loss carryforwards | $15,773 | $15,258 |
| Business interest expense | 3,693 | 3,343 |
| Start-up costs (crude oil and condensate processing facility) | 488 | 509 |
| ARO liability/deferred revenue | 498 | 498 |
| Other | 4 | 3 |
| Total deferred tax assets | 20,456 | 19,611 |
| Deferred tax liabilities: | ||
| Basis differences in property and equipment | (7,409) | (7,230) |
| Total deferred tax liabilities | (7,409) | (7,230) |
13,047 | (7,230) | |
| Valuation allowance | (13,047) | (12,381) |
| Deferred tax assets, net | $- | $- |
|
| 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, 2019 | 9,614 | 43,058 | 52,672 |
| Net operating losses | - | 13,305 | 13,305 |
| Balance at December 31, 2020 | $9,614 | $56,363 | $65,977 |
| Net operating losses | (1,718) | 2,456 | 738 |
| Balance at March 31, 2021 | $7,896 | $58,819 | $66,715 |
|
| 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 | ||
March 31, | ||
2021 | 2020 | |
(in thousands | ||
except share and per share amounts) | ||
| Net loss | $(3,174) | $(3,340) |
| Basic and diluted income (loss) per share | $(0.25) | $(0.27) |
| Basic and Diluted | ||
| Weighted average number of shares of | ||
common stock outstanding and potential | ||
| dilutive shares of common stock | 12,693,514 | 12,327,365 |
|
| 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 March 31,September 30, 2021, and 2020 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. Although we planned to decommission thedecommissioning activities for 2020, offshore pipelinesweather conditions and platform assets during 2020, decommissioning of these assets has been delayed due to cash constraints associated with the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico.pandemic led to delays. We cannot currently estimate when decommissioning maywill occur. In the interim, BDPL provides BSEE with updates regarding the project’s status.
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 March 31,September 30, 2021. At both March 31,September 30, 2021, and December 31, 2020, BDPL maintained $2.4 million in AROs related to abandonment ofdecommissioning these assets.
Defaults Under Secured Loan Agreements with Third Parties
See “Notes (1), (3), (10), and (11)” to our consolidated financial statements for additional disclosures related to defaults under our secured and unsecured debt agreements.
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Notes to Consolidated Financial Statements |
Financing Agreements and Guarantees
Indebtedness
. See “Notes (1), (3), (10), and (11)” to our consolidated financial statements for disclosures related to Affiliate and third-party indebtedness and defaults thereto.Guarantees
. 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. These 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 resolve the INCs.resolved. Although we planned to decommission thedecommissioning activities for 2020, offshore pipelinesweather conditions and platform assets during 2020, decommissioning of these assets has been delayed due to cash constraints associated with the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico.pandemic led to delays. We cannot currently estimate when decommissioning maywill occur. In the interim, BDPL provides BOEMFurther, we cannot currently estimate when we can provide additional financial assurance (supplemental pipeline bonds).
Financial constraints and BSEE with updates regarding the project’s status.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of March 31,September 30, 2021. At both March 31,September 30, 2021, and December 31, 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)
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 termsaggregate principal amount of the arrangement, BDSC will pay TR 801 Travis LLC past due obligations, including rent installments and other charges totaling approximately $0.1$10.0 million (the “Past Due Obligations”“NPS Loan”), effective October 1, 2021. The NPS Loan has a ten-year term with a fixed interest rate of 5.75%. The loan requires monthly interest-only payments beginning in equal monthly installments beginning June 1,October 2021 and continuing through the August 31, 2023 lease expiration date. The Past Due Obligations shall be subject to an annual percentage rate of 4.50%. As revised, BDSC’ monthly base rent plus the prorated portion of the Past Due Obligations will approximate $0.02 million.
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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 accrues at the rate of 3.75% per annumagreement and will accrue from the date of loan. Installment payments, including principalassociated pledge agreement, subordination agreement, and interest, total $.003 million per month and will begin eighteen (18) months from the date of the loan. The balance of principal and interest is payable over a 30-year term. SBA EIDLs are not forgivable. Jonathan Carroll and LEH, an Affiliate, provided gurantees of the debt. The debt is subject to certain customary covenants and default provisions.
