UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended
March 31,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)12(b) of the Act:
Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
Common Stock, par value $0.01 per share | BDCO | OTCQX |
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☒
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☒
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer | ☐ | Accelerated filer | ☐ |
Non-accelerated | ☐ | 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, 2021: 12,693,514
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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 Ingleside and Lazarus Capital) and/or LEH and its affiliates (including LMT and LTRI). Together, Jonathan Carroll and LEH owned approximately 82% of the Common Stock as of the filing date of this report.
AMT. Alternative Minimum Tax.
Amended Pilot Line of Credit. Line of Credit Agreement dated May 3, 2019, between Pilot and NPS and subsequently amended on May 9, 2019, May 10, 2019, and September 3, 2019, the last amendment being Amendment No. 1; original line of credit amount was $13.0 million; NPS repaid all obligations owed to Pilot on October 4, 2021.
Amended and Restated Operating Agreement. Affiliate agreement between Blue Dolphin, LE, LRM, NPS, BDPL, BDPC, BDSC and LEH governing LEH’s operation and management of those companies’ assets; three-year term effective April 1, 2020 expiring April 1, 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.
ARO. Asset retirement obligations.
ASU. Accounting Standards Update.
AGO. Atmospheric gas oil, which is the heaviest product boiled by a crude distillation tower operating at atmospheric pressure. This fraction ordinarily sells as distillate fuel oil, either in pure form or blended with cracked stocks. Certain ethylene plants, called heavy oil crackers, can take AGO as feedstock.
bbl. Barrel; a unit of volume equal to 42 U.S. gallons.
BDPC. Blue Dolphin Petroleum Company, a wholly owned subsidiary of Blue Dolphin.
BDPL. Blue Dolphin Pipe Line Company, a wholly owned subsidiary of Blue Dolphin.
BDPL-LEH Loan Agreement. Loan Agreement dated August 15, 2016, between BDPL and LEH in the original principal amount of $4.0 million; interest accrues at 16% annually; guaranteed by certain BDPL property; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type; matured August 2018; currently in default for failure to pay past due obligations at maturity.
BDSC. Blue Dolphin Services Co., a wholly owned subsidiary of Blue Dolphin.
BDSC-LEH Office Sub-Lease Agreement. Office sublease agreement in Houston, Texas between BDSC and LEH; sixty-eight -month term effective January 1, 2018 expiring August 31, 2023; includes 6-month rent abatement period; rent approximately $0.003 million per month
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.
BDEC Term Loan Due 2051 (as modified). An EIDL dated May 4, 2021 between Blue Dolphin and the SBA in the original principal amount of $0.5 million; the note was modified in February 2022 to increase the principal amount to $2.0 million; additional principal used for working capital; interest accrues at 3.75%; maturity date May 2051; monthly principal and interest payment $0.01 million; payments deferred first thirty (30) months; interest accrues during deferral period; first payment due December 2023; loan not forgivable; security includes all tangible and intangible personal property, including, but not limited to inventory, equipment, instruments, chattel paper, documents, letter of credit rights, accounts, deposit accounts, commercial tort claims, general intangibles, and as-extracted collateral; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type.
Board. Board of Directors of Blue Dolphin.
BOEM. Bureau of Ocean Energy Management.
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BSEE. 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. With respect to the crude distillation tower, the rate is calculated by dividing total refinery throughput or total refinery production on a bpd basis by the total capacity of the crude distillation tower (currently 15,000 bpd).
CAA. Clean Air Act.
CARES Act. Coronavirus Aid, Relief and Economic Security Act, which was passed by Congress in March 2020, to provide economic assistance related to the onset of the COVID-19 pandemic.
CDC. Centers for Disease Control and Prevention.
CERLA. Comprehensive Environmental Response, Compensation, and Liability Act of 1980.
CIP. Construction in progress.
COVID-19. An infectious disease first identified in 2019 in Wuhan, the capital of China’s Hubei province; the disease has since spread globally, resulting in the ongoing coronavirus pandemic.
CWA. Clean Water Act.
Common Stock. Blue Dolphin common stock, par value $0.01 per share. Blue Dolphin has 20,000,000 shares of Common Stock authorized and 12,693,514 shares of Common Stock issued and outstanding as of March 31, 2022.
Complexity. A numerical score that denotes, for a given refinery, the extent, capability, and capital intensity of the refining processes downstream of the crude distillation tower. Refinery complexities range from the relatively simple crude distillation tower (“topping unit”), which has a complexity of 1.0, to the more complex deep conversion (“coking”) refineries, which have a complexity of 12.0.
Condensate. Liquid hydrocarbons that are produced in conjunction with natural gas. Although condensate is sometimes like crude oil, it is usually lighter.
Cost of goods sold. Reflects the cost of crude oil and condensate, fuel use, and chemicals.
Crude distillation tower. A tall column-like vessel in which crude oil and condensate is heated and its vaporized components are distilled by means of distillation trays. This process 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 terms of density (light to heavy) and sulfur content (sweet to sour). Crude oil must be broken down into its various components by distillation before these chemicals and compounds can be used as fuels or converted to more valuable products.
Crude Sale Agreement. Crude Sale Agreement between Pilot and LE dated May 7, 2019, as amended on November 11, 2019, which agreement was assigned by Pilot to Tartan pursuant to an Assignment of Contract dated March 20, 2020.
Depropanizer unit. A distillation column that is used to isolate propane from a mixture containing butane and other heavy components.
Distillates. The result of crude distillation and therefore any refined oil product. Distillate is more commonly used as an abbreviated form of middle distillate. There are mainly four (4) types of distillates: (i) very light oils or light distillates (such as naphtha), (ii) light oils or middle distillates (such as our jet fuel), (iii) medium oils, and (iv) heavy oils (such as our low-sulfur diesel and HOBM, reduced crude, and AGO).
Distillation. The first step in the refining process whereby crude oil and condensate are heated at atmospheric pressure in the base of a distillation tower. As the temperature increases, the various compounds vaporize in succession at their various boiling points and then rise to prescribed levels within the tower per their densities, from lightest to heaviest. They then condense in distillation trays and are drawn off individually for further refining. Distillation is also used at other points in the refining process to remove impurities.
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Downtime. Scheduled and/or unscheduled periods in which the crude distillation tower is not operating. Downtime may occur for a variety of reasons, including severe weather, power failures, and preventive maintenance.
EIA. 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. Environmental Protection Agency.
Eagle Ford Shale. Ahydrocarbon-producing geological formation extending 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 in the original principal amount of $0.7 million; loan represents conversion of prior equipment rental agreement with option to purchase at maturity; interest accrues at 4.50%; maturity date October 2025; monthly principal and interest payment $0.0013 million; security includes first priority lien in the equipment (backhoe); contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type.
Exchange Act. Securities Exchange Act of 1934, as amended.
FASB. Financial Accounting Standards Board.
FDIC. Federal Deposit Insurance Corporation.
Feedstocks. Crude oil and other hydrocarbons, such as condensate and/or intermediate products, that are used as basic input materials in a refining process. Feedstocks are transformed into one or more finished products.
Finished petroleum products. Materials or products which have received the final increments of value through processing operations, and which are being held in inventory for delivery, sale, or use.
Freeport facility. Encompasses processing units for: (i) crude oil and natural gas separation and dehydration, (ii) natural gas processing, treating, and redelivery, and (iii) vapor recovery; also includes two onshore pipelines and 162 acres of land in Freeport, Texas.
GEL. GEL Tex Marketing, LLC, a Delaware limited liability company and an affiliate of Genesis Energy, LLC.
GNCU. Greater Nevada Credit Union.
Greenhouse gases. Molecules in the Earth’s atmosphere such as carbon dioxide, methane, and chlorofluorocarbons which warm the atmosphere.
Gross profit (deficit).Calculated as total revenue less cost of goods sold; reflected as a dollar ($) amount.
HOBM. Heavy oil-based mud blendstock; see also “distillates.”
HUBZone. Historically Underutilized Business Zones program established by the SBA to help small businesses in both urban and rural communities.
IBLA. Interior Board of Land Appeals.
INC. Incident of Noncompliance issued by BOEM and/or BSEE.
Ingleside. Ingleside Crude, LLC, an affiliate of Jonathan Carroll.
Intermediate petroleum products. A petroleum product that might require further processing before it is saleable to the ultimate consumer. This further processing might be done by the producer or by another processor. Thus, an intermediate petroleum product might be a final product for one company and an input for another company that will process it further.
IRC Section 382. Title 26, Internal Revenue Code, Subtitle A – Income Taxes, Subchapter C – Corporate Distributions and Adjustments, Part V Carryovers, § 382. Limits NOL carryforwards and certain built-in losses following ownership change.
IRS. Internal Revenue Service.
Jet fuel. A high-quality kerosene product primarily used in aviation. Kerosene-type jet fuel (including Jet A and Jet A-1) has a carbon number distribution between 8 and 16 carbon atoms per molecule; wide-cut or naphtha-type jet fuel (including Jet B) has between 5 and 15 carbon atoms per molecule.
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Jet Fuel Sales Agreement. Product agreement for the sale of jet fuel between LE and LEH; one-year term effective April 1, 2022 expiring earliest to occur of March 31, 2023, 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.
June LEH Note. June 2017 promissory note between Blue Dolphin and LEH; for Blue Dolphin working capital; reflects amounts owed to LEH under the Amended and Restated Operating Agreement; interest accrues at 8% compounded annually; no covenants; matured January 2019; currently in default for failure to pay past due obligations at maturity.
Kissick Debt. Previously referred to as the ‘Notre Dame Debt; loan agreement originally entered into between LE and Notre Dame Investors, Inc. in the original principal amount of $8.0 million; debt held by John Kissick as of March 31, 2022; pursuant to a 2017 sixth amendment, the Kissick Debt was amended to increase the principal amount by $3.7 million; the additional principal was used to reduce LE’s obligation to GEL; under a 2015 subordination agreement, John Kissick agreed to subordinate his right to payments and security interest, as well as liens on the Nixon facility’s business assets, in favor of Veritex as holder of the LE Term Loan Due 2034; interest accrues at 16%; no covenants; matured January 2019; security includes subordinated deed of trust that encumbers the crude distillation tower and general assets of LE; currently in default for failure to pay past due obligations at maturity.
Lazarus Capital. Lazarus Capital, LLC, an affiliate of Jonathan Carroll.
LE. Lazarus Energy, LLC, a wholly owned subsidiary of Blue Dolphin.
LE Amended and Restated Guaranty Fee Agreement. Amended and Restated Guaranty Fee Agreement dated April 1, 2017, between LE and Jonathan Carroll; tied to payoff of LE Term Loan Due 2034; fee paid equal to 2% per annum of outstanding principal balance owed under LE Term Loan Due 2034; fees payable 50% in cash and 50% in Common Stock; Blue Dolphin accrues payment of Common Stock portion quarterly.
LE Term Loan Due 2034. Loan Agreement dated June 22, 2015, between LE, Veritex, and guarantors in the original principal amount of $25.0 million; Jonathan Carroll required to provide personal guarantee; interest accrues at WSJ Prime plus 2.75%; maturity date June 2034; monthly principal and interest payment $0.2 million; purpose of loan was loan refinance and Nixon facility capital improvements; loan 100% USDA-guaranteed; security includes first priority lien on Nixon facility’s business assets (excluding accounts receivable and inventory), assignment of all Nixon facility contracts, permits, and licenses, absolute assignment of Nixon facility rents and leases, including tank rental income, and a $0.5 million life insurance policy on Jonathan Carroll; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type; currently in default for failing to make principal and interest payments, failing to replenish a $1.0 million payment reserve account, and events of default under other secured loan agreements with Veritex; covenant violations relate to debt service coverage ratio, current ratio, and debt to net worth ratio.
LE Term Loan Due 2050. An EIDL dated August 29, 2020 between NPS and the SBA in the original principal amount of $0.15 million; principal used for working capital; interest accrues at 3.75%; maturity date August 2050; monthly principal and interest payment $0.0007 million; payments deferred first thirty (30) months; interest accrues during deferral period; first payment due March 2023; loan not forgivable; security includes business assets (e.g., machinery and equipment, furniture, fixtures, etc.) as more fully described in the security agreement; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type.
LEH. Lazarus Energy Holdings, LLC, an affiliate of Jonathan Carroll and controlling shareholder of Blue Dolphin.
LEH Operating Fee. A management fee paid to LEH under the Amended and Restated Operating Agreement; calculated as 5% of all consolidated operating costs, excluding crude costs, depreciation, amortization, and interest, of Blue Dolphin, LE, LRM, NPS, BDPL, BDPC and BDSC; previously reflected within refinery operating expenses in our consolidated statements of operations.
Leasehold interest. The interest of a lessee under an oil and gas lease.
Light crude. A liquid petroleum that has a low density and flows freely at room temperature. It has a low viscosity, low specific gravity, and a high American Petroleum Institute gravity due to the presence of a high proportion of light hydrocarbon fractions.
LMT. Lazarus Marine Terminal I, LLC, an affiliate of LEH.
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Glossary of Terms |
LRM. Lazarus Refining & Marketing, LLC, a wholly owned subsidiary of Blue Dolphin.
LRM Amended and Restated Guaranty Fee Agreement. Amended and Restated Guaranty Fee Agreement dated April 1, 2017, between LRM and Jonathan Carroll; tied to payoff of LRM Term Loan Due 2034; fee paid equal to 2% per annum of outstanding principal balance owed under LRM Term Loan Due 2034; fees payable 50% in cash and 50% in Common Stock; Blue Dolphin accrues payment of Common Stock portion quarterly.
LRM Term Loan Due 2034. Loan Agreement dated December 4, 2015, between LRM, Veritex, and guarantors in the original principal amount of $10.0 million; Jonathan Carroll required to provide personal guarantee; interest accrues at WSJ plus 2.75%; maturity date December 2034; monthly principal and interest payment $0.1 million; purpose of loan to refinance bridge loan and Nixon facility capital improvements; loan 100% USDA-guaranteed; security includes second priority lien on rights of LE in crude distillation tower and other collateral of LE, first priority lien on real property interests of LRM, first priority lien on all LRM fixtures, furniture, machinery, and equipment, first priority lien on all LRM contractual rights, general intangibles, and instruments, except with respect to LRM rights in its leases of certain specified tanks for which Veritex has a second priority lien, and all other collateral as described in the security agreements; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type; currently in default for failing to make principal and interest payments and events of default under other secured loan agreements with Veritex; covenant violations relate to debt service coverage ratio, current ratio, and debt to net worth ratio.
LTRI. Lazarus Texas Refinery I, an affiliate of LEH.
March Carroll Note. March 2017 promissory note between Blue Dolphin and Lazarus Capital; reflects amounts owed to Jonathan Carroll under LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement; interest accrues at 8% compounded annually; no covenants; matured January 2019; currently in default for failure to pay past due obligations at maturity.
March Ingleside Note. March 2017 promissory note between Blue Dolphin and Ingleside; represents periodic working capital to Blue Dolphin through conversion of accounts payable; interest accrues at 8% compounded annually; no covenants; matured January 2019; currently in default for failure to pay past due obligations at maturity.
NAAQS. National Ambient Air Quality Standards.
Naphtha. A refined or partly refined light distillate fraction of crude oil. Blended further or mixed with other materials it can make high-grade motor gasoline or jet fuel. It is also a generic term applied to the lightest and most volatile petroleum fractions.
Natural gas. A naturally occurring hydrocarbon gas mixture consisting primarily of methane, but commonly including varying amounts of other higher alkanes, and sometimes a small percentage of carbon dioxide, nitrogen, hydrogen sulfide, or helium.
NOL. Net operating losses.
Nixon facility. Encompasses the Nixon refinery, petroleum storage tanks, loading and unloading facilities, and 56 acres of land in Nixon, Texas.
Nixon refinery. The 15,000-bpd crude distillation tower and associated processing units in Nixon, Texas.
NPS. Nixon Product Storage, LLC, a wholly owned subsidiary of Blue Dolphin.
NPS Term Loan Due 2031. Loan Agreement dated September 20, 2021, between NPS, GNCU, and guarantors in the original principal amount of $10.0 million; Jonathan Carroll required to provide personal guarantee; interest accrues at 5.75%; maturity date October 2031; monthly principal and interest payment $0.1 million; interest-only payments first thirty-six (36) months; first principal payment due November 2024; purpose of loan working capital; loan 90% USDA-guaranteed; security includes deed of trust lien on approximately 56 acres of land and improvements owned by LE, leasehold deed of trust lien on certain property leased by NPS from LE, and assignment of leases and rents and certain personal property; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type; currently in default; covenant violations relate to debt service coverage ratio, current ratio, and debt to net worth ratio.
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Glossary of Terms |
NPS Term Loan Due 2050. An EIDL dated August 29, 2020 between NPS and the SBA in the original principal amount of $0.15 million; principal used for working capital; interest accrues at 3.75%; maturity date August 2050; monthly principal and interest payment $0.0007 million; payments deferred first thirty (30) months; interest accrues during deferral period; first payment due March 2023; loan not forgivable; security includes business assets (e.g., related machinery and equipment, furniture, fixtures, etc.) as more fully described in the security agreement; contains representations and warranties, affirmative and negative covenants, and events of default that are usual and customary for a credit facility of this type.
NSR/PSD. New Source Review/Prevention of Significant Deterioration.
OPA 90. Oil Pollution Act of 1990.
Operating days. Represents the number of days in a period in which the crude distillation tower operated. Operating days is calculated by subtracting downtime in a period from calendar days in the same period.
OPEC+. Organization of Petroleum Exporting Countries, Russia, and certain other oil-exporting countries.
OSHA. Occupational Safety and Health Administration.
OSRO. Oil Spill Response Organization.
Other conversion costs. Represents the combination of direct labor costs and manufacturing overhead costs. These are the costs that are necessary to convert our raw materials into refined products.
Other operating expenses. Represents costs associated with our natural gas processing, treating, and redelivery facility, as well as our pipeline assets and leasehold interests in oil and gas properties.
PCAOB. Public Company Accounting Oversight Board.
Petroleum. A naturally occurring flammable liquid consisting of a complex mixture of hydrocarbons of various molecular weights and other liquid organic compounds. The name petroleum covers both the naturally occurring unprocessed crude oils and petroleum products that are made up of refined crude oil.
PHMSA. Pipeline and Hazardous Materials Safety Administration of the U.S. Department of Transportation.
Pilot. Pilot Travel Centers LLC, a Delaware limited liability company.
Preferred Stock. Blue Dolphin preferred stock, par value $0.10 per share. Blue Dolphin has 2,500,000 shares of Preferred Stock authorized and no shares of Preferred Stock issued and outstanding.
Product slate. Represents type and quality of products produced.
Propane. A by-product of natural gas processing and petroleum refining. Propane is one of a group of liquified petroleum gases. Others include butane, propylene, butadiene, butylene, isobutylene, and mixtures thereof.
Refined products. Hydrocarbon compounds, such as jet fuel and residual fuel, that are produced by a refinery.
Refinery. Within the oil and gas industry, a refinery is an industrial processing plant where crude oil, condensate, and intermediate feeds are separated and transformed into petroleum products.
Refining gross profit (deficit) per bbl. Calculated as refinery operations revenue less total cost of goods sold divided by the volume, in bbls, of refined products sold during the period; reflected as a dollar ($) amount per bbl.
ROU. Right-of-use.
SBA. Small Business Administration.
SEC. Securities and Exchange Commission.
Securities Act. The Securities Act of 1933, as amended.
Segment margin (deficit). For 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.
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Glossary of Terms |
Sour crude. Crude oil containing sulfur content of more than 0.5%.
Stabilizer unit. A distillation column intended to remove the lighter boiling compounds, such as butane or propane, from a product.
Sulfur. Present at various levels of concentration in many hydrocarbon deposits, such as petroleum, coal, or natural gas. Also, produced as a by-product of removing sulfur-containing contaminants from natural gas and petroleum. Some of the most commonly used hydrocarbon deposits are categorized per their sulfur content, with lower sulfur fuels usually selling at a higher, or premium, price and higher sulfur fuels selling at a lower, or discounted, price.
Sweet crude. Crude oil containing sulfur content of less than 0.5%.
Tartan. Tartan Oil LLC, an affiliate of Pilot.
Texas First. Texas First Rentals, LLC.
TCEQ. Texas Commission on Environmental Quality.
Throughput. The volume processed through a unit or a refinery or transported through a pipeline.
TMT. Texas margins tax; a form of business tax imposed on an entity’s gross profit rather than on 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 more for comprehensive revamp and renewal.
USACOE. U.S. Army Corps of Engineers.
USDA. U.S. Department of Agriculture; the USDA, acting through its agencies, administers a federal rural credit program that makes direct loans and guarantees portions of loans made and serviced by USDA-qualified lenders for various purposes; each USDA guarantee is a full faith and credit obligation of the U.S. with the USDA guaranteeing up to 100% of the principal amount; lenders of USDA-guaranteed loans are required by regulations to retain both the guaranteed and unguaranteed portions of the loan, to service the entire underlying loan, and to remain mortgage and/or secured party of record; both the guaranteed and unguaranteed portions of the loan are to be secured by the same collateral with equal lien priority; the USDA-guaranteed portion of the loan cannot be paid later than, or in any way be subordinated to, the related unguaranteed portion.
U.S. GAAP. Accounting principles generally accepted in the United States of America.
Veritex. Veritex Community Bank, successor in interest to Sovereign Bank by merger.
WHO. World Health Organization.
WSJ prime rate. A measure of the U.S. prime rate as defined by the Wall Street Journal.
XBRL. eXtensible Business Reporting Language.
Yield. The percentage of refined products that is produced from crude oil and other feedstocks.
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Important Information Regarding Forward Looking Statements |
Important Information Regarding Forward-Looking Statements
This report (including information incorporated by reference) contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act, including, but not limited to, those under “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.” All statements other than statements of historical fact, including without limitation statements regarding expectations regarding revenue, cash flows, capital expenditures, and other financial items, our business strategy, goals and expectations concerning our market position, future operations and profitability, are forward-looking statements. Forward-looking statements may be identified by use of the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will,” “would” and similar terms and phrases. Although we believe our assumptions concerning future events are reasonable, several risks, uncertainties, and other factors could cause actual results and trends to differ materially from those projected, including but not limited to:
Business and Industry
· | Our going concern status. |
· | Inadequate liquidity to sustain operations due to defaults under our secured loan agreements, margin |
· | Substantial debt in current liabilities, all of 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 that |
· | Affiliate |
· | Operational hazards inherent in |
· | Geographical concentration of our assets and customers in West Texas. |
· | Competition from companies |
· | Environmental laws and regulations that |
· | 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 |
· | Actual or potential security threats. |
· | Uncertainty regarding the impact of |
· | Public health threats, pandemics, and epidemics, such as the ongoing outbreak of COVID-19, and the adverse impacts thereof on our business, financial condition, results of operations, and liquidity. |
· | Potential impairment in the carrying value of long-lived assets, which could negatively affect our operating results. |
Downstream and Midstream Operations
· | |
· | Crude oil, other feedstocks, and fuel and utility services price volatility. |
· | Availability and |
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Important Information Regarding Forward Looking Statements |
· | 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 |
· | Assessment of penalties by regulatory agencies, such as the TCEQ, for alleged violations. |
· | Regulatory changes emissions, including carbon dioxide. |
· | 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 |
· | Our estimates of future AROs related to our pipeline and facilities assets may increase. |
Common Stock
· | Fluctuations in our stock price that may result in a substantial investment loss. |
· | Declines in our stock price due to share sales. |
· | 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, 20202021 as filed with the SEC and elsewhere in this report. All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to revise or update any forward-looking statements as a result of new information, future events, or otherwise.
Unless the context otherwise requires, references in this report to “Blue Dolphin,” “we,” “us,” “our,” or “ours” refer to Blue Dolphin Energy Company, one or more of its consolidated subsidiaries, or all of them taken as a whole.
Blue Dolphin Energy Company | March 31, |
| 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 |
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands except share amounts) |
| |||||
|
|
|
|
|
|
| ||
ASSETS |
|
|
|
|
|
| ||
CURRENT ASSETS |
|
|
|
|
|
| ||
Cash and cash equivalents |
| $ | 106 |
|
| $ | 9 |
|
Restricted cash |
|
| 0 |
|
|
| 48 |
|
Accounts receivable, net |
|
| 143 |
|
|
| 126 |
|
Prepaid expenses and other current assets |
|
| 1,732 |
|
|
| 2,433 |
|
Deposits |
|
| 110 |
|
|
| 110 |
|
Inventory |
|
| 5,810 |
|
|
| 3,098 |
|
Total current assets |
|
| 7,901 |
|
|
| 5,824 |
|
|
|
|
|
|
|
|
|
|
LONG-TERM ASSETS |
|
|
|
|
|
|
|
|
Total property and equipment, net |
|
| 59,274 |
|
|
| 59,923 |
|
Operating lease right-of-use assets, net |
|
| 288 |
|
|
| 332 |
|
Surety bonds |
|
| 230 |
|
|
| 230 |
|
Total long-term assets |
|
| 59,792 |
|
|
| 60,485 |
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS |
| $ | 67,693 |
|
| $ | 66,309 |
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) |
|
|
|
|
|
|
|
|
CURRENT LIABILITIES |
|
|
|
|
|
|
|
|
Long-term debt less unamortized debt issue costs, current portion (in default) |
| $ | 43,004 |
|
| $ | 42,953 |
|
Long-term debt, related party, current portion (in default) |
|
| 18,087 |
|
|
| 20,042 |
|
Interest payable (in default) |
|
| 8,493 |
|
|
| 8,689 |
|
Interest payable, related party (in default) |
|
| 3,614 |
|
|
| 3,454 |
|
Accounts payable |
|
| 2,356 |
|
|
| 2,548 |
|
Accounts payable, related party |
|
| 155 |
|
|
| 155 |
|
Current portion of lease liabilities |
|
| 220 |
|
|
| 215 |
|
Income taxes payable |
|
| 41 |
|
|
| 0 |
|
Accrued expenses and other current liabilities |
|
| 4,855 |
|
|
| 6,225 |
|
Total current liabilities |
|
| 80,825 |
|
|
| 84,281 |
|
|
|
|
|
|
|
|
|
|
LONG-TERM LIABILITIES |
|
|
|
|
|
|
|
|
Asset retirement obligations |
|
| 3,494 |
|
|
| 3,461 |
|
Long-term lease liabilities, net of current |
|
| 99 |
|
|
| 156 |
|
Unearned contract renewal income |
|
| 1,090 |
|
|
| 1,200 |
|
Long-term debt, net of current portion |
|
| 2,334 |
|
|
| 838 |
|
Total long-term liabilities |
|
| 7,017 |
|
|
| 5,655 |
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES |
|
| 87,842 |
|
|
| 89,936 |
|
|
|
|
|
|
|
|
|
|
Commitments and contingencies (Note 15) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
STOCKHOLDERS' DEFICIT |
|
|
|
|
|
|
|
|
Common stock ($0.01 par value, 20,000,000 shares authorized; 12,693,514 shares issued at both March 31, 2022 and December 31, 2021)(1) |
|
| 127 |
|
|
| 127 |
|
Additional paid-in capital |
|
| 38,457 |
|
|
| 38,457 |
|
Accumulated deficit |
|
| (58,733 | ) |
|
| (62,211 | ) |
TOTAL STOCKHOLDERS' DEFICIT |
|
| (20,149 | ) |
|
| (23,627 | ) |
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT |
| $ | 67,693 |
|
| $ | 66,309 |
|
(1) | Blue Dolphin has 20,000,000 shares of common stock, par value $0.01 per share, and 2,500,000 shares of preferred stock, par value $0.10 per share, authorized. There are 12,693,514 shares of common stock issued and outstanding and no shares of preferred stock issued and outstanding. |
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | March 31, |
| 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 March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands, except share and per-share amounts) |
| |||||
REVENUE FROM OPERATIONS |
|
|
|
|
|
| ||
Refinery operations |
| $ | 109,757 |
|
| $ | 58,483 |
|
Tolling and terminaling |
|
| 926 |
|
|
| 930 |
|
|
|
|
|
|
|
|
|
|
Total revenue from operations |
|
| 110,683 |
|
|
| 59,413 |
|
|
|
|
|
|
|
|
|
|
COST OF GOODS SOLD |
|
|
|
|
|
|
|
|
Crude oil, fuel use, and chemicals |
|
| 102,393 |
|
|
| 57,783 |
|
Other conversion costs |
|
| 1,684 |
|
|
| 1,840 |
|
Total cost of goods sold |
|
| 104,077 |
|
|
| 59,623 |
|
|
|
|
|
|
|
|
|
|
Gross profit (loss) |
|
| 6,606 |
|
|
| (210 | ) |
|
|
|
|
|
|
|
|
|
COST OF OPERATIONS |
|
|
|
|
|
|
|
|
LEH operating fee, related party |
|
| 126 |
|
|
| 124 |
|
Other operating expenses |
|
| 11 |
|
|
| 54 |
|
General and administrative expenses |
|
| 624 |
|
|
| 658 |
|
Depreciation and amortization |
|
| 701 |
|
|
| 693 |
|
Accretion of asset retirement obligations |
|
| 33 |
|
|
| - |
|
|
|
|
|
|
|
|
|
|
Total cost of operations |
|
| 1,495 |
|
|
| 1,529 |
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations |
|
| 5,111 |
|
|
| (1,739 | ) |
|
|
|
|
|
|
|
|
|
OTHER INCOME (EXPENSE) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Easement, interest and other income |
|
| 0 |
|
|
| 2 |
|
Interest and other expense |
|
| (1,592 | ) |
|
| (1,480 | ) |
Gain on extinguishment of debt |
|
| 0 |
|
|
| 43 |
|
Total other expense |
|
| (1,592 | ) |
|
| (1,435 | ) |
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes |
|
| 3,519 |
|
|
| (3,174 | ) |
|
|
|
|
|
|
|
|
|
Income tax expense |
|
| (41) |
|
|
| 0 |
|
|
|
|
|
|
|
|
|
|
Net Income (loss) |
| $ | 3,478 |
|
| $ | (3,174 | ) |
|
|
|
|
|
|
|
|
|
Income (loss) per common share: |
|
|
|
|
|
|
|
|
Basic |
| $ | 0.27 |
|
| $ | (0.25 | ) |
Diluted |
| $ | 0.27 |
|
| $ | (0.25 | ) |
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding: |
|
|
|
|
|
|
|
|
Basic |
|
| 12,693,514 |
|
|
| 12,693,514 |
|
Diluted |
|
| 12,693,514 |
|
|
| 12,693,514 |
|
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | March 31, |
| 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) | $- | $- |
|
| Three Months Ended March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
OPERATING ACTIVITIES |
|
|
|
|
|
| ||
Net income (loss) |
| $ | 3,478 |
|
| $ | (3,174 | ) |
Adjustments to reconcile net income (loss) to net cash |
|
|
|
|
|
|
|
|
used in operating activities: |
|
|
|
|
|
|
|
|
Depletion, depreciation and amortization |
|
| 701 |
|
|
| 693 |
|
Accretion of asset retirement obligations |
|
| 33 |
|
|
| 0 |
|
Amortization of debt issue costs |
|
| 51 |
|
|
| 32 |
|
Guaranty fees paid in kind |
|
| 152 |
|
|
| 152 |
|
Related-party interest expense paid in kind |
|
| 277 |
|
|
| 225 |
|
Deferred revenue and expenses |
|
| (110 | ) |
|
| 3 |
|
Gain on extinguishment of debt |
|
| 0 |
|
|
| (43 | ) |
Changes in operating assets and liabilities |
|
|
|
|
|
|
|
|
Accounts receivable |
|
| (17 | ) |
|
| 44 |
|
Prepaid expenses and other current assets |
|
| 701 |
|
|
| 2,504 |
|
Deposits and other assets |
|
| 0 |
|
|
| 14 |
|
Inventory |
|
| (2,712 | ) |
|
| (37 | ) |
Accounts payable, accrued expenses and other liabilities |
|
| (1,617 | ) |
|
| (913 | ) |
Accounts payable, related party |
|
| 0 |
|
|
| 0 |
|
Net cash provided by operating activities |
|
| 937 |
|
|
| (500 | ) |
|
|
|
|
|
|
|
|
|
FINANCING ACTIVITIES |
|
|
|
|
|
|
|
|
Proceeds from debt |
|
| 1,500 |
|
|
| 0 |
|
Payments on debt |
|
| (4 | ) |
|
| (6 | ) |
Net activity on related-party debt |
|
| (2,384 | ) |
|
| (36 | ) |
Net cash used in financing activities |
|
| (888 | ) |
|
| (42 | ) |
Net change in cash, cash equivalents, and restricted cash |
|
| 49 |
|
|
| (542 | ) |
|
|
|
|
|
|
|
|
|
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT BEGINNING OF PERIOD |
|
| 57 |
|
|
| 1,111 |
|
CASH, CASH EQUIVALENTS, AND RESTRICTED CASH AT END OF PERIOD |
| $ | 106 |
|
| $ | 569 |
|
|
|
|
|
|
|
|
|
|
Supplemental Information: |
|
|
|
|
|
|
|
|
Non-cash operating activities |
|
|
|
|
|
|
|
|
Financing of line of credit via related-party debt |
| $ | 0 |
|
| $ | 873 |
|
Amended Pilot Line of Credit offset by tank lease payments |
| $ | 0 |
|
| $ | 576 |
|
Interest paid |
| $ | 1,051 |
|
| $ | 287 |
|
Income taxes paid (refunded) |
| $ | 0 |
|
| $ | 0 |
|
The accompanying notes are an integral part of these consolidated financial statements.