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Management’s Discussion and Analysis | ||||
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, 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, withand 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”.
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). For more information related to our business segments, 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, one or more of Blue Dolphin’s subsidiaries, or all of them taken as a whole
Affiliates
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 and funds 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 “Part I, Item 1. Financial Statements – Note (3)” for additional disclosures related to Affiliate agreements, arrangements, and risks associated with working capital deficits.
Business Operations Update
General Business Environment. In early 2020, the outbreak ofglobal and national measures taken to address the COVID-19 pandemic, negatively impacted worldwide economicincluding government-imposed temporary business closures and commercial activity and financial markets, as well as global demand for petroleum products. As a resultvoluntary shelter-at-home directives, caused oil prices to decline sharply. In addition, actions by members of commodity price volatility and decreased demand for our products, our business results and cash flows were significantly adversely impacted by the COVID-19 pandemic in 2020 and throughout the first quarter of 2021. As vaccine rollouts ramp up around the world, travel restrictions are pared back, and OPEC and other producer countries re-balance inventories, wein 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 cautiously optimisticforecasted 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 global economy, oil demand, and commodity prices will recover from theongoing impact of the pandemic.
We can provide no guarantees that: our business strategy will be successful, Affiliates will continue to fund our working capital needs when we experience working capital deficits, we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and related market developments is unknown. The continued negative impact of these eventsdecommission offshore pipelines and platform assets, we will be able to obtain additional financing on commercially reasonable terms or at all, or margins on our businessrefined products will be favorable. Further, if Veritex exercises its rights and operations will depend on the ongoing severity, location and duration of the effects and spread of COVID-19, the effectiveness of vaccine programs, other actions undertaken by federal, state, and local governments and health officials to contain the virus or treat its effects, and how quickly and to what extent economic conditions improve and normal business and operating conditions resume in 2021 or thereafter. Non-compliance with applicable environmental and safety requirements, including as a result of reduced staff due to an outbreak of the virus at one ofremedies under our locations, may impairsecured loan agreements, our operations, subject us to fines or penalties assessed by governmental authorities, and/or result in an environmental or safety incident. We may also be subject to liability as a result of claims against us by impacted workers or third parties. The foregoing and other continued disruptions to our business as a result of the COVID-19 pandemic could result in a material adverse effect on our business, result of operations, financial condition, cash flows, and our ability to service our indebtedness and other obligations. There can also be no assurance that our liquidity, business, financial condition, and results of operations will revert to pre-2020 levels once the impacts of the COVID-19 pandemic cease.
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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. As discussed more fully below, theseThese factors include inadequate liquidity to sustain operations due to defaults under our secured loan agreements, margin deterioration and volatility, and historichistorical net losses and working capital deficits.deficits, as discussed more fully below. Our consolidated financial statements assume we will continue as a going concern and do not include any adjustments that might result from the outcome of this uncertainty. Our ability to continue as a going concern depends on sustained positive operating margins and havingadequate working capital for, amongst other requirements, purchasing crude oil and condensate and making payments on long-term debt. Without positive operating margins and working capital, our business will be jeopardized, and we may not be able to continue. If we are unable to process crude oil and condensate into sellable refined products or make required debt payments, we would likely have tomay consider other options. These options such asmight include selling assets, raising additional debt or equity capital, cutting costs, or otherwise reducing our cash requirements, restructuring debt obligations, or negotiating with our creditors to restructure our applicable obligations, including a potential bankruptcy filing.
Defaults Under Secured Loan Agreements
. We are currently in default under certain of our secured loan agreements with third parties and related 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 Veritex, either upon maturity or if accelerated, (ii) LE and LRM will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder, will provide future default waivers. The borrowers continue in active dialogue with Veritex.
As of the filing date of this report, payments under the Veritex loans were current, but other defaults remained outstanding.
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, 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 being in default. As a result, these debt obligations were classified within the current portion of long-term debt on our consolidated balance sheets at September 30, 2021, and December 31, 2020.