Blue Dolphin Energy Company | March 31, |
| 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 business 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 Blue Dolphin subsidiaries BDPL (inactive pipeline and facilities assets), BDPC (inactive leasehold interests in oil and gas wells), and BDSC (administrative services). See “Note (4)” to our consolidated financial statements for more information about our business segments.
Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours,” refer to Blue Dolphin, one or more of its consolidated subsidiaries or all of them taken as a whole.
Affiliates
Affiliates 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 propertiesassets 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, substantial current debt, margin deterioration and volatility, and historichistorical net losses and working capital deficits.and equity 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 ascould 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. As a result, the debt associated with these obligations was classified within the current portion of long-term debt on our consolidated balance sheets at March 31,Third-Party Defaults
· | Veritex Loans –As of the filing date of this report, LE and LRM were in default under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 for failing to make required monthly principal and interest payments and failing to satisfy financial covenants. In addition, LE was in default under the LE Term Loan Due 2034 for failing to replenish a $1.0 million payment reserve account. 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. |
· | GNCU Loan –As of the filing date of this report, NPS was in default under the NPS Term Loan Due 2031 for failing to satisfy financial covenants. |
· | 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. To date, Mr. Kissick has taken no action due to the non-payment. As of the filing date of this report, there were defaults under the Kissick Debt related to payment of past due obligations at maturity. |
Blue Dolphin Energy Company | March 31, 2022 │Page 15 |
| Table of Contents |
Notes to Consolidated Financial Statements |
We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements, with Veritex, either upon maturity or if accelerated, (ii) LE, LRM, and LRMNPS will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder,third parties will provide future default waivers. The borrowers continue in active dialogue with Veritex. AsDefaults under our secured loan agreements and any exercise by third parties of the filing date of this report, payments under the Veritex loans were current, but other defaults remained outstanding.
Related-Party Defaults
· | Notes and Loan Agreement – As of the filing date of this report, Blue Dolphin | was in default concerning past due payment obligations under the March |
Substantial Current Debt
Excluding accrued interest, we had current debt of (a) the Terminal Services Agreement (covering Tank Nos. 67, 71, 72, 73, 77,$61.1 million and 78), dated$63.0 million, respectively, 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, 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 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. For the three-month periods ended March 31, 20212022 and 2020,December 31, 2021. Current debt consists of bank debt, investor debt, and related party debt. Substantial current debt is primarily the tank lease setoff amounts totaled $0.6 million and $0, respectively. Forresult of secured loan agreements being in default. As a result, these debt obligations were classified within the three-month periods endedcurrent portion of long-term debt on our consolidated balance sheets at March 31, 20212022 and 2020,December 31, 2021.
Margin Volatility. Crude oil refining is primarily a margin-based business. To improve margins, we must maximize yields of higher value finished petroleum products and minimize costs of feedstocks and operating expenses. When the amountspread between these commodity prices decreases, our margins are negatively affected. Although an increase or decrease in the commodity price for crude oil and other feedstocks generally results in a similar increase or decrease in commodity prices for finished petroleum products, typically there is a time lag between the two. The effect of interest NPS incurred undercrude oil commodity price changes on our finished petroleum product commodity prices therefore depends, in part, on how quickly and how fully the Amended Pilot Line of Credit totaled $0.3 million and $0.4 million, respectively.
In March 2020, the WHO declared the outbreak of operations. NPS and guarantors continue in active dialogue with Pilot to reachCOVID-19 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,pandemic, and the general condition of the financial markets. Given the current financial markets, we could be forcedU.S. economy began 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.
In February 2022, Russia invaded neighboring Ukraine. The conflict caused turmoil in global commodity markets, injecting even more uncertainty into a worldwide economy recovering from the effects of COVID-19. Sanctions imposed on Russia resulted in global tightening of refined product inventories and crude stocks, which caused refining margins to widen significantly. These conditions contributed to a significant improvement in our refining operating results in the first quarter of 2022 compared to the prior year period. Despite favorable refining margins during the first quarter, the future impact of the Russian-Ukrainian conflict on our financial position and results of operations remains uncertain.
The Russian conflict with Ukraine and the COVID-19 pandemic continue to evolve, and the extent to which these events may impact our business, financial condition, liquidity, results of operations, and prospects will depend highly on future developments, which are very uncertain and cannot be predicted with confidence.
Historic Net Losses and Working Capital Deficits
Net Income (Losses). We had net income of $3.5 million for the three months ended March 31, 2022 compared to a net loss of $3.2 million for the three months ended March 31, 2021. The significant improvement for the three months ended March 31, 2022 resulted from improved refining margins associated with supply contraction and strong demand. While refining margins improved significantly in 2022, the general outlook for the remainder of the year remains unclear, and we can provide no assurances that refining margins and demand will remain at current levels.
Blue Dolphin Energy Company | March 31, 2022 │Page 16 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Working Capital Deficits. We had $72.9 million and $78.5 million in working capital deficits at March 31, 2022 and December 31, 2021, respectively. Excluding the current portion of long-term debt, we had $11.8 million and $15.5 million in working capital deficits at March 31, 2022 and December 31, 2021, respectively.
Cash and cash equivalents totaled $0.1 million and $0.01 million at March 31, 2022 and December 31, 2021, respectively. Restricted cash (current portion) totaled $0 and $0.05 million at March 31, 2022 and December 31, 2021, respectively.
Our financial health could behas been materially and adversely affected by defaults in our secured loan agreements, substantial current debt, margin deterioration and volatility, historichistorical net losses and working capital deficits, as well as termination ofand equity deficits. If Tartan terminates the crude supply agreementCrude Supply Agreement or terminal services agreement, with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, sustained periods of lowcondensate could be adversely affected. If producers experience crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. A failurecosts, our crude acquisition costs may rise, or we may not receive sufficient amounts to acquire crude oil and condensate when needed will have a material effect onmeet our business results and operations. During the three-month period ended March 31, 2021, our refinery experienced 1 day of downtime as a result of lack of crude due to cash constraints.
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 |
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. We are currently unable to estimate the impactThe Russian conflict with Ukraine and the COVID-19 pandemic will have oncontinue to evolve, and the extent to which these events may impact our futurebusiness, financial position andcondition, liquidity, results of operations. Under earlier stateoperations, and federal mandates that regulated business closures, our business was deemed as an essential businessprospects will depend highly on future developments, which are very uncertain and as such, remained open. As U.S. federal, state, and local officials roll out COVID-19 vaccines, we expectcannot be predicted with confidence.
Management continues to continue operating. Any governmental mandates, while necessary to address the virus, will 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.
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 tocan 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 Pilotthird parties exercise their rights and remedies under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
(2)
Basis of Presentation
The accompanying unaudited consolidated financial statements, which include Blue Dolphin and its subsidiaries, have been prepared in accordance with GAAP for interim consolidated financial information pursuant to the rules and regulations of the SEC under Article 10 of Regulation S-X and the instructions to Form 10-Q. Accordingly, certain information and footnote disclosures normally included in our audited financial statements have been condensed or omitted pursuant to the SEC’s rules and regulations. Significant intercompany transactions have been eliminated in the consolidation. In management’s opinion, all adjustments considered necessary for a fair presentation have been included, disclosures are adequate, and the presented information is not misleading.
The consolidated balance sheet as of December 31, 20202021 was derived from the audited financial statements at that date. The accompanying consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 20202021 as filed with the SEC. Operating results for the three months ended March 31, 20212022 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2021,2022, or for any other period.
Significant Accounting Policies
The summary of significant accounting policies of Blue Dolphin is presented to assist in understanding our consolidated financial statements. Our consolidated financial statements and accompanying notes are representations of management, who is responsible for their integrity and objectivity. These accounting policies conform to GAAP and have been consistently applied in the preparation of our consolidated financial statements.
Use of Estimates
. The preparation of our financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the related disclosures. Actual results could differ from those estimates. 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. We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to usBlue Dolphin Energy Company | March 31, 2022 │Page 17 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Cash and Cash Equivalents
. Cash and cash equivalents represent liquid investments with an original maturity of three months or less. Cash balances are maintained in depository and overnight investment accounts with financial institutions that, at times, may exceed insured deposit limits. We monitor the financial condition of the financial institutions and have experienced no losses associated with these accounts.Restricted Cash
. Restricted cash, current portionInventory
. Inventory primarily consists of refined products, crude oil and condensate, and chemicals. Inventory is valued 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. If the net realizable value of our refined products inventory declines to an amount less than our average cost, we record a write-down of inventory and an associated adjustment to cost of goods sold. See “Note (7)” to our consolidated financial statements for additional disclosures related to inventory.Property and Equipment
.Pipelines and Facilities
.Oil and Gas Properties
. Our oil and gas properties are accounted for using the full-cost method of accounting, whereby all costs associated with acquisition, exploration and development of oil and gas properties, including directly related internal costs, are capitalized on a cost center basis. Amortization of such costs and estimated future development costs are determined using the unit-of-production method. All leases associated with our oil and gas properties have expired, and our oil and gas propertiesCIP
. CIP expenditures, including capitalized interest, relate to construction and refurbishment activities and equipment for the Nixon facility. These expenditures are capitalized as incurred. Depreciation begins once the asset is placed in service. See “Note (8)” to our consolidated financial statements for additional disclosures related toLeases.
WeFor operating lease is recognized as a singleleases, we record lease cost on a straight-line basis over the lease term and is reflectedterm; we record lease expenses in the appropriate line on the income statement line item based on the leased asset’s function. Amortization expense of aintended use. For finance leases (previously referred to under GAAP as capital leases), we amortize lease payments for the ROU asset is recognized on a straight-line basis over the lesser of the leased asset’s useful life of the leased asset or the lease term. However, ifterm; we record amortization expenses on the lease transfers ownership of the finance lease ROU asset to us at the end of the lease term, the finance lease ROU asset is amortized over the useful life of the leased asset. Amortization expense is reflectedincome statement in ‘depreciation and amortization expense.expense;’ Interestwe record interest expense is incurred based on the carrying value of the lease liability and is reflectedincome statement in ‘interest and other expense.
Blue Dolphin Energy Company | March 31, 2022 │Page 18 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Revenue Recognition
.Refinery Operations Revenue
.We consider a variety of facts and circumstances in assessing the point of a control transfer, including but not limited to: whether the purchaser can direct the use of the refined product, the transfer of significant risks and rewards, our rights to payment, and transfer of legal title. In each case, the term between the sale and when payment is due is not significant. Transportation,We include incurred transportation, shipping, and handling costs incurred are included in the cost of goods sold. ExciseWe do not include excise and other taxes that are collected from customers and remitted to governmental authorities are not included in revenue.
Tolling and Terminaling Revenue
. Tolling and terminaling revenue represents feesWe typically satisfy performance obligations for tolling and terminaling operations with the passage ofover time. We determine the transaction price at agreement inception based on the guaranteed minimum amount of revenue over the term of the agreement.agreement term. We allocate the transaction price to the single performance obligation that exists under the agreement, and weagreement. We recognize revenue in the amount for which we have a right to invoice. Generally, payment terms do not exceed 30 days.
Revenue from tank storage customers may, from time to time, include fees for ancillary services, such as in-tank and tank-to-tank blending. These services are considered optional to the customer, and the price we charge for such services is not included in thecustomer. The fixed cost under the customer’s tank storage agreement. Ancillaryagreement does not include ancillary service fees. We consider ancillary services are consideredas a separate performance obligation by us under the tank storage agreement. TheWe satisfy the performance obligation is satisfiedand recognize the associated fee when we complete the requested service has been performed in the applicable period.
Deferred Revenue
.Unearned Contract Renewal Income. We recognize deferred revenue from suppliers for upfront payments received but not yet earned as a reduction of cost of sales on a straight-line basis over the term of the supply contract.
Income Taxes
.Management uses significant judgment is required in evaluating uncertain tax positions and determining itsthe provision for income taxes. As of each reporting date, we consider new evidence, both positive and negative, to determineassess the realizability of deferred tax assets. We considerweigh whether itthere is a more likely than not that50% probability of realizing a portion or all the deferred tax assets will be realized, which is dependent uponassets. Realization depends on the generation of future taxable income prior tobefore the expiration of any NOL carryforwards. When we determine that it is more likely than not that a tax benefit will not be realized,We record a valuation allowance against deferred income tax assets if there is recorded to reducea 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. 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.
A significant piece of objective negative evidence evaluated was cumulative losses incurred over the three-year period ended March 31, 2021.2022. Such objective evidence limits the ability to consider other subjective evidence, such as projections for future growth. Based on this evaluation, we recorded a valuation allowance against the deferred tax assets for which realization was not deemed more likely than not as of March 31, 20212022 and December 31, 2020.2021. In addition, we have NOL carryforwards that remain available for future use.
Impairment or Disposal of Long-Lived Assets
. We periodically evaluate our long-lived assets for impairment. Additionally, weBlue Dolphin Energy Company | March 31, 2022 │Page 19 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Commodity price market volatility of commodity prices as a result ofassociated with the ongoing COVID-19 pandemic and the Russian conflict with Ukraine could affect the value of certain of our long-lived assets. Management evaluated our refinery and facilities assets for impairment as of MarchDecember 31, 2021. No impairment was deemed necessary based upon this testing, and we We did not record any impairment of our refinery and facilitieslong-lived assets for the periods presented.
Asset Retirement Obligations
. We record a liability for the discounted fair value of an ARO in the periodRefinery and Facilities. We believe we have concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Further, we believe that these assets have indeterminate lives because we cannot reasonably estimate the dates or ranges of dates upon which we would retire these assets. Management will record an asset retirement obligation for these assets cannot reasonably be estimated at this time. Whenwhen a legal or contractualdefinitive obligation to dismantle or remove the refinery and facilities assets arises, and a date or range ofretirement dates can reasonably be estimated for the retirement of these assets, we willare evident.
Pipeline and Facilities; Oil and Gas Properties. Management uses significant judgment to estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.
Computation of Earnings Per Share
. We present basic and diluted EPS. Basic EPS excludes dilution and is computed by dividing net income available to common stockholders by theNew Pronouncements Adopted
. The FASB issues ASUs to communicate changes to the FASB ASC, includingNew Pronouncements Issued, Not Yet Effective
.No new pronouncements issued but not yet effective are not expected to have a material impact on our financial position, results of operations, or liquidity.
(3)
Affiliate Operational Agreements Summary
Blue Dolphin and certain of its subsidiaries are partyparties to several operational agreements with Affiliates. Management believes that these related-party transactions were consummated on terms equivalent to those that prevail in arm's-length transactions. Related-party agreements related to Blue Dolphin’s operations consist ofAffiliates, including the following:
Working Capital
We have historically dependedrelied on Affiliates for financingfunding when revenue from operations and borrowingsavailability under bank facilities arewere insufficient to meet our liquidity and working capital needs. SuchWe reflect such borrowings are reflected in our consolidated balance sheets in accounts payable, related party, and/or long-term debt, related party.
Related-Party 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 March 31,Blue Dolphin Energy Company | March 31, 2022 │Page 20 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Long-term debt, related party, current portion (in default) and accrued interest payable, related party.
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) |
$- | $- | |
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
LEH |
|
|
|
|
|
| ||
June LEH Note (in default) |
| $ | 10,507 |
|
| $ | 12,672 |
|
BDPL-LEH Loan Agreement |
|
| 7,614 |
|
|
| 7,454 |
|
LEH Total |
|
| 18,121 |
|
|
| 20,126 |
|
Ingleside |
|
|
|
|
|
|
|
|
March Ingleside Note (in default) |
|
| 1,075 |
|
|
| 1,066 |
|
Jonathan Carroll |
|
|
|
|
|
|
|
|
March Carroll Note (in default) |
|
| 2,505 |
|
|
| 2,304 |
|
|
|
| 21,701 |
|
|
| 23,496 |
|
|
|
|
|
|
|
|
|
|
Less: Long-term debt, related party, current portion, in default |
|
| (18,087 | ) |
|
| (20,042 | ) |
Less: Accrued interest payable, related party (in default) |
|
| (3,614 | ) |
|
| (3,454 | ) |
Currently, management does not intend to pay Mr. Carroll the cash portion owed under the LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement 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. See “Notes (1) and (10)” to our consolidated financial statements for additional information regarding defaults under our secured loan agreements and their potential effects on our business, financial condition, and results of operations.
Consolidated Statements of Operations
.Total revenue from operations.
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, |
| |||||||||||||
|
| 2022 |
|
| 2021 |
| ||||||||||
|
| (in thousands, except percent amounts) |
| |||||||||||||
Refinery operations |
|
|
|
|
|
|
|
|
|
|
|
| ||||
LEH |
| $ | 34,518 |
|
|
| 31.2 | % |
| $ | 16,080 |
|
|
| 27.1 | % |
Third-Parties |
|
| 75,239 |
|
|
| 68.0 | % |
|
| 42,403 |
|
|
| 71.3 | % |
Tolling and terminaling |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-Parties |
|
| 926 |
|
|
| 0.8 | % |
|
| 930 |
|
|
| 1.6 | % |
|
| $ | 110,683 |
|
|
| 100.0 | % |
| $ | 59,413 |
|
|
| 100.0 | % |
Interest expense.
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, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Jonathan Carroll |
|
|
|
|
|
| ||
Guaranty Fee Agreements |
|
|
|
|
|
| ||
LE Term Loan Due 2034 |
| $ | 107 |
|
| $ | 108 |
|
LRM Term Loan Due 2034 |
|
| 45 |
|
|
| 45 |
|
March Carroll Note (in default) |
|
| 49 |
|
|
| 29 |
|
LEH |
|
|
|
|
|
|
|
|
BDPL-LEH Loan Agreement (in default) |
|
| 160 |
|
|
| 160 |
|
June LEH Note (in default) |
|
| 206 |
|
|
| 182 |
|
Ingleside |
|
|
|
|
|
|
|
|
March Ingleside Note (in default) |
|
| 21 |
|
|
| 14 |
|
|
| $ | 588 |
|
| $ | 538 |
|
Other. BDSC received under the office sub-lease agreement withsublease income from LEH totaled approximatelytotaling $0.01 million for both three-month periods ended March 31, 20212022 and 2020.2021. The LEH operating fee was also relatively flat totaling approximately $0.1 million for both three-month periods ended March 31, 2022 and 2021, and 2020.
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
(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. Refinery operations relate to the refiningterminaling, focused on tolling and marketing ofstoring petroleum products at our 15,000-bpd crude distillation tower. Tolling and terminaling operations relate to tolling and storage terminaling services under third-party lease agreements. Both operations are conductedfor third parties at the Nixon facility. Corporate and other includes BDSC, BDPL, and BDPC.
Revenue from Contracts with Customers
Disaggregation of Revenue
.Receivables from Contracts with Customers
.Contract Liabilities
. Our contract liabilitiesRemaining Performance Obligations
. Most of our customer contractsRemainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | March 31, |
| 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 | ||
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, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Net revenue (excluding intercompany fees and sales) |
|
|
|
|
|
| ||
Refinery operations |
| $ | 109,757 |
|
| $ | 58,483 |
|
Tolling and terminaling |
|
| 926 |
|
|
| 930 |
|
Total net revenue |
|
| 110,683 |
|
|
| 59,413 |
|
|
|
|
|
|
|
|
|
|
Intercompany fees and sales |
|
|
|
|
|
|
|
|
Refinery operations |
|
| (653 | ) |
|
| (566 | ) |
Tolling and terminaling |
|
| 653 |
|
|
| 566 |
|
Total intercompany fees |
|
| 0 |
|
|
| 0 |
|
|
|
|
|
|
|
|
|
|
Operation costs and expenses(1) |
|
|
|
|
|
|
|
|
Refinery operations |
|
| (103,458 | ) |
|
| (59,289 | ) |
Tolling and terminaling |
|
| (619 | ) |
|
| (334 | ) |
Corporate and other |
|
| (11 | ) |
|
| (54 | ) |
Total operation costs and expenses |
|
| (104,088 | ) |
|
| (59,677 | ) |
|
|
|
|
|
|
|
|
|
Segment contribution margin (deficit) |
|
|
|
|
|
|
|
|
Refinery operations |
|
| 5,646 |
|
|
| (1,372 | ) |
Tolling and terminaling |
|
| 960 |
|
|
| 1,162 |
|
Corporate and other |
|
| (11 | ) |
|
| (54 | ) |
Total segment contribution margin (deficit) |
|
| 6,595 |
|
|
| (264 | ) |
|
|
|
|
|
|
|
|
|
General and administrative expenses(2) |
|
|
|
|
|
|
|
|
Refinery operations |
|
| (282 | ) |
|
| (301 | ) |
Tolling and terminaling |
|
| (70 | ) |
|
| (68 | ) |
Corporate and other |
|
| (431 | ) |
|
| (413 | ) |
Total general and administrative expenses |
|
| (783 | ) |
|
| (782 | ) |
|
|
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
|
|
|
|
|
|
Refinery operations |
|
| (307 | ) |
|
| (302 | ) |
Tolling and terminaling |
|
| (342 | ) |
|
| (340 | ) |
Corporate and other |
|
| (52 | ) |
|
| (51 | ) |
Total depreciation and amortization |
|
| (701 | ) |
|
| (693 | ) |
|
|
|
|
|
|
|
|
|
Interest and other non-operating expenses, net(3) |
|
|
|
|
|
|
|
|
Refinery operations |
|
| (717 | ) |
|
| (598 | ) |
Tolling and terminaling |
|
| (418 | ) |
|
| (452 | ) |
Corporate and other |
|
| (457 | ) |
|
| (385 | ) |
Total interest and other non-operating expenses, net |
|
| (1,592 | ) |
|
| (1,435 | ) |
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes |
|
|
|
|
|
|
|
|
Refinery operations |
|
| 4,340 |
|
|
| (2,573 | ) |
Tolling and terminaling |
|
| 130 |
|
|
| 302 |
|
Corporate and other |
|
| (951 | ) |
|
| (903 | ) |
Total income (loss) before income taxes |
|
| 3,519 |
|
|
| (3,174 | ) |
|
|
|
|
|
|
|
|
|
Income tax expense |
|
| (41) |
|
|
| 0 |
|
|
|
|
|
|
|
|
|
|
Net income (loss) |
| $ | 3,478 |
|
| $ | (3,174 | ) |
(1) | Operation costs include cost of goods sold. Also, operation costs within: (a) tolling and terminaling includes terminal operating expenses and an allocation of other costs (e.g., insurance and maintenance) and (b) corporate and other includes expenses related to BDSC, BDPC and BDPL. |
(2) | General and administrative expenses within refinery operations include the LEH operating fee and accretion of asset retirement obligations. |
(3) | Corporate and other within interest and other non-operating expenses, net primarily reflects interest expense for the LE Amended and Restated Guaranty Fee Agreement, LRM Amended and Restated Guaranty Fee Agreement, June LEH Note, March Carroll Note, and March Ingleside Note. |
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
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 |
|
| Three Months Ended |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Capital expenditures |
|
|
|
|
|
| ||
Refinery operations |
| $ | 0 |
|
| $ | 0 |
|
Tolling and terminaling |
|
| 0 |
|
|
| 0 |
|
Corporate and other |
|
| 0 |
|
|
| 0 |
|
Total capital expenditures |
| $ | 0 |
|
| $ | 0 |
|
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Identifiable assets |
|
|
|
|
|
| ||
Refinery operations |
| $ | 48,741 |
|
| $ | 45,186 |
|
Tolling and terminaling |
|
| 17,434 |
|
|
| 18,527 |
|
Corporate and other |
|
| 1,518 |
|
|
| 1,839 |
|
Total identifiable assets |
| $ | 67,693 |
|
| $ | 65,552 |
|
(5)
Bank Accounts
Financial instruments that potentially subject us to concentrations of risk consist primarily of cash, trade receivables and payables. We maintain cash balances at financial institutions in Houston, Texas. The FDIC insures certain financial products up to a maximum of $250,000 per depositor. At March 31, 20212022 and December 31, 2020, we had2021, our cash balances (including restricted cash) that exceededdid not exceed the FDIC insurance limit per depositor of approximately $0.3 million and $0.6 million, respectively.
Key Supplier
Operation of the Nixon refinery depends on our ability to purchase adequate amounts of crude oil and condensate. We have a long-term crude supply agreement in place with Pilot.Tartan. The crude supply agreement, the initial term of which is volume based,volume-based Crude Supply Agreement expires when Pilot sells uswe receive 24.8 million net bbls of crude oil. Thereafter,After that, the crude supply agreementCrude Supply Agreement automatically renews for successive one-year terms (each such term, a “Renewal Term”) unless eitherrenewal term). Either party providesmay provide the other with notice of nonrenewalnon-renewal at least 60 days prior tobefore the expiration of any Renewal Term. Total volume billed under the crude supply agreement totaled approximately 5.8 million bbls asrenewal term. As of March 31, 2021. Effective March 1, 2020, Pilot assigned its rights, title, interest, and obligations in2022, we received approximately 10.1 million bbls, or 40.4%, of the crude supply agreementcontracted total volume under the Crude Supply Agreement.
Related to Tartan Oil LLC, a Pilot affiliate. Sustained periods of low crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations. During the three-month periods ended March 31, 2021 and 2020, our refinery experienced 1 day and no days, respectively, of downtime as a result of lack of crude due to cash constraints.
Our financial health could behas been materially and adversely affected by defaults in our secured loan agreements, substantial current debt, margin deterioration and volatility, historichistorical net losses and working capital deficits, as well as termination ofand equity deficits. If Tartan terminates the crude supply agreementCrude Supply Agreement or terminal services agreement, with Pilot, which could impact our ability to acquire crude oil and condensate. In addition, sustained periods of lowcondensate could be adversely affected. If producers experience crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. During the three-month period ended March 31, 2021,costs, our refinery experienced 1 day of downtime as a result of lack of crude dueacquisition costs may rise, or we may not receive sufficient amounts to cash constraints. A failure to acquire crude oil and condensate when needed will have a material effect onmeet our business results and operations.
Significant Customers
We routinely assess the financial strength of our customers andcustomers. To date, we have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.
Number Significant Customers | % Total Revenue from Operations | Portion of Accounts Receivable at March 31, | |
| (in thousands, except percents) | |||
| March 31, 2021 | 4 | 90% | $0 |
| March 31, 2020 | 4 | 94% | $0.6 million |
Three Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at March 31, |
| |||
|
|
|
|
|
|
|
|
|
| |||
March 31, 2022 |
|
| 3 |
|
|
| 64.9 | % |
| $ | 0 |
|
March 31, 2021 |
|
| 4 |
|
|
| 90.4 | % |
| $ | 0 |
|
One of our significant customers is LEH, an Affiliate. TheDue 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 due to a HUBZone certification.terms. The Affiliate accounted for 27%31.2% and 29%27.1% of total revenue from operations infor the three months ended March 31, 2022 and 2021, and 2020, respectively. The Affiliate represented $0 in accounts receivable at both March 31, 2022 and 2021, and 2020, respectively. Amounts outstanding relating to the Jet Fuel Sales Agreement can significantly vary period to period based on the timing of the related sales and payments received. Amounts we owed to LEH under various long-term debt, related-party agreements totaled $16.6 million and $16.3 million at March 31, 2021 and December 31, 2020, respectively. See “Notes (3) and (16)” to our consolidated financial statements for additional disclosures related to transactions with Affiliates.
Blue Dolphin Energy Company | March 31, 2022 │Page 24 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Concentration of Customers
. Our customer base is concentrated on 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. This includes the uncertainties related to the COVID-19 pandemic and the associated volatility in the globalRefined Product Sales
. We sell our products primarily in the U.S. within PADD 3. Occasionally we sell refined products to customers that export toThree 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% | |
|
| Three Months Ended March 31, |
| |||||||||||||
|
| 2022 |
|
| 2021 |
| ||||||||||
|
| (in thousands, except percent amounts) |
| |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
LPG mix |
| $ | 0 |
|
|
| 0.0 | % |
| $ | 6 |
|
|
| 0.0 | % |
Naphtha |
|
| 27,754 |
|
|
| 25.2 | % |
|
| 14,224 |
|
|
| 24.3 | % |
Jet fuel |
|
| 34,518 |
|
|
| 30.3 | % |
|
| 16,080 |
|
|
| 27.5 | % |
HOBM |
|
| 23,075 |
|
|
| 22.0 | % |
|
| 15,663 |
|
|
| 26.8 | % |
AGO |
|
| 24,410 |
|
|
| 22.5 | % |
|
| 12,510 |
|
|
| 21.4 | % |
|
| $ | 109,757 |
|
|
| 100.0 | % |
| $ | 58,483 |
|
|
| 100.0 | % |
An Affiliate, LEH, purchases all of our jet fuel. See “Notes (3) and (16)(15)” to our consolidated financial statements for additional disclosures related to Affiliate transactions.
(6)
Prepaid expenses and other current assets as of the dates indicated consisted of the following:
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, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Prepaid crude oil and condensate |
| $ | 932 |
|
| $ | 1,368 |
|
Prepaid insurance |
|
| 680 |
|
|
| 953 |
|
Prepaid easement renewal fees |
|
| 71 |
|
|
| 76 |
|
Other prepaids |
|
| 49 |
|
|
| 36 |
|
|
| $ | 1,732 |
|
| $ | 2,433 |
|
(7)
Inventory as of the dates indicated consisted of the following:
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, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
HOBM |
| $ | 3,265 |
|
| $ | 1,749 |
|
Naphtha |
|
| 1,107 |
|
|
| 189 |
|
Crude oil and condensate |
|
| 954 |
|
|
| 660 |
|
AGO |
|
| 305 |
|
|
| 338 |
|
Chemicals |
|
| 116 |
|
|
| 121 |
|
Propane |
|
| 43 |
|
|
| 27 |
|
LPG mix |
|
| 20 |
|
|
| 14 |
|
|
| $ | 5,810 |
|
| $ | 3,098 |
|
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
(8)
Property, plant and equipment, net, as of the dates indicated consisted of the following:
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, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Refinery and facilities |
| $ | 72,583 |
|
| $ | 72,583 |
|
Land |
|
| 566 |
|
|
| 566 |
|
Other property and equipment |
|
| 903 |
|
|
| 903 |
|
|
|
| 74,052 |
|
|
| 74,052 |
|
|
|
|
|
|
|
|
|
|
Less: Accumulated depreciation and amortiation |
|
| (18,444 | ) |
|
| (17,795 | ) |
|
|
| 55,608 |
|
|
| 56,257 |
|
|
|
|
|
|
|
|
|
|
CIP |
|
| 3,666 |
|
|
| 3,666 |
|
|
| $ | 59,274 |
|
| $ | 59,923 |
|
(9)
Accrued expenses and other current liabilities as of the dates indicated consisted of the following:
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 | |
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Unearned revenue from contracts with customers |
| $ | 3,066 |
|
| $ | 4,388 |
|
Accrued fines and penalties |
|
| 407 |
|
|
| 407 |
|
Unearned contract renewal income |
|
| 400 |
|
|
| 400 |
|
Board of director fees payable |
|
| 263 |
|
|
| 230 |
|
Other payable |
|
| 207 |
|
|
| 218 |
|
Taxes payable |
|
| 203 |
|
|
| 136 |
|
Customer deposits |
|
| 173 |
|
|
| 173 |
|
Insurance |
|
| 136 |
|
|
| 273 |
|
|
| $ | 4,855 |
|
| $ | 6,225 |
|
(10)
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 | |
Outstanding Principal, Debt Issue Costs, and Accrued Interest
Third-party long-term debt, (outstandingincluding outstanding principal and accrued interest),interest, as of the dates indicated was as follows:
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, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Veritex Loans |
|
|
|
|
|
| ||
LE Term Loan Due 2034 (in default) |
| $ | 23,580 |
|
| $ | 23,789 |
|
LRM Term Loan Due 2034 (in default) |
|
| 9,777 |
|
|
| 9,861 |
|
Kissick Debt (in default) |
|
| 10,409 |
|
|
| 10,210 |
|
GNCU Loan |
|
|
|
|
|
|
|
|
NPS Term Loan Due 2031 (in default) |
|
| 9,976 |
|
|
| 10,094 |
|
SBA EIDLs |
|
|
|
|
|
|
|
|
BDEC Term Loan Due 2051 |
|
| 2,025 |
|
|
| 512 |
|
LE Term Loan Due 2050 |
|
| 158 |
|
|
| 156 |
|
NPS Term Loan Due 2050 |
|
| 158 |
|
|
| 156 |
|
Equipment Loan Due 2025 |
|
| 49 |
|
|
| 53 |
|
|
|
| 56,132 |
|
|
| 54,831 |
|
|
|
|
|
|
|
|
|
|
Less: Current portion of long-term debt, net |
|
| (43,004 | ) |
|
| (42,953 | ) |
Less: Unamortized debt issue costs |
|
| (2,301 | ) |
|
| (2,351 | ) |
Less: Accrued interest payable (in default) |
|
| (8,493 | ) |
|
| (8,689 | ) |
|
| $ | 2,334 |
|
| $ | 838 |
|
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Unamortized debt issue costs associated with the Veritex and GNCU loans as of the dates indicated consisted of the following:
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, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Veritex Loans |
|
|
|
|
|
| ||
LE Term Loan Due 2034 (in default) |
| $ | 1,674 |
|
| $ | 1,674 |
|
LRM Term Loan Due 2034 (in default) |
|
| 768 |
|
|
| 768 |
|
GNCU Loan |
|
|
|
|
|
|
|
|
NPS Term Loan Due 2031 (in default) |
|
| 730 |
|
|
| 730 |
|
|
|
|
|
|
|
|
|
|
Less: Accumulated amortization |
|
| (871 | ) |
|
| (821 | ) |
|
| $ | 2,301 |
|
| $ | 2,351 |
|
Amortization expense was $0.05 million and $0.03 million for both three-month periodsthe three months ended March 31, 2022 and 2021, and 2020.