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Management’s Discussion and Analysis |
Margin Deterioration and Volatility
Historic Net Losses and Working Capital Deficits
.Net Losses
Net loss for the three months ended March 31,September 30, 2021, was $3.4$2.9 million, or a loss of $0.27$0.23 per share, compared to a net loss of $3.3$4.7 million, or a loss of $0.27$0.37 per share, for the three months ended March 31, 2020. Net losses in both periods were the result of unfavorable refining margins per bbl. The net loss during the three months ended March 31,September 30, 2020. Net loss for the nine months ended September 30, 2021, was also due$10.2 million, or a loss of $0.80 per share, compared to 10 daysa net loss of refinery downtime associated with Winter Storm Uri.
Working Capital Deficits
We had a working capital deficit of $74.3$79.8 million and $72.3 million in working capital deficits at March 31,September 30, 2021, and December 31, 2020, respectively. Excluding the current portion of long-term debt, we had a working capital deficit of $24.2$26.2 million and $22.6 million in working capital deficits at March 31,September 30, 2021, and December 31, 2020, respectively.
Cash and cash equivalents restrictedtotaled $2.2 million and $0.5 million at September 30, 2021, and December 31, 2020, respectively. Restricted cash (current portion), totaled $0.05 million at both September 30, 2021, and restrictedDecember 31, 2020. Restricted cash, noncurrent were as follow:
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Cash and cash equivalents | $521 | $549 |
| Restricted cash (current portion) | 48 | 48 |
| Restricted cash, noncurrent | - | 514 |
| Total | $569 | $1,111 |
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 risks.
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 “Part I, Item 1. Financial Statements – Note (1)” under “Going Concern” 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,we remained open. As U.S. federal, state, and local officials roll out COVID-19 vaccines,If future restrictive directives become necessary, we expect to continue operating. AnyHowever, additional 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. We are 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. At the Nixon facility, we adjust throughput and production based on prevailing market conditions. With regard toTo safeguard personnel, we have adopted remote working where possible. Where on-site operations are required, personnel are required to wear maskspossible and practice social distancing. We also implementeddistancing, mask-wearing, and other site-specific precautionary measures where on-site operations are required. We also incentivize personnel to reducereceive the risk of exposure and have restricted non-essential business travel. Personnel, customers, and partners are also encouraged to collaborate virtually.
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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Management’s Discussion and Analysis |
Business Strategy
Our primary business objective is to improve our financial profile by executing the below strategies, modified as necessary, to reflect changing economic conditions and other circumstances:
Optimize Existing Asset Base | • Operate safely and • Planning and managing turnarounds and downtime. | ||
Improve Operational Efficiencies | |||
• Reduce or • Increase throughput capacity and • 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 Biden Administration, the focus on cleaner energy sources and technology to decarbonize resource-intensive industries continues to accelerate. This focus is steering government policy to incentivize clean energy sources and carbon capture technologies, as well as supporting new industry-wide investment in areas like renewables, green hydrogen, and carbon capture, utilization, and storage. During the firstthird quarter of 2021, we maintained safe and reliable operations at the Nixon facility. COVID-related social distancing measures presented unique challenges. However, we successfully balanced protecting personnel from exposure to COVID-19 and related variants and ensuring adequate staffing levels to operate the plant. Refinery downtime decreased to 6 days in the third quarter of 2021 compared to 11 days in the third quarter of 2020.
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 opportunitiesoptions to position Blue Dolphin in the global transition to cleaner, lower-carbon alternatives from traditional fossil fuels. These opportunities may include technology, development, or commercial partnerships, as well as the repurposing of assetsfuels through collaboration and facilities, for the production, storage, transportation and sale of alternative fuels and other low-carbon products.
Successful execution of our business strategy depends on several keyfactors. These factors including,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. There can be no assuranceOur business strategy involves risks. Accordingly, we cannot assure investors that our business strategyplans will be successful, including a pivot to renewables through LEAF, that Affiliates will continue to fund our working capital needs when we experience working capital deficits, that we will meet regulatory requirements to provide additional financial assurance (supplemental pipeline bonds) and decommission offshore pipelines and platform assets, that we will be able to obtain additional financing on commercially reasonable terms or at all, or that margins on our refined products will be favorable. Further, if Veritex and/or Pilot exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
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 foreseeable future. Management has determined that conditions exist that raise substantial doubt about our ability to continue as a going concern due to defaults under our secured loan agreements, 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 long-term debt. If we are unable tocannot achieve these goals, our business would be jeopardized, we may not be able to continue operating, and we may have to cease operating or seek bankruptcy protection.