Accrued interest related to third-party long-term debt, reflected as accrued interest payable in our consolidated balance sheets, as of the dates indicated consisted of the following:
March 31, | December 31, | |
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 | $- | $- |
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Kissick Debt (in default) |
| $ | 5,431 |
|
| $ | 5,232 |
|
Veritex Loans |
|
|
|
|
|
|
|
|
LE Term Loan Due 2034 (in default) |
|
| 2,129 |
|
|
| 2,338 |
|
LRM Term Loan Due 2034 (in default) |
|
| 875 |
|
|
| 959 |
|
GNCU Loan |
|
|
|
|
|
|
|
|
NPS Term Loan Due 2031 (in default) |
|
| 17 |
|
|
| 136 |
|
SBA EIDLs |
|
|
|
|
|
|
|
|
BDEC Term Loan Due 2051 |
|
| 25 |
|
|
| 12 |
|
LE Term Loan Due 2050 |
|
| 8 |
|
|
| 6 |
|
NPS Term Loan Due 2050 |
|
| 8 |
|
|
| 6 |
|
|
|
| 8,493 |
|
|
| 8,689 |
|
Less: Accrued interest payable (in default) |
|
| (8,493 | ) |
|
| (8,689 | ) |
Long-term Interest Payable, Net of Current Portion |
| $ | 0 |
|
| $ | 0 |
|
As reflected in the table above and elsewhere in this report, we are in default under the LE Term Loan Due 2034, LRM Term Loan Due 2034, NPS Term Loan Due 2031, and the Notre DameKissick Debt. Defaults under these secured loan agreements permit the LE Term Loan Due 2034 and LRM Term Loan Due 2034 permit Veritexlender to declare the amounts owed under these loan agreements immediately due and payable, exercise itstheir rights with respect to collateral securing obligors’ obligations under these loan agreements, and/or exercise any other rights and remedies available. The debt associated with the LE Term Loan Due 2034, LRM Term Loan Due 2034, and the Notre Dame Debtthese loan agreements was classified within the current portion of long-term debt on our consolidated balance sheets at March 31, 20212022 and December 31, 2020.
Any exercise by Veritexthird parties of itstheir rights and remedies under our secured loan agreements wouldwill have a material adverse effect on our business operations, including crude oil and condensate procurement and our customer relationships; financial condition; and results of operations. In such a case, the trading price of our common stockCommon Stock and the value of an investment in our common stockCommon Stock could significantly decrease, which could lead to holders of our common stockCommon Stock losing their investment in our common stockCommon Stock in its entirety.
We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements, with Vertitex, either upon maturity or if accelerated, (ii) LE, LRM, and LRMNPS will be able to refinance or restructure the payments of the debt, and/or (iii) Veritex, as first lien holder,third parties will provide future default waivers. Defaults under our secured loan agreements and any exercise by Veritexthird parties of itstheir rights and remedies related to such defaults may have a material adverse effect on our business, the trading prices of our common stockCommon Stock, and on the value of an investment in our common stock,Common Stock, and holders of our common stockCommon Stock could lose their investment in our common stockCommon Stock in its entirety. See “Notes (1) and (11)(3)” to our consolidated financial statements for additional information regarding defaults under our secured loan agreements and their potential effects on our business, financial condition, and results of operations.
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 |
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
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 | |
(11) AROs
Refinery and Facilities
Management has concluded that there is no legal or contractual obligation to dismantle or remove the refinery and facilities assets. Management believes that the refinery and facilities assets have indeterminate lives under FASB ASC guidance for estimating AROs because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a legal or contractual obligation to dismantle or remove the refinery and facilities assets arises and a date or range of dates can reasonably be estimated for the retirement of these assets, we will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using present value techniques.
Pipelines and Facilities and Oil and Gas Properties
We have AROs associated with the decommissioning of our pipelines and facilities assets, as well as the plugging and abandonment ofabandoning our oil and gas properties. We recorded a discounted liability for the fair value of an ARO with a corresponding increase to the carrying value of the related long-lived asset at the time the asset was installed or placed in service, and we depreciated the amount added to property and equipmentequipment. Although these assets were previously fully accreted, during the twelve months ended December 31, 2021 we determined that the estimated future cost and recognizedtiming of decommissioning these assets changed. As a result, we recorded an increase in liability at December 31, 2021, and we will recognize accretion expense relating to the discounted liability over the remaining life of the asset. At March 31, 2021 and December 31, 2020,assets over their remaining life.
ARO liability as of the liabilitydates indicated was fully accreted. as follows:
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
AROs, at the beginning of the period |
| $ | 3,461 |
|
| $ | 2,370 |
|
Changes in estimates of existing obligations |
|
| 0 |
|
|
| 1,091 |
|
Accretion expense |
|
| 33 |
|
|
| 0 |
|
|
|
| 3,494 |
|
|
| 3,461 |
|
Less: AROs, current portion |
|
| 0 |
|
|
| 0 |
|
Long-term AROs, at the end of the period |
| $ | 3,494 |
|
| $ | 3,461 |
|
See “Note (16)(15)” to our consolidated financial statements for disclosures related to decommissioning of our offshore pipelines and platform assets and related risks.
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 | $- | $- |
(12) Lease Obligations
Lease Obligations
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 of rent. In May 2021, BDSC and TR 801 Travis LLC (“Building Lessor”) reached an agreement to cure BDSC’s office lease default. Under the terms of a Delaware limited partnership, informed BDSC that it was in default under itsfourth amendment to the office lease.lease, Building Lessor agreed to defer BDSC’s failure to pay 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 including the prorated portion of the Past Due Obligations was $0.02 million.
Building Lessor notified BDSC in an agreementOctober 11, 2021 letter of a new default under the office lease due to non-payment of rent. As of the filing date of this report, BDSC was in default related to required monthly base rent including Past Due Obligations, as well as for proportionate base costs. 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. BDSC and Lessor are in discussions with regard to requirements to cure the default. See “Note (17) Subsequent Events”Although management desires to our consolidated financial statements for additional disclosures related tocure the Houston office lease.
An Affiliate, LEH, subleases a portion of the Houston office space. SubleaseBDSC received sublease income received from LEH totaled approximately $0.01totaling $0.008 million for both the three monthsthree-month periods ended March 31, 20212022, and 2020.2021. See “Note (3)” to our consolidated financial statements for additional disclosures related to the Affiliate sub-lease.
Blue Dolphin Energy Company | March 31, 2022 │Page 28 |
| 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 | |
|
|
|
|
| March 31, |
|
| December 31, |
| |||
|
| Balance Sheet Location |
|
| 2022 |
|
| 2021 |
| |||
|
|
|
|
| (in thousands) |
| ||||||
Assets |
|
|
|
|
|
|
|
|
| |||
Operating lease ROU assets |
| Operating lease ROU assets |
|
| $ | 787 |
|
| $ | 787 |
| |
Less: Accumulated amortization on operating lease assets |
| Operating lease ROU assets |
|
|
| (499 | ) |
|
| (455 | ) | |
|
|
|
|
|
|
|
|
|
|
|
| |
Total lease assets |
|
|
|
|
| 288 |
|
|
| 332 |
| |
|
|
|
|
|
|
|
|
|
|
|
| |
Liabilities |
|
|
|
|
|
|
|
|
|
|
| |
Current |
|
|
|
|
|
|
|
|
|
|
| |
Operating lease |
| Current portion of lease liabilities |
|
|
| 220 |
|
|
| 215 |
| |
|
|
|
|
|
|
|
|
|
|
|
| |
Noncurrent |
|
|
|
|
|
|
|
|
|
|
| |
Operating lease |
| Long-term lease liabilities, net of current |
|
|
| 99 |
|
|
| 156 |
| |
Total lease liabilities |
|
|
|
|
| $ | 319 |
|
| $ | 371 |
|
Weighted average remaining lease term in years | |||||
Operating lease | 1.42 | ||||
Weighted average discount rate | |||||
Operating lease | 8.25 | % | |||
Finance leases | 8.25 | % | |||
The following table presents information related to lease costs incurred 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 |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
Operating lease costs |
| $ | 51 |
|
| $ | 51 |
|
Total lease cost |
| $ | 51 |
|
| $ | 51 |
|
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 |
|
|
|
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
|
|
| (in thousands) |
| |||
Cash paid for amounts included in the measurement of lease liabilities: |
|
|
|
|
|
| ||
Operating cash flows for operating lease |
| $ | 52 |
|
| $ | 47 |
|
As of March 31, 2021,2022, maturities of lease liabilities for the periods indicated were as follows:
| March 31, | Operating Lease |
(in thousands) | |
| 2021 | $199 |
| 2022 | 220 |
| 2023 | 99 |
$518 |
March 31, |
| Operating Lease |
|
| Total |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
2023 |
| $ | 220 |
|
| $ | 220 |
|
2024 |
|
| 99 |
|
|
| 99 |
|
|
|
|
|
|
|
|
|
|
|
| $ | 319 |
|
| $ | 319 |
|
Future minimum annual lease commitments that are non-cancelable:
Operating | |
| March 31, | Lease |
(in thousands) | |
| 2021 | $233 |
| 2022 | 237 |
| 2023 | 101 |
$571 |
|
| Operating |
| |
March 31, |
| Lease |
| |
|
| (in thousands) |
| |
2023 |
| $ | 238 |
|
2024 |
|
| 101 |
|
|
| $ | 339 |
|
Blue Dolphin Energy Company | March 31, 2022 │Page 29 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(13) Income Taxes
Tax Provision
The provision for income tax expensebenefit (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 |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Current |
|
|
|
|
|
| ||
Federal |
| $ | 0 |
|
| $ | 0 |
|
State |
|
| (41) |
|
|
| 0 |
|
Deferred |
|
|
|
|
|
|
|
|
Federal |
|
| (1,086) |
|
|
| 667 |
|
State |
|
| 0 |
|
|
| 0 |
|
Change in valuation allowance |
|
| 1,086 |
|
| (667 | ) | |
|
|
|
|
|
|
|
|
|
Total provision for income taxes |
| $ | (41) |
|
| $ | 0 |
|
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 | $- | $- |
|
| March 31, |
|
| December 31, |
| ||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Deferred tax assets: |
|
|
|
|
|
| ||
NOL and capital loss carryforwards |
| $ | 15,588 |
|
| $ | 16,818 |
|
Business interest expense |
|
| 4,573 |
|
|
| 4,680 |
|
Start-up costs (crude oil and condensate processing facility) |
|
| 403 |
|
|
| 424 |
|
ARO liability/deferred revenue |
|
| 734 |
|
|
| 727 |
|
Other |
|
| 18 |
|
|
| 12 |
|
Total deferred tax assets |
|
| 21,316 |
|
|
| 22,661 |
|
|
|
|
|
|
|
|
|
|
Deferred tax liabilities: |
|
|
|
|
|
|
|
|
Basis differences in property and equipment |
|
| (8,012 | ) |
|
| (7,945 | ) |
Total deferred tax liabilities |
|
| (8,012 | ) |
|
| (7,945 | ) |
|
|
| 13,304 |
|
|
| 14,716 |
|
|
|
|
|
|
|
|
|
|
Valuation allowance |
|
| (13,304 | ) |
|
| (14,716 | ) |
|
|
|
|
|
|
|
|
|
Deferred tax assets, net |
| $ | 0 |
|
| $ | 0 |
|
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 ofBlue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
NOL Carryforwards
. NOL carryforwards that remained available for future use for the periods indicated were as follow (amounts shown are net of NOLs that will expire unused because of the IRC Section 382 limitation):Net Operating Loss Carryforward | |||
Pre-Ownership Change | Post-Ownership Change | Total | |
(in thousands) | |||
| Balance at December 31, 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, 2020 |
|
| 9,614 |
|
|
| 56,363 |
|
|
| 65,977 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net operating losses used and expired |
|
| (1,717 | ) |
|
| 9,148 |
|
|
| 7,431 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2021 |
| $ | 7,897 |
|
| $ | 65,511 |
|
| $ | 73,408 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net operating losses used and expired |
|
| (5,855 | ) |
|
| 0 |
|
|
| (5,855 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at March 31, 2022 |
| $ | 2,042 |
|
| $ | 65,511 |
|
| $ | 67,553 |
|
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 March 31, 2022 and December 31, 2021, there were no uncertain tax positions for which a reserve or liability was necessary.
(14)Earnings Per Share
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 |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands, |
| |||||
|
| except share and per share amounts) |
| |||||
|
|
|
|
|
|
| ||
Net income (loss) |
| $ | 3,478 |
|
| $ | (3,174 | ) |
|
|
|
|
|
|
|
|
|
Basic and diluted income (loss) per share |
| $ | 0.27 |
|
| $ | (0.25 | ) |
|
|
|
|
|
|
|
|
|
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 |
|
Diluted EPS is computed by dividing net income available to common stockholders by the weighted average number of shares of common stock outstanding. Diluted EPS for the three months ended March 31, 20212022 and 20202021 was the same as basic EPS as there were no stock options or other dilutive instruments outstanding.
Blue Dolphin Energy Company | March 31, 2022 │Page 31 |
| Table of Contents |
Notes to Consolidated Financial Statements |
(15) Commitments and Contingencies
Amended and Restated Operating Agreement
See “Note (3)” to our consolidated financial statements for additional disclosures related to operation and management of all Blue Dolphin propertiesassets by an Affiliate under the Amended and Restated Operating Agreement.
BSEE Offshore Pipelines and Platform Decommissioning
BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations. Until such structures are abandoned or removed, lessees and rights-of-way holders are required to inspect and maintain the assets in accordance with regulatory requirements.
In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE onin August 15, 2019 to address BDPL’s plans with respect to decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning along withpermit applications, including a safe boarding plan, for the platform, within six (6) months (no later thanby February 15, 2020), and develop and implement a safe boarding plan for submission with such permit applications. Further, BSEE proposed that2020. BDPL complete approved, permitted work within twelve (12) months (no later than August 15, 2020). BDPL timely submitted permit applications for decommissioning of the subject offshore pipelines and platform assets to BSEE onin February 11, 2020 and the USACOE onin March 25, 2020. Although we planned to decommission the offshore pipelines 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. We cannot currently estimate when decommissioning may occur. In the interim, BDPL provides BSEE with updates regarding the project’s status.
Lack of permit approvals does 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 platform assets and/or remedy the INCs within a timeframe determined to be 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, which 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 havedid not recordedrecord a liability related to potential penalties on our consolidated balance sheetsheets as of March 31, 2022 and December 31, 2021. At both March 31, 20212022 and December 31, 2020,2021, BDPL maintained $2.4$3.5 million in AROs related to abandonment of these assets.
Defaults Under Secured Loan Agreements with Third Parties
See “Notes (1), (3), (10), and (11)(10)” to our consolidated financial statements for additional disclosures related to defaults under our secured and unsecured debt agreements.
Financing Agreements and Guarantees
Indebtedness
. See “Notes (1), (3),Guarantees
. Affiliates provided guarantees on certain debt of Blue Dolphin and its subsidiaries. The maximum amount of any guarantee is equal to the principal amount and accrued interest, which amounts are reduced as payments are made. See “Notes (1), (3),Health, 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
In the ordinary course of business, we are involved in legal matters incidental to the routine operation of our business, such as mechanic’s liens and contract-related disputes. We may also become party to lawsuits, administrative proceedings, and governmental investigations, including environmental, regulatory, and other matters. Large, and sometimes unspecified, damages or penalties may be sought from us in some matters and certain matters may require years to resolve. Although we cannot provide assurance, we believe that an adverse resolution of the matters described below would not have a material impact on our liquidity, consolidated financial position, or consolidated results of operations.
Blue Dolphin Energy Company | March 31, 2022 │Page 32 |
| Table of Contents |
Notes to Consolidated Financial Statements |
Unresolved Matters.
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
. To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days.rights-of-way. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Although the IBLA granted multiple extension requests, that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, theThe 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 eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Although we planned to decommission the offshore pipelines and platform assets during 2020, decommissioningDecommissioning of these assets has beenwas delayed due to our cash constraints associated with historical net losses and the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico.COVID-19. We cannot currently estimate when decommissioning may occur. In the interim, BDPL provides BOEM and BSEE with updates regarding the project’s status.
BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we havedid not recordedrecord a liability on our consolidated balance sheetsheets as of March 31, 2022 and December 31, 2021. At both March 31, 20212022 and December 31, 2020,2021, BDPL maintained approximately $0.9 million in credit and cash-backedpipeline rights-of-way surety bonds issued to BOEM through RLI Corp. Of the pipeline rights-of-way bonds, issued$0.7 million was credit-backed and $0.2 million was cash-backed.
TCEQ Proposed Agreed Order. In October 2021, LRM received a proposed agreed order from the TCEQ for alleged solid and hazardous waste violations discovered during an investigation from January 29, 2020 to BOEM.
Pilot Dispute Related to Set-Off Payments. On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. However, in a letter from NPS to Pilot dated October 28, 2021, NPS disputed approximately $0.3 million in payments Pilot made to Tartan arising under a product sales agreement. NPS contends the disputed amount should have been applied to the balance owed by NPS under the Amended Pilot Line of Credit. Pilot has asserted that the redirected payment was offset by accrued interest owed by NPS under the Amended Pilot Line of Credit. As of the filing date of this report, the amount remained in dispute between the parties.
Defaults under Secured Loan Agreements. We are involvedcurrently in lawsuits, claims, and proceedings incidental to the conductdefault under certain of our business, including mechanic’s liens, contract-related disputes, and administrative proceedings. Management is in discussionsecured loan agreements with all concernedthird parties and does not believe thatrelated parties. See “Notes (1), (3), and (10)” to our consolidated financial statements for additional disclosures related to third-party and related-party debt, defaults on such matters will have a material adverse effectdebt, and the potential effects of such defaults on our business, financial position, earnings, or cash flows. However, there can be no assurance that such discussions will result in a manageable outcome.condition, and results of operations. If Veritex and/or Pilotthird parties exercise their rights and remedies due to defaults under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
Counterparty Contract-Related Dispute. As of the filing date of this report, we were involved in a contract-related dispute with Tartan involving a revenue sharing-arrangement for the storage and sale of crude oil. Management is working to resolve the dispute amicably, however, the potential outcome is unknown. Management does not believe that the contract-related dispute will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurance that management’s efforts will result in a manageable outcome.
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Notes to Consolidated Financial Statements |
Resolved Matters.
None.
(16) Subsequent Events
Sales of Unregistered Securities.
Set forth below is information regarding the sale or issuance of shares of Common Stock by us that were not registered under the Securities Act of 1933 and subsequent to the three months ended March 31, 2022:
On May 11, 2021, BDSC and TR 801 Travis LLC reached12, 2022, we issued an agreementaggregate of 1,853,080 restricted shares of Common Stock to cure BDSC’s Houston office lease default. Under the termsJonathan Carroll, which represents payment of the arrangement, BDSCcommon stock component under the LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement for monthly periods from April 30, 2020 through March 31, 2022. The average cost basis was $0.42, the low was $0.27, and the high was $0.64. Currently, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will pay TR 801 Travis LLC past due obligations, including rent installmentscontinue to accrue and other charges totaling approximately $0.1 million (the “Past Due Obligations”), in equal monthly installments beginning June 1,be added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement.
On May 12, 2022, we also issued an aggregate of 252,447 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three-month periods ended September 30, 2020, March 31, 2021, September 30, 2021, and continuing throughMarch 31, 2022. The average cost basis was $0.55, the August 31, 2023 lease expiration date. low was $0.33, and the high was $0.91.
The Past Due Obligations shall be subject to an annual percentage rate of 4.50%. As revised, BDSC’ monthly base rent plus the prorated portionsale and issuance of the Past Due Obligations will approximate $0.02 million.
Remainder of Page Intentionally Left Blank
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Management’s Discussion and Analysis |
Management’s Discussion and Analysis is our analysis of our financial performance, financial condition, and significant trends that may affect future performance. All statements in this section, other than statements of historical fact, are forward-looking statements that are inherently uncertain. See “Important Information Regarding Forward-Looking Statements” for a discussion of the factors that could cause actual results to differ materially from those projected in these statements. You should read the following discussion together with the financial statements and the related notes included elsewhere in this Quarterly Report, as well as with the business strategy, risk factors, and financial statements and related notes included thereto in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020
Overview
Blue Dolphin is an independent downstream energy company operating in the Gulf Coast region of the United States. Our subsidiaries operate a light sweet-crude, 15,000-bpd crude distillation tower with approximatelymore than 1.2 million bbls of petroleum storage tank capacity in Nixon, Texas. Blue Dolphin was formed in 1986 as a Delaware corporation and is traded on the OTCQX under the ticker symbol “BDCO”.
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 propertiesassets and fundshas historically funded working capital requirements during periods of working capital deficits, and an Affiliate is a significant customer of our refined products. Blue Dolphin and certain of its subsidiaries are currently parties to a variety of agreements with Affiliates. See “Part I, Item 1. Financial Statements – Note (3)” for additional disclosures related to Affiliate agreements, arrangements, and risks associated with working capital deficits.
General Trends and Outlook
We anticipate that our business will continue to be affected by the following key factors. Our expectations are based on assumptions made by us and information currently available to us. To the extent our underlying assumptions about, or interpretations of, available information prove to be incorrect, our actual results may vary materially from our expected results.
COVID-19 Pandemic. In March 2020, the WHO declared the outbreak of the COVID-19 pandemic negatively impacted worldwide economic and commercial activity and financial markets, as well as global demand for petroleum products. As a result 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, we are cautiously optimistic that the global economy, oil demand, and commodity prices will recover from the impact of the pandemic.
Russian-Ukrainian Conflict. In February 2022, Russia invaded neighboring Ukraine. The conflict caused turmoil in global markets, injecting even more uncertainty into a worldwide economy recovering from the effects of COVID-19. Sanctions imposed on Russia resulted in global tightening of refined product inventories and crude stocks, which caused refining margins to widen significantly. These conditions contributed to a significant improvement in our refining operating results in the first quarter of 2022 compared to the prior year. Despite favorable refining margins during the first quarter, the future impact of the Russian-Ukrainian Conflict on our financial condition, cash flows,position and our abilityresults of operations remains uncertain.
Liquidity and Access to service our indebtednessCapital Markets. We continue to actively explore additional financing to meet working capital needs or refinance and other obligations.restructure debt. During the three months ended March 31, 2022 and 2021, we successfully secured an additional $1.5 million and $0, respectively, in working capital through CARES Act loans. There can also be no assurance that we will be able to raise additional capital on acceptable terms, or at all. If we are unable to raise sufficient additional capital, we may not, in the short term, be able to purchase crude oil and condensate or meet debt payment obligations. In the long term, we may not be able to withstand business disruptions, such as those related to COVID-19 or the Russian conflict with Ukraine, or execute our liquidity, business financial condition, and results of operations will revertstrategy. We may have to pre-2020 levels once the impacts of the COVID-19 pandemic cease.
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Management’s Discussion and Analysis |
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, substantial current debt, margin deterioration and volatility, and historichistorical net losses and working capital and equity deficits. 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 ascould 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.
Business Opportunities. We are currently in default under certain of our secured loan agreements with third parties and related parties. As a result, the debt associated with these obligations was classified within the current portion of long-term debt on our consolidated balance sheets at March 31, 2021 and December 31, 2020. See “Part I, Item 1. Financial Statements – Notes (1), (3), (10), and (11)” for additional disclosures related to third-party and related-party debt, defaults on such debt, and the potential effects of such defaults on our business, financial condition, and results of operations.
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 |
Changes in Regulations. Our operations and the operations of our customers have been, and will continue to be, affected by political developments and federal, state, tribal, local, and other laws and regulations that are becoming more numerous, more stringent, and more complex. These laws and regulations include, among other things, permitting requirements, environmental protection measures such as limitations on methane and other GHG emissions, and renewable fuels standards. The number and scope of the regulations with which we and our customers must comply has a meaningful impact on our and their businesses, and new or revised regulations, reinterpretations of existing regulations, and permitting delays or denials could adversely affect the profitability of our assets.
Business Strategy and Accomplishments
Our primary business objectives are to improve our financial profile and refining margins by executing the below strategies, modified as necessary, to reflect changing economic conditions and other circumstances:
Optimize Existing Asset Base | · Maintain safe operations and enhance health, safety, and environmental systems. · Planning and managing turnarounds and downtime. | |
Improve Operational Efficiencies | · Reduce or streamline variable costs incurred in production. · Increase throughput capacity and optimize product slate. · Increase tolling and terminaling revenue | |
Seize Market Opportunities | · Leverage existing infrastructure to engage in renewable energy projects. · Take advantage of market opportunities as they arise. | |
Optimize Existing Asset Base. The refinery experienced less downtime during the three-month period ended March 31, 2022 compared to the same period a year earlier. During the three-month periods ended March 31, 2022 and 2021, the refinery experienced 6 days and 11 days of downtime, respectively. Given recent favorable refining margins, management delayed the Nixon facility’s annual maintenance turnaround in order to maximize refinery runs.
Improve Operational Efficiencies. Management continued to focus on optimizing receivables and payables by prioritizing payments, optimizing inventory levels based on demand, monitoring discretionary spending, and delaying capital expenditures. Continued austerity measures further contributed to improved refinery throughput, production, and sales during the three-months ended March 31, 2022 compared to the same period in 2021.
Seize Market Opportunities. In March 2021, we announced plans to leverage our existing infrastructure to establish adjacent lines of business, capture growing market opportunities, and capitalize on green energy growth. We continue to explore potential commercial partnerships and project-based government loans as vehicles to expand our corporate strategy into renewable energy, and we will continue these efforts throughout 2022. While we believe our renewable energy strategy successfully aligns with our long-term growth strategy and financial and operational priorities, they are aspirational and may change, and there is no guarantee that we will achieve our objectives.
Successful execution of our business strategy depends on several factors. These factors include (i) having adequate working capital to meet operational needs and regulatory requirements, (ii) maintaining safe and reliable operations at the Nixon facility, (iii) meeting contractual obligations, (iv) having favorable margins on refined products, and (v) collaborating with new partners to develop and finance clean energy projects. Our business strategy involves risks. Accordingly, we cannot assure investors that our plans will be successful.
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Management’s Discussion and Analysis |
Downstream Operations
Our refinery operations segment consists of the following assets and operations:
Property | Key Products Handled | Operating Subsidiary | Location | |||||||||
Nixon facility · Crude distillation tower (15,000 bpd) · Petroleum storage tanks · Loading and unloading facilities · Land (56 acres) | Crude Oil Refined Products | LE | Nixon, Texas | |||||||||
Crude Oil and Condensate Supply
. Operation of the Nixon refinery depends on our ability to purchase adequate amounts of crude oil and condensate. We have a long-term crude supply agreement in place withRelated to the crude supply agreement toCrude Supply Agreement, Tartan Oil LLC, a Pilot affiliate. Sustained periods of low crude oil prices due to market volatility associated with the COVID-19 pandemic has resulted in significant financial constraints on producers, which in turn has resulted in long term crude oil supply constraints and increased transportation costs. A failure to acquire crude oil and condensate when needed will have a material effect on our business results and operations. During the three-month periods ended March 31, 2021 and 2020, our refinery experienced 1 day and no days, respectively, of downtime as a result of lack of crude due to cash constraints.
Our financial health has been materially and adversely affected by defaults in our secured loan agreements, substantial current debt, margin volatility, historical net losses and working capital and equity deficits. If Tartan 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 agreement.
Products and Markets
. Our market is the Gulf Coast region of the U.S., which is represented by the EIA as Petroleum Administration for PADD 3. We sell our products primarily in the U.S. within PADD 3. Occasionally, we sell refined products to customers that export toThe Nixon refinery’s product slate is moderately adjusted based on market demand. We currently produce a single finished product – jet fuel – and several intermediate products, including naphtha, HOBM, and AGO. Our jet fuel is sold to an Affiliate, which is HUBZone certified. The product sales agreement with the Affiliate has a 1-year term expiring the earliest to occur of March 31, 20222023 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 require our customers to prepay and us to sell fixed quantities and/or minimum quantities of finished and intermediate petroleum products. Many of these arrangements are subject to periodic renegotiation on a forward-looking basis, which could result in higher or lower relative prices on future sales of our refined products.Competition
.Many of our competitors are substantially larger than us and are engaged on a national or international level in many segments of the oil and gas industry, including exploration and production, gathering and transportation, and marketing. These competitors may have greater flexibility in responding to or absorbing market changes occurring in one or more of these business segments. We compete primarily based on cost. Due to the low complexity of our simple “topping unit” refinery, we can be relatively nimble in adjusting our refined products slate because of changing commodity prices, market demand, and refinery operating costs.Safety and Downtime
.Blue Dolphin Energy Company | March 31, 2022 │Page 37 |
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Management’s Discussion and Analysis |
The Nixon refinery periodically experiencesundergoes 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.
Midstream Operations
Our tolling and terminaling segment consists of the following assets and operations:
Property | Key Products Handled | Operating Subsidiary | Location | |||
Nixon facility ·Petroleum storage tanks ·Loading and unloading facilities | Crude Oil Refined Products | LRM, NPS | Nixon, Texas | |||
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
. OurInactive Operations
We own certain other pipeline and facilities assets and have leasehold interests in oil and gas properties. These assets which are shown belowinactive. We account for these inactive operations in ‘corporate and included in corporate and other, are not operational and are fully impaired. Weother.’ Our pipeline assets have been fully impaired our pipeline assets insince 2016 and our oil and gas leasehold interests inhave been fully impaired since 2011. Our pipeline assets and oil and gas leasehold interests had no revenue during the three months ended March 31, 20212022 and 2020.2021. See “Part I, Item 1. Financial Statements – Note (16)(15)” related to pipelines and platform decommissioning requirements and related 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 and are subject to safety regulations under OSHA, PHMSA, BOEM, BSEE, and comparable state and local regulations. We have response and control plans, spill prevention and other programs to respond to emergencies related to these assets.
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| Table of Contents |
Management’s Discussion and Analysis |
Results of Operations
A discussion and analysis of the factors contributing to our consolidated financial results of operations is presented below and should be in read in conjunction with our financial statements in “Part I, Item 1. Financial Statements”. The financial statements, together with the following information, are intended to provide investors with a reasonable basis for assessing our historical operations, but they should not serve as the only criteria for predicting future performance.
Major Influences on Results of Operations
. Our results of operations and liquidity are highly dependent upon the margins that we receive for our refined products. The dollar per bbl commodity price difference between crude oil and condensate (input) and refined products (output) is the most significant driver of refining margins, and they have historically been subject to wide fluctuations.While refining margins improved significantly in the first quarter of operations throughout 2021.