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 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.
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 (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.
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. 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.
Blue Dolphin Energy Company | September 30, 2021 │Page 41 |
| Table of Contents |
Management’s Discussion and Analysis |
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.other.’ We fully impaired our pipeline assets in 2016 and our oil and gas leasehold interests in 2011. Our pipeline assets and oil and gas leasehold interests had no revenue during the three and nine months ended March 31,September 30, 2021, and 2020. See “Part I, Item 1. Financial Statements – Note (16)” related to pipelines and platform decommissioningabandonment requirements and relatedassociated risks.
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.
We present below a discussion and analysis of the factors contributing to our consolidated financial results of operations is presented below andoperations. Investors should be in read this section in conjunction with our financial statements in “Part I, Item 1. Financial Statements”. The financial statements, togetherWhen 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
. Our results of operations and liquidityBlue Dolphin Energy Company | September 30, 2021 │Page 42 |
| Table of Contents |
Management’s Discussion and Analysis |
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 Results of Operationssection and the financial statements within “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.
Remainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | September 30, 2021 │Page |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Consolidated Results
.Our consolidated results of operations include certainThree Months Ended | Nine Months Ended September 30, 2021 Versus September 30, 2020 (9 Months 2021 Versus 9 Months 2020) | |
Overview . Net loss for | Overview. Net and decreased interest and other expense also contributed to the improvement between the periods. | |
Total Revenue from Operations. Total revenue from operations | 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 $126.2 million for | |
Gross Profit. Gross profit was $0.3 million for Q3 2021 compared to a gross deficit of $1.5 million for Q3 2020. The significant improvement resulted from more stable commodity prices and improved sales volumes from economic recovery. | Gross Deficit. Gross deficit | |
General and Administrative Expenses . General and administrative expenses | 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, representing an increase of approximately $0.1 million. The increase related to placing refinery assets in | |
Total Other Expense. Total other expense increased slightly in Q3 2021 | Total Other Expense. Total other expense was $4.7 million in 9 Months 2021 compared to $4.9 million in 9 Months 2020, representing a decrease of approximately $0.2 million. The decrease primarily related to lower Pilot interest expense. Total other expense in both periods primarily related to interest expense associated with secured loan agreements with Veritex, related-party debt, and the line of credit with Pilot. |
Blue Dolphin Energy Company | September 30, 2021 │Page |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Downstream Operations
.Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Refined product sales | $58,483 | $60,897 |
| Less: Total cost of goods sold | (59,623) | (62,088) |
| Gross deficit | (1,140) | (1,191) |
| Sales (Bbls) | 948 | 1,141 |
| Gross Deficit per Bbl | $(1.20) | $(1.04) |
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
Net revenue (1) | $58,483 | $60,897 |
| Intercompany fees and sales | (566) | (617) |
| Operation costs and expenses | (59,289) | (61,833) |
| Segment Contribution Deficit | $(1,372) | $(1,553) |
|
| 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) Net revenue excludes intercompany crude sales.
Q3 2021 Versus Q1Q3 2020
· | Refining gross deficit per bbl was $0.61 for Q3 2021 compared to gross deficit per bbl of $2.45 in Q3 2020, representing an improvement of $1.84 per bbl. The improvement between the periods related to higher refining margins; sales volume was relatively flat. Commodity prices and refined product demand experienced a recovery in Q3 2021 compared to Q3 2020 as more businesses resumed operations and pandemic-related restrictions lifted. |
· | 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 sales.
9 Months 2021 compared to gross deficit per bbl of $1.04 in Q1Versus 9 Months 2020 representing a decline of $0.16 per bbl. The deficit in both periods related to lower
· | 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, 2021 │Page 45 |
| Table of Contents |
Management’s Discussion and Analysis |
Midstream Operations. LRM and market fluctuations associated with the COVID-19 pandemic. Refinery downtime associated with Winter Storm Uri also caused an increase in gross deficit per bbl in Q1 2021.
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
Net revenue (1) | $930 | $1,103 |
| Intercompany fees and sales | 566 | 617 |
| Operation costs and expenses | (334) | (255) |
| Segment Contribution Margin | $1,162 | $1,465 |
|
| 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) Net revenue excludes intercompany crude sales.