How We Evaluate Our Operations
. Management uses certain financial and operating measures to analyze segment performance. These measures are significant factors in assessing our operating results and profitability and include: segment contribution margin (deficit), and refining gross profit (deficit) per bbl, tank rental revenue, operation costs and expenses, refinery throughput and production data, and refinery downtime. Segment contribution margin (deficit) and refining gross profit (deficit) per bbl are non-GAAP measures.Segment Contribution Margin (Deficit) and Refining Gross Profit (Deficit) per Bbl
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-GAAP Reconciliations” within this Results of Operations and the financial statements within “Part I, Item 1. Financial Statements” for a reconciliation of Non-GAAP measures to U.S. GAAP.
Tank Rental Revenue
Tolling and terminaling revenue primarily represents tank rental storage fees associated with customer tank rental agreements. As a result, tank rental revenue is one of the measures management uses to evaluate the performance of our tolling and terminaling business segment.
Operation Costs and Expenses
We manage operating costs and expenses in tandem with meeting environmental and safety requirements and objectives and maintaining the integrity of our assets. Operating costs and expenses are comprised primarily of labor expenses, repairs and other maintenance costs, and utility costs. Expenses for refinery operations generally remain stable across broad ranges of throughput volumes, but they can fluctuate from period to period depending on the mix of activities performed during that period and the timing of those expenses. Operation costs and expenses for tolling and terminaling operations are relatively fixed.
Refinery Throughput and Production Data
The amount of revenue we generate from ourthe refinery operations business segment primarily depends on the volumes of crude oil andthat we process into refined products that we handle through our processing assets and the volume of refined products sold to customers. These volumes are affected by the supply and demand of, and demand for, crude oil and refined products in the markets served directly or indirectly by our assets, as well as refinery downtime.
Blue Dolphin Energy Company | March 31, 2022 │Page 39 |
| Table of Contents |
Management’s Discussion and Analysis |
Refinery Downtime
The Nixon refinery periodically experiences planned and unplanned temporary shutdowns. Any scheduled or unscheduled downtime will result in lost margin opportunity, potential increased maintenance expense, and a reduction of refined products inventory, which could reduce our ability to meet our payment obligations.
Consolidated Results
.Our consolidated results of operations include certain other unallocated corporate activities and the elimination of intercompany transactions and therefore do not equal the sum of the operating results of our refinery operations and tolling and terminaling business segments.Three Months Ended March 31, 2022 (“Q1 2022”) Versus March 31, 2021 (“Q1 2021”)
Overview. Net income for Q1 2022 was $3.5 million, or income of $0.27 per share, compared to a net loss of $3.2 million, or a loss of $0.25 per share, in Q1 2021. The $6.7 million, or $0.52 per share, increase in net income between the periods was the result of favorable refining margins and improved product demand as the impact from COVID-19 lessened. The net loss in Q1 2021 was also due to 11 days of refinery downtime, 10 days of which was associated with Winter Storm Uri.
Total Revenue from Operations. Total revenue from operations increased 86% to $110.7 million for Q1 2022 from $59.4 million for Q1 2021. Increased commodity prices primarily drove refinery operations revenue higher in Q1 2022; increased sales volume contributed approximately 10% to the rise in refinery operations revenue. Tolling and terminaling revenue was flat between the periods at $0.9 million.
Total Cost of Goods Sold. Total cost of goods sold increased approximately 75% to $104.1 million for Q1 2022 from $59.6 million for Q1 2021. The significant increase related to higher crude acquisition costs and slightly higher throughput.
Gross Margin (Deficit). Gross margin was $6.6 million for Q1 2022 compared to gross deficit of $0.2 million for Q1 2021. Refinery margins were positively affected by higher commodity prices and improved refinery uptime in Q1 2022 compared to Q1 2021.
General and Administrative Expenses. General and administrative expenses decreased approximately 5% to $0.6 million in Q1 2022 from approximately $0.7 million in Q1 2021. The decrease primarily related to lower insurance premiums and professional fees.
Depreciation and Amortization. Depreciation and amortization expenses totaled approximately $0.7 million for both Q1 2022 and Q1 2021.
Total Other Income (Expense). Total other expense in Q1 2022 was $1.6 million compared to total other expense of $1.4 million in Q1 2021, representing an increase of approximately $0.2 million. Total other expense primarily relates to interest expense associated with third-party and related party secured loan agreements.
Downstream Operations
. Our refinery operations business segment is owned by LE. Assets within this segment consist of a light sweet-crude, 15,000-bpd crude distillation tower, petroleum storage tanks, loading and unloading facilities, and approximately 56 acres of land. Refinery operations revenue is derived from refined product sales.Three Months Ended | ||
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) |
Q1 20212022 Versus Q1 2020
Refining Gross Margin (Deficit) per Bbl. Refining gross margin per bbl was $1.20$5.51 for Q1 20212022 compared to gross deficit per bbl of $1.04$1.20 in Q1 2020,2021, representing a declinesignificant increase of $0.16$6.71 per bbl. The deficitsignificant increase in both periodsQ1 2022 related to higher refining margins, improved product demand as the impact from COVID-19 lessened, and increased refinery uptime. Refining gross deficit per bbl in Q1 2021 was the result of lower margins and market fluctuations associated with the COVID-19 pandemic. Refinerypandemic and refinery downtime associated with Winter Storm Uri also caused an increase in gross deficit per bblUri.
Segment Contribution Margin (Deficit). Segment contribution margin improved dramatically in Q1 2021.
Refinery Downtime. Refinery downtime increased significantlydecreased to 6 days in Q1 2022 compared to 11 days in Q1 2021 compared to 3 days2021. Refinery downtime in Q1 2020. Refinery2022 primarily related to maintenance while refinery downtime in Q1 2021 primarily related to power outages during Winter Storm Uri.
|
| Three Months Ended |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
|
|
|
|
|
|
| ||
Refined product sales |
| $ | 109,757 |
|
| $ | 58,483 |
|
Less: Total cost of goods sold |
|
| (104,077 | ) |
|
| (59,623 | ) |
Gross margin (deficit) |
|
| 5,680 |
|
|
| (1,140 | ) |
|
|
|
|
|
|
|
|
|
Sales (Bbls) |
|
| 1,031 |
|
|
| 948 |
|
|
|
|
|
|
|
|
|
|
Gross margin (deficit) per bbl |
| $ | 5.51 |
|
| $ | (1.20 | ) |
|
| Three Months Ended |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 109,757 |
|
| $ | 58,483 |
|
Intercompany fees and sales |
|
| (653 | ) |
|
| (566 | ) |
Operation costs and expenses |
|
| (103,458 | ) |
|
| (59,289 | ) |
Segment contribution margin (deficit) |
| $ | 5,646 |
|
| $ | (1,372 | ) |
(1) | Net revenue excludes intercompany crude sales. |
Blue Dolphin Energy Company | March 31, 2022 │Page 40 |
| Table of Contents |
Management’s Discussion and Analysis |
Midstream Operations. Our tolling and terminaling business segment is owned by LRM and NPS. Assets within this segment include petroleum storage tanks and loading and unloading facilities. Tolling and terminaling revenue is derived from tank storage rental fees, tolling and reservation fees for use of the naphtha stabilizer, and fees collected for ancillary services, such as in-tank blending.
Three Months Ended | ||
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 |
Q1 20212022 Versus Q1 2020
Net Revenue. Tolling and terminaling net revenue decreased nearly 16%was relatively flat in Q1 20212022 compared to Q1 2020 primarily as a result of lower tank rental revenue.
Intercompany Fees and Sales. Intercompany fees and sales, which reflect processing fees associated with an intercompany tolling agreement tied to naphtha volumes, decreasedincreased in Q1 20212022 compared to Q1 2020.2021. Naphtha sales volumes decreasedprocessed nearly doubled between the periods.
Segment Contribution Margin. Segment contribution margin in Q1 20212022 decreased 20%17% to $1.0 million from $1.2 million compared to $1.5in Q1 2021. The $0.2 million Q1 2020. The decrease related to lower revenuehigher intercompany fees and intercompany feesoperation costs tied to naphtha volumes.
|
| Three Months Ended |
| |||||
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
|
| (in thousands) |
| |||||
Net revenue (1) |
| $ | 926 |
|
| $ | 930 |
|
Intercompany fees and sales |
|
| 653 |
|
|
| 566 |
|
Operation costs and expenses |
|
| (619 | ) |
|
| (334 | ) |
Segment contribution margin |
| $ | 960 |
|
| $ | 1,162 |
|
(1) | Net revenue excludes intercompany crude sales. |
Non-GAAP Reconciliations
.Reconciliation of Segment Contribution Margin (Deficit)
|
| Three Months Ended March 31, |
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| 2022 |
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| 2021 |
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| 2022 |
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| 2021 |
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| 2022 |
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| 2021 |
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| 2022 |
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| 2021 |
| ||||||||
|
| Refinery Operations |
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| Tolling and Terminaling |
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| Corporate and Other |
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| Total |
| ||||||||||||||||||||
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| (in thousands) |
| |||||||||||||||||||||||||||||
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|
|
|
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| ||||||||
Segment contribution margin (deficit) |
| $ | 5,646 |
|
| $ | (1,372 | ) |
| $ | 960 |
|
| $ | 1,162 |
|
| $ | (11 | ) |
| $ | (54 | ) |
| $ | 6,595 |
|
| $ | (264 | ) |
General and administrative expenses(1) |
|
| (282 | ) |
|
| (301 | ) |
|
| (70 | ) |
|
| (68 | ) |
|
| (431 | ) |
|
| (413 | ) |
|
| (783 | ) |
|
| (782 | ) |
Depreciation and amortization |
|
| (307 | ) |
|
| (302 | ) |
|
| (342 | ) |
|
| (340 | ) |
|
| (52 | ) |
|
| (51 | ) |
|
| (701 | ) |
|
| (693 | ) |
Interest and other non-operating income (expenses), net |
|
| (717 | ) |
|
| (598 | ) |
|
| (418 | ) |
|
| (452 | ) |
|
| (457 | ) |
|
| (385 | ) |
|
| (1,592 | ) |
|
| (1,435 | ) |
Income (loss) before income taxes |
|
| 4,340 |
|
|
| (2,573 | ) |
|
| 130 |
|
|
| 302 |
|
|
| (951 | ) |
|
| (903 | ) |
|
| 3,519 |
|
|
| (3,174 | ) |
Income tax expense |
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| (41) |
|
|
| - |
|
Net income (loss) |
| $ | 4,340 |
|
| $ | (2,573 | ) |
| $ | 130 |
|
| $ | 302 |
|
| $ | (951 | ) |
| $ | (903 | ) |
| $ | 3,478 |
|
| $ | (3,174 | ) |
(1) | General and administrative expenses within refinery operations include the LEH operating fee and accretion of |
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) |
Capital Resources and Liquidity
We had acurrently rely on revenue from operations, including sales of refined products and rental of petroleum storage tanks, Affiliates, and financing to meet our liquidity needs. Due to defaults under our secured loan agreements, substantial current debt, margin volatility, historic net losses and working capital deficit of $74.3 million and $72.3 million at March 31, 2021 and December 31, 2020, respectively. Excluding the current portion of long-term debt,deficits, we had ahave inadequate liquidity to sustain operations. Our short-term working capital deficit of $24.2 million and $22.6 million at March 31, 2021 and December 31, 2020, respectively. Although in place pre-pandemic, we have further tightened our cash conservation program to manage cash flow and remain competitive in a low oil price environment. This includes optimizing receivables and payables by prioritizing payments, managing inventory to avoid buildup, 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.
We continue to maintain our focus on safe and reliable operations and conserving cash. The Russian conflict with Ukraine and the COVID-19 pandemic continue to evolve, and the extent to which these events may impact our business, financial condition, liquidity, results of operations, and prospects will depend highly on future developments, which are very uncertain and cannot be predicted with confidence.
Management believes it has made significant progress on bolstering liquidity through efforts including securing additional financing, monitoring discretionary spending, and non-essential costs; and where possible, modifying vendor and contractor payment terms. During the three months ended March 31, 2022 and 2021, we have historically relied on Affiliatessuccessfully secured an additional $1.5 million and $0, respectively, in working capital through CARES Act loans. We continue to actively explore additional financing to meet our liquidity needs. We are actively exploring additional financing; however, we currently have no arrangements for additionalworking capital needs or refinance and no assurancesrestructure debt.
Blue Dolphin Energy Company | March 31, 2022 │Page 41 |
| Table of Contents |
Management’s Discussion and Analysis |
There can be givenno assurance that we will be able to raise sufficientadditional capital when needed, on acceptable terms, or at all. If we are unable to raise sufficient additional capital, we may not, in the very nearshort term, we may further default on our payment obligations under certain of our existing debt obligations. Without additional financing, it remains unclear whether we will have or can obtain sufficient liquiditybe able to withstand further disruptions to our business.
Working Capital
We had $72.9 million and $78.5 million in working capital deficits at March 31, 2022 and December 31, 2021, respectively. Excluding the current portion of long-term debt, we had $11.8 million and $15.5 million in working capital deficits at March 31, 2022 and December 31, 2021, respectively. Cash and cash equivalents totaled $0.1 million and $0.01 million at March 31, 2022 and December 31, 2021, respectively. Restricted cash (current portion) totaled $0 and $0.05 million at March 31, 2022 and December 31, 2021, respectively.
Sources and Use of Cash
Components of Cash Flows
|
| March 31, |
| |||||
|
| 2022 |
|
| 2021 |
| ||
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| (in thousands) |
| |||||
Cash Flows Provided By (Used In): |
|
|
|
|
|
| ||
Operating activities |
| $ | 937 |
|
| $ | (500 | ) |
Financing activities |
|
| (888 | ) |
|
| (42 | ) |
Increase (Decrease) in Cash and Cash Equivalents |
| $ | 49 |
|
| $ | (542 | ) |
Cash Flow Q1 2022 Compared to Q1 2021
We had a cash flow from operations of $0.9 million for Q1 2022 compared to a cash flow deficit of $0.5 million for Q1 2021. The significant increase in cash flow from operations in Q1 2022 was due to profit from operations. As a result, we may haveThe cash flow deficit for Q1 2021 primarily related to seek protection under bankruptcy laws. In such a case,loss from operations.
Capital Expenditures
During both Q1 2022 and Q1 2021, capital expenditures totaled $0. Due to continued uncertainties related to the trading price of our common stockCOVID-19 pandemic and the valueRussian conflict with Ukraine, we anticipate little, if any, new capital expenditures in 2022.However, to the extent we are able to capitalize on green energy growth opportunities, capital expenditures may be financed through project-based government loans.
We account for our capital expenditures in accordance with 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 an investment inmanagement judgment and discretion. 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.
Debt Overview.
The table below summarizes 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.