Q3 2021 Versus Q1Q3 2020
· | 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 16% in Q1excludes intercompany crude sales.
9 Months 2021 compared to Q1Versus 9 Months 2020 primarily as a result of lower tank rental revenue.
· | 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, 2021 │Page |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Non-GAAP Reconciliations
.Reconciliation of Segment Contribution Margin (Deficit) |
Three Months Ended March 31, | ||||||||
2021 | 2020 | 2021 | 2020 | 2021 | 2020 | 2021 | 2020 | |
Refinery Operations | Tolling and Terminaling | Corporate and Other | Total | |||||
| (in thousands) | ||||||||
| Segment contribution margin (deficit) | $(1,372) | $(1,553) | $1,162 | $1,465 | $(54) | $(59) | $(264) | $(147) |
General and administrative expenses(1) | (301) | (304) | (68) | (68) | (413) | (419) | (782) | (791) |
| Depreciation and amortization | (302) | (288) | (340) | (294) | (51) | (51) | (693) | (633) |
| Interest and other non-operating income (expenses), net | (598) | (741) | (452) | (770) | (385) | (243) | (1,435) | (1,754) |
| Income (loss) before income taxes | (2,573) | (2,886) | 302 | 333 | (903) | (772) | (3,174) | (3,325) |
| Income tax expense | - | - | - | - | - | (15) | - | (15) |
| Income (loss) before income taxes | $(2,573) | $(2,886) | $302 | $333 | $(903) | $(787) | $(3,174) | $(3,340) |
|
| 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 and Liquidity
We had a working capital deficit of $74.3$79.8 million and $72.3 million in working capital deficits at March 31,September 30, 2021, and December 31, 2020, respectively. Excluding the current portion of long-term debt, we had a working capital deficitdeficits of $24.2$26.2 million and $22.6 million at March 31,September 30, 2021, and December 31, 2020, respectively. Although in place pre-pandemic,During the third quarter of 2021, we have further tightened ourcontinued efforts to conserve cash conservation program to manage cash flowamid lower refined product sales. Mitigation steps include: adjusting throughput and remain competitive in a low oil price environment. This includesproduction based on market conditions, optimizing receivables and payables by prioritizing payments, managing inventory to avoid buildup, delaying capital spending, and monitoring discretionary spending and delaying capital expenditures. Despite this focus, management is keeping in mind the overall safety of our operations and personnel, as well as the impact to our business over the long-term.
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 working capital deficit, we have historically relied on Affiliates to meet our liquidity needs. We are actively exploring additional financing; however,financing, including potential financing options made available under the Coronavirus Aid, Relief, and Economic Security Act, also known as the CARES Act. However, we currently have no arrangements forcannot assure success in raising additional capital and no assurances can be givenor that wesuch additional funds will be able to raise sufficient capital when needed,available on acceptable terms, orif at all. IfWe may further default on certain of our existing debt obligations if we are unable tocannot raise sufficient additional capital in the very near term, we may further default on our payment obligations under certain of our existing debt obligations. term. Without additional financing, it remains unclear whether we will have or can obtain sufficient liquidity to withstand further disruptions to our business.
How long and to what extent COVID-19 and related market developments will continue to affect our business and operations is unknown. The overallWith 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 future financial position and results of operations. Accordingly, we believe these events will dependfactors could have a material adverse effect on our financial results for the actionsremainder of federal, state,2021 and local governmentinto 2022.
Our ability to continue as a going concern depends on sustained positive operating margins and health officialsworking capital to contain and treat the virus, including deploymentsustain operations, purchase of vaccines, and how quickly economic conditions improve thereafter. A sustained period of low crude oil prices due to market volatility associated with the COVID-19 pandemic may also result in significant financial constraints on producers, which could result in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate, when needed will have a material effectand payments on our business results and operations. As a result,long-term debt. If we cannot achieve these goals, we may have tocease operating or seek protection under bankruptcy laws. In such a case, the trading price of our common stock and the value of an investment in our common stock could significantly decrease, whichprotection. These adverse market actions could lead to holders of our common stock losing their investment in our common stock in its entirety.
Blue Dolphin Energy Company | September 30, 2021 │Page |
| Table of Contents |
Management’s Discussion and Analysis | ||||
Debt Overview
.Total Debt and Accrued Interest |
March 31, | December 31, | |
2021 | 2020 | |
(in thousands) | ||
| Veritex Loans | ||
LE Term Loan Due 2034 (in default) | $23,104 | $22,840 |
LRM Term Loan Due 2034 (in default) | 9,601 | 9,473 |
Amended Pilot Line of Credit (in default) | 7,272 | 8,145 |
Notre Dame Debt (in default) | 9,613 | 9,413 |
| Related-Party Debt | ||
BDPL Loan Agreement (in default) | 6,974 | 6,814 |
March Ingleside Note (in default) | 1,031 | 1,013 |
March Carroll Note (in default) | 1,732 | 1,551 |
June LEH Note (in default) | 9,588 | 9,446 |
| LE Term Loan Due 2050 | 153 | 152 |
| NPS Term Loan Due 2050 | 153 | 152 |
| Equipment Loan Due 2025 | 65 | 71 |
| Total Debt | 69,286 | 69,070 |
| Less: Current portion of long-term debt, net | (57,244) | (57,744) |
| Less: Unamortized debt issue costs | (1,718) | (1,749) |
Less: Accrued interest payable (in default) | (9,975) | (9,222) |
$349 | $355 | |
|
| 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 usedconstraints associated with COVID-19, payments on debt in financing activities2021 were minimal totaling $0.004 million in Q3 2021 and $0.013 million in 9 Months 2021. Comparatively, payments on debt in 2020 totaled $0.9 million in Q1Q3 2020 and $2.4 million in 9 Months 2020. We received government assistance from CARES Act loans in both 2021 and 2020. For 9 Months 2021, proceeds from issuance of debt totaled $0.5 million compared to $0.7 million provided by financing activities in Q1 2020. Principal payments on long-term debt totaled $0.9$0.3 million in Q19 Months 2020. In 9 Months 2021, compared to $0.7 millionwe received a single SBA EIDL loan; in Q1 2020. As of the filing date of this report, LE and LRM were in default with respect to required monthly payments under secured loan agreements with Veritex. NPS is making partial monthly payments to Pilot under the Amended Pilot Line of Credit as a tank lease setoff using amounts Pilot owed to NPS under9 Months 2020 we received two tank lease agreements. No payments have been made under the subordinated Notre Dame Debt.
Debt Defaults
. The majority of our debt is in default. Defaults underNumber Significant Customers | % Total Revenue from Operations | Portion of Accounts Receivable at March 31, | |
| March 31, 2021 | 4 | 90% | $0 |
| March 31, 2020 | 4 | 94% | $0.6 million |
Contractual Obligations
.Related-Party Debt
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 |
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 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 |
| Equipment Loan Due 2025 | LE-Texas First | $0.07 | Oct 2025 | $0.0013 million | 4.50% | Equipment Lease Conversion |
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, 2021 │Page 49 |
| 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 resolve the INCs.resolved. Although we planned to decommission thedecommissioning activities for 2020, offshore pipelinesweather conditions and platform assets during 2020, decommissioning of these assets has been delayed due to cash constraints associated with the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico.pandemic led to delays. We cannot currently estimate when decommissioning maywill occur. In the interim, BDPL provides BOEMFurther, we cannot currently estimate when we can provide additional financial assurance (supplemental pipeline bonds).
Financial constraints and BSEE with updates regarding the project’s status.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of March 31,September 30, 2021. At both March 31,September 30, 2021, and December 31, 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 |
| 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. Although we planned decommissioning activities for 2020, offshore weather conditions and cash constraints associated with the ongoing COVID-19 pandemic led to delays. We cannot currently estimate when decommissioning will 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 associated with the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico. We cannot currently estimate when decommissioning may occur. In the interim, BDPL provides BSEE with updates regarding the project’s status.
We are currently unable to predict the outcome of the BSEE INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of March 31,September 30, 2021. At both March 31,September 30, 2021, and December 31, 2020, BDPL maintained $2.4 million in AROs related to abandonment ofdecommissioning these assets.
Sources and Use of Cash
.Components of Cash Flows |
Three Months Ended | ||
March 31, | ||
2021 | 2020 | |
(in thousands) | ||
| Cash Flows Provided By (Used In): | ||
| Operating activities | $373 | $(259) |
| Investing activities | - | (198) |
| Financing activities | (915) | 654 |
| Increase (Decrease) in Cash and Cash Equivalents | $(542) | $197 |
|
| 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 Q1 2021 Compared to Q1 2020
We had cash flow from operations of approximately $0.3$4.1 million for Q1Q3 2021 compared to aapproximately $1.7 million for Q3 2020. The improvement in cash flow from operations between the three-month comparative periods primarily related to an increase in unearned 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 cash flow deficit of approximately $0.3 million for Q1 2020. Cash frow from operations for Q1 2021 was due tobetween the timing of crude oil purchases. The cash flow deficit for Q1 2020nine-month periods primarily related to loss from operations.
Capital Expenditures
During Q1Q3 2021, capital expenditures totaled $0 compared to $0.2 million during Q1Q3 2020. During 9 Months 2021, capital expenditures totaled $0 compared to $1.1 million during 9 Months 2020. Capital expenditures in Q1during 2020 primarily related to completion of a petroleum storage tank. In view oftank and a maintenance turnaround. We completed the 5-year Nixon capital improvement expansion project during 9 Months 2020. Given the uncertainty surrounding the COVID-19 pandemic, combined with the weakervolatile commodity price environment, we anticipate new capital expenditures to be minimal in 2021.
We account for our capital expenditures in accordance withper GAAP. We also classify capital expenditures as ‘maintenance’ if the expenditure maintains capacity or throughput or as ‘expansion’ if the 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 |
| 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 “Part I, Item 1. Financial Statements – Note (2)”. The ongoing COVID-19 pandemic and related governmental responses, volatility in commodity prices, and severe weather resulting from climate change have impacted and likely will continue to impact our business. Under earlier stateAlthough management cannot predict the impact these factors will have on our future financial position and federal mandates that regulated business closures, our business was deemed as an essential business and, as such, remained open. As U.S. federal, state, and local officials roll out COVID-19 vaccines, we expect to continue operating. We have instituted various initiatives throughout the company as partresults 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 2021 and beyond.
We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of COVID-19 as of March 31,September 30, 2021, 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)”.
Remainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | September 30, 2021 │Page 52 |
| Table of Contents |
Internal Controls |
ITEM 3. QUANTITATIVE ANDAND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not applicable.
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, 2020, 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 report. Management is currently evaluating internal processes in orderHowever, management has taken corrective actions to take corrective actions.remedy both the significant deficiency and material weakness. Corrective actions may include included implementing formal policies, improvingend of month processes documenting procedures,to 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 months ended March 31, 2021 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting. (SeeSeptember 30, 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, 2021 │Page |
| Table of Contents |
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 the August 15, 2019 meeting may help in future discussions with BOEM related to the INCs.once BDPL reasonably expects that successful completion of its decommissioning obligations (discussed within this “Note (16)” under ‘BSEE Offshore Pipelines and Platform Decommissioning’) prior to BSEE’s August 2020 deadline will significantly reduce or eliminatecompletes 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.
Financial constraints and BDPL’s pending appeal of the BOEM INCs doesdo not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BOEM requires BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds)security or is assessedassesses significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we have not recorded a liability on our consolidated balance sheet as of March 31, 2020.September 30, 2021. At March 31, 2020both September 30, 2021, 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 is in discussioncommunicates with all concerned parties and does not believe that suchthese matters will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurancewe cannot assure that such discussionscommunications 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.
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, 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. ThereExcept for 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, 2020.
Our future results could be adversely affected if we cannot effectively execute new business strategies, such as renewable fuels.
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 incentives; substantive upfront capital investments; permitting challenges; product market identification; competition; supply chain issues; environmental impact assessment requirements; construction and implementation delays; technology deployment failure; and environmental and ecological consequences. These risks and uncertainties could adversely affect anticipated results and benefits of our renewable fuels business strategy.
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None.
See “Part I, Item. 1. Financial Statements – Notes (10) and (11)” for disclosures related to defaults on our debt.
Not applicable.
None.
ITEM 6. EXHIBITS
Exhibits Index
No. | Description |
| 31.1* | ||
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. |
*
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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) | |||||
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