Total Debt and Lease Obligations
|
|
|
|
| Between |
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| Between |
|
|
|
|
|
|
| |||||
|
| Less than |
|
| 1 and 3 |
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| 3 and 5 |
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| 5 Years |
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| |||||
|
| 1 Year |
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| Years |
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| Years |
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| and Later |
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| Total |
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| (in thousands) |
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Long-term debt less unamortized debt issue costs(1)(2) |
|
|
|
|
|
|
|
|
|
|
|
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| |||||||
Third-party |
| $ | 43,004 |
|
| $ | 197 |
|
| $ | 142 |
|
| $ | 1,995 |
|
| $ | 45,338 |
|
Related-party |
|
| 18,087 |
|
|
| - |
|
|
| - |
|
|
| - |
|
|
| 18,087 |
|
Total long-term debt less debt issue costs |
|
| 61,091 |
|
|
| 197 |
|
|
| 142 |
|
|
| 1,995 |
|
|
| 63,425 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease obligations |
|
| 220 |
|
|
| 99 |
|
|
| - |
|
|
| - |
|
|
| 319 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| $ | 61,311 |
|
| $ | 296 |
|
| $ | 142 |
|
| $ | 1,995 |
|
| $ | 63,744 |
|
(1) | See “Item 1. Financial Statements – Notes (3) and (10)” for additional disclosures related to third-party and related-party debt. | |
(2) | Long-term debt excludes interest payable; at March 31, 2022, interest payable and interest payable, related party was estimated to be 12.1 million (less than 1 year), $0.1 million (between 1 and 3 years), $0.1 million (between 3 and 5 years), and $0.5 million (5 years and later). |
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Management’s Discussion and Analysis |
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 | |
Net cash used in financing activitiesproceeds from the issuance of debt totaled $0.9$1.5 million in Q1 20212022 compared to $0.7 million provided by financing activities$0 in Q1 2020.2021. Proceeds in Q1 2022 were from the BDEC Term Loan Due 2051. Principal payments on long-term debt totaled $0.9$0.004 million in Q1 20212022 compared to $0.7$0.006 million in Q1 2020. As of the filing date of this report, LE2021.Net activity on debt to related parties (non-cash payments) totaled $2.4 million and LRM were$0.04 million 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 under 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.Third-Party Defaults
· | Veritex Loans – For Q1 2022 and Q1 2021, principal and interest payments to Veritex totaled $0.8 million and $0, respectively. As of the filing date of this report, LE and LRM were in default under the LE Term Loan Due 2034 and LRM Term Loan Due 2034 for failing to make required monthly principal and interest payments and failing to satisfy financial covenants. In addition, LE was in default under the LE Term Loan Due 2034 for failing to replenish a $1.0 million payment reserve account. 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. |
· | GNCU Loan – For Q1 2022, interest only payments to GNCU totaled $0.3 million. As of the filing date of this report, NPS was in default under the NPS Term Loan Due 2031 for failing to satisfy financial covenants. |
· | 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. To date, Mr. Kissick has taken no action due to the non-payment. As of the filing date of this report, there were defaults under the Kissick Debt related to payment of past due obligations at maturity. |
We can provide no assurance that: (i) our assets or cash flow will be sufficient to fully repay borrowings under our secured loan agreements, either upon maturity or if accelerated, (ii) LE, LRM, and NPS will be able to refinance or restructure the debt, and/or (iii) third parties will provide future default waivers. Defaults under our secured loan agreements withand any exercise by third parties include: (1) Veritex financial covenant violations, failure to make monthly payments,of their rights and failure to replenish a payment reserve account; (2) Pilot event of default and debt acceleration; and (3) Notre Dame Debt event of default. We also have defaults under secured and unsecured related-party debt. See “Part I, Item 1. Financial Statements – Notes (1), (3), (10), and (11)” for additional disclosuresremedies related to Affiliatesuch defaults may have a material adverse effect on our business, the trading prices of our Common Stock, and third-party debt agreements, including debt guarantees, and defaultson the value of an investment in our debt obligations.
Related-Party Defaults
· | Notes and Loan Agreement – 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. |
Concentration of Customers Risk
. We routinely assess the financial strength of our customers and have not experienced significant write-downs in accounts receivable balances. We believe that our accounts receivable credit risk exposure is limited.Number Significant Customers | % Total Revenue from Operations | Portion of Accounts Receivable at March 31, | |
| March 31, 2021 | 4 | 90% | $0 |
| March 31, 2020 | 4 | 94% | $0.6 million |
Three Months Ended |
| Number Significant Customers |
|
| % Total Revenue from Operations |
|
| Portion of Accounts Receivable at March 31, |
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| |||
March 31, 2022 |
|
| 3 |
|
|
| 64.9 | % |
| $ | 0 |
|
March 31, 2021 |
|
| 4 |
|
|
| 90.4 | % |
| $ | 0 |
|
One of our significant customers is LEH, an Affiliate. TheDue 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 due to a HUBZone certification.terms. The Affiliate accounted for 27%31.2% and 29%27.1% of total revenue from operations infor the three months ended March 31, 2022 and 2021, and 2020, respectively. The Affiliate represented $0 in accounts receivable at both March 31, 20212022 and 2020, respectively. Amounts outstanding relating to the Jet Fuel Sales Agreement can significantly vary period to period based on the timing of the related sales and payments received. Amounts we owed to LEH under various long-term debt, related-party agreements totaled $16.6 million and $16.3 million at March 31, 2021, and December 31, 2020, respectively. See “Part I, Item“Item 1. Financial Statements – Notes (3) and (16)(15)” for additional disclosures related to Affiliate agreements and arrangements, andas well as “Part I, Item 1A. Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2021 as filed with the SEC for additional disclosures related to Affiliate risk.
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Management’s Discussion and Analysis |
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 |
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
To cover the various obligations of lessees and rights-of-way holders operating in federal waters of the Gulf of Mexico, BOEM evaluates an operator’s financial ability to carry out present and future obligations to determine whether the operator must provide additional security beyond the statutory bonding requirements. Such obligations include the cost of plugging and abandoning wells and decommissioning pipelines and platforms at the end of production or service activities. Once plugging and abandonment work has been completed, the collateral backing the financial assurance is released by BOEM.
BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days.rights-of-way. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Although the IBLA granted multiple extension requests, that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, theThe 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 eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs. Although we planned to decommission the offshore pipelines and platform assets during 2020, decommissioningDecommissioning of these assets has beenwas delayed due to our cash constraints associated with historical net losses and the ongoing impact of COVID-19 and winter being the offseason for dive operations in the U.S. Gulf of Mexico.COVID-19. We cannot currently estimate when decommissioning may occur. In the interim, BDPL provides BOEM and BSEE with updates regarding the project’s status.
BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we havedid not recordedrecord a liability on our consolidated balance sheetsheets as of March 31, 2022 and December 31, 2021. At both March 31, 20212022 and December 31, 2020,2021, BDPL maintained approximately $0.9 million in credit and cash-backedpipeline rights-of-way surety bonds issued to BOEM through RLI Corp. Of the pipeline rights-of-way bonds, issued to BOEM.
BSEE Offshore Pipelines and Platform Decommissioning
BDPL has pipelines and platform assets that are subject to BSEE’s idle iron regulations. Idle iron regulations mandate lessees and rights-of-way holders to permanently abandon and/or remove platforms and other structures when they are no longer useful for operations. Until such structures are abandoned or removed, lessees and rights-of-way holders are required to inspect and maintain the assets in accordance with regulatory requirements.
In December 2018, BSEE issued an INC to BDPL for failure to flush and fill Pipeline Segment No. 13101. Management met with BSEE onin August 15, 2019 to address BDPL’s plans with respect to decommissioning its offshore pipelines and platform assets. BSEE proposed that BDPL re-submit permit applications for pipeline and platform decommissioning along withpermit applications, including a safe boarding plan, for the platform, within six (6) months (no later thanby February 15, 2020), and develop and implement a safe boarding plan for submission with such permit applications. Further, BSEE proposed that2020. BDPL complete approved, permitted work within twelve (12) months (no later than August 15, 2020). BDPL timely submitted permit applications for decommissioning of the subject offshore pipelines and platform assets to BSEE onin February 11, 2020 and the USACOE onin March 25, 2020. 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 tocompleted the INC related to the structural platform surveys, and BSEE approved BDPL’s extension request. The required platform surveys were completed, and the INC was resolved in June 2020.
Lack of permit approvals does 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 platform assets and/or remedy the INCs within a timeframe determined to be 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, which 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 havedid not recordedrecord a liability related to potential penalties on our consolidated balance sheetsheets as of March 31, 2022 and December 31, 2021. At both March 31, 20212022 and December 31, 2020,2021, BDPL maintained $2.4$3.5 million in AROs related to abandonment of these assets.
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 |
Blue Dolphin Energy Company | March 31, |
| Table of Contents |
Management’s Discussion and Analysis |
Off-Balance Sheet Arrangements
. None.Accounting Standards
.Critical Accounting Policies and Estimates
Significant Accounting Policies. Our significant accounting policies relate to use of estimates, cash and recent accounting developments are described in “Part I, Item 1. Financial Statements – Note (2)”cash equivalents, restricted cash, accounts receivable and allowance for doubtful accounts, inventory, property and equipment, leases, revenue recognition, income taxes, impairment or disposal of long-lived assets, asset retirement obligations, and computation of earnings per share.
Estimates. 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 state 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 part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The uncertainty around the availability and prices of crude oil, the prices and demand for our refined products, and the general business environment is expected to continue through 2021 and beyond.
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 state 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 address surging coronavirus cases and roll out COVID-19 vaccines, we expect to continue operating.
In February 2022, Russia invaded neighboring Ukraine. The conflict caused turmoil in global markets, injecting even more uncertainty into a worldwide economy recovering from the effects of COVID-19. Given the evolving conflict, there are many unknown factors and events that could materially impact our operations.
We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The Russian conflict with Ukraine and the COVID-19 pandemic continue to evolve. Therefore, uncertainty surrounding refining margins, demand for our refined products, and the general business environment are expected to continue through 2022 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 the Russian conflict with Ukraine and COVID-19 as of March 31, 20212022 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts, inventory, and related reserves, and the carrying value of long-lived assets.
New Accounting Standards and Disclosures
New accounting standards and disclosuresPronouncements Adopted. The FASB issues ASUs to communicate changes to the FASB ASC, including modifications to non-authoritative SEC content. During the three months ended March 31, 2022, we did not adopt any ASUs.
New Pronouncements Issued, Not Yet Effective.
No new pronouncements issued but not yet effective are discussed in “Part I, Item 1. Financial Statements – Note (2)”.
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Controls and Procedures |
ITEM 3. QUANTITATIVE ANDAND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not applicable.
Evaluation of Disclosure Controls and Procedures
Under the supervision of, and with the participation of our management, including our Chief Executive Officer (principal executive officer and principal financial officer), we conducted an evaluation of the effectiveness of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”). As previously reported in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, basedBased on our evaluation, our Chief Executive Officer (principal executive officer principal financial officer, and principal accountingfinancial officer) concluded that our disclosure controls and procedures were ineffective due to certain material weaknesses and/or significant deficiencies as described below:
Changes in Internal Control over Financial Reporting
There havehas been no change in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the three months ended March 31, 20212022 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting. (See the above section “Evaluation
Remainder of Disclosure Controls and Procedures” for a discussion related to current ineffective disclosure controls and procedures.)
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ITEM 1. LEGAL PROCEEDINGS
In the ordinary course of business, we are involved in legal matters incidental to the routine operation of our business, such as mechanic’s liens and contract-related disputes. We may also become party to lawsuits, administrative proceedings, and governmental investigations, including environmental, regulatory, and other matters. Large, and sometimes unspecified, damages or penalties may be sought from us in some matters and certain matters may require years to resolve. Although we cannot provide assurance, we believe that an adverse resolution of the matters described below would not have a material impact on our liquidity, consolidated financial position, or consolidated results of operations.
Unresolved Matters.
BOEM Additional Financial Assurance (Supplemental Pipeline Bonds)
BDPL has historically maintained $0.9 million in financial assurance to BOEM for the decommissioning of its trunk pipeline offshore in federal waters. Following an agency restructuring of the financial assurance program, in March 2018 BOEM ordered BDPL to provide additional financial assurance totaling approximately $4.8 million for five (5) existing pipeline rights-of-way within sixty (60) calendar days.rights-of-way. In June 2018, BOEM issued BDPL INCs for each right-of-way that failed to comply. BDPL appealed the INCs to the IBLA, andIBLA. Although the IBLA granted multiple extension requests, that extended BDPL’s deadline for filing a statement of reasons for the appeal with the IBLA. On August 9, 2019, BDPL timely filed its statement of reasons for the appeal with the IBLA. Considering BDPL’s August 2019 meeting with BOEM and BSEE, BDPL requested a stay in the IBLA matter until August 2020. The Office of the Solicitor of the U.S. Department of the Interior was agreeable to a 10-day extension while it conferred with BOEM on BDPL’s stay request. In late October 2019, BDPL filed a motion to request the 10-day extension, which motion was subsequently granted by the IBLA. The solicitor’s office consented to an additional 14-day extension for BDPL to file its reply, and BDPL filed a motion to request the 14-day extension in November 2019. The solicitor’s office indicated that BOEM would not consent to further extensions. However, theThe solicitor’s office signaled that BDPL’s adherence to the milestones identified in thean August 15, 2019 meeting between management and BSEE may help in future discussions with BOEM related to the INCs. BDPL reasonably expects that successful completionDecommissioning of its decommissioning obligations (discussed within this “Note (16)” under ‘BSEE Offshore Pipelines and Platform Decommissioning’) prior to BSEE’s August 2020 deadlinethese assets will significantly reduce or eliminate the amount of financial assurance required by BOEM, which may serve to partially or fully resolve the INCs.
BDPL’s pending appeal of the BOEM INCs does not relieve BDPL of its obligations to provide additional financial assurance or of BOEM’s authority to impose financial penalties. There can be no assurance that we will be able to meet additional financial assurance (supplemental pipeline bond) requirements. If BDPL is required by BOEM to provide significant additional financial assurance (supplemental pipeline bonds) or is assessed significant penalties under the INCs, we will experience a significant and material adverse effect on our operations, liquidity, and financial condition.
We are currently unable to predict the outcome of the BOEM INCs. Accordingly, we havedid not recordedrecord a liability on our consolidated balance sheetsheets as of March 31, 2020. At March 31, 20202022 and December 31, 2019,2021. At both March 31, 2022 and December 31, 2021, BDPL maintained approximately $0.9 million in credit and cash-backedpipeline rights-of-way surety bonds issued to BOEM through RLI Corp. Of the pipeline rights-of-way bonds, issued$0.7 million was credit-backed and $0.2 million was cash-backed.
TCEQ Proposed Agreed Order. In October 2021, LRM received a proposed agreed order from the TCEQ for alleged solid and hazardous waste violations discovered during an investigation from January 29, 2020 to BOEM.
Pilot Dispute Related to Set-Off Payments. On October 4, 2021, NPS repaid all obligations owed to Pilot under the Amended Pilot Line of Credit. However, in lawsuits, claims, and proceedings incidentala letter from NPS to Pilot dated October 28, 2021, NPS disputed approximately $0.3 million in payments Pilot made to Tartan arising under a product sales agreement. NPS contends the disputed amount should have been applied to the conductbalance owed by NPS under the Amended Pilot Line of Credit. Pilot has asserted that the redirected payment was offset by accrued interest owed by NPS under the Amended Pilot Line of Credit. As of the filing date of this report, the amount remained in dispute between the parties.
Defaults under Secured Loan Agreements. We are currently in default under certain of our business, including mechanic’s liens, contract-related disputes, and administrative proceedings. Management is in discussionsecured loan agreements with all concernedthird parties and does not believe thatrelated parties. See “Notes (1), (3), and (10)” to our consolidated financial statements for additional disclosures related to third-party and related-party debt, defaults on such matters will have a material adverse effectdebt, and the potential effects of such defaults on our business, financial position, earnings, or cash flows. However, there can be no assurance that such discussions will result in a manageable outcome.condition, and results of operations. If Veritex and/or Pilotthird parties exercise their rights and remedies due to defaults under our secured loan agreements, our business, financial condition, and results of operations will be materially adversely affected.
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Risk Factors and Unregistered Sale of Equity Securities |
Counterparty Contract-Related Dispute. As of the filing date of this report, we were involved in a contract-related dispute with Tartan involving a revenue sharing-arrangement for the storage and sale of crude oil. Management is working to resolve the dispute amicably, however, the potential outcome is unknown. Management does not believe that the contract-related dispute will have a material adverse effect on our financial position, earnings, or cash flows. However, there can be no assurance that management’s efforts will result in a manageable outcome.
Resolved Matters.
None.
ITEM 1A. RISK FACTORS
In addition to the other information set forth in this Quarterly Report, careful consideration should be given to the risk factors discussed under “Part I, Item 1A. Risk Factors” and elsewhere in our Annual Report on Form 10-K for the fiscal year ended December 31, 20202021as filed with the SEC. These risks and uncertainties could materially and adversely affect our business, financial condition and results of operations. Our operations could also be affected by additional factors that are not presently known to us or by factors that we currently consider immaterial to our business. ThereExcept as described below, there have been no material changes in our assessment of our risk factors from those set forth in our Annual Report for the fiscal year ended December 31, 2020.
Our estimates of future AROs related to our pipeline and facilities assets may increase.
As of March 31, 2022, we maintained $3.5 million in AROs related to decommissioning our pipeline and facilities assets in the Gulf of Mexico. However, estimating these types of future removal and restoration costs is especially difficult because: (i) removal obligations will likely occur many years in the future, (ii) decommissioning activities for offshore operations are considerably more expensive than land-based operations due to increased regulatory scrutiny and logistical issues associated with working in waters of various depths, and (iii) liabilities could increase in the future for a variety of reasons outside our control including, but not limited to:
· | the limited availability of equipment and the experienced workforce necessary to accomplish this type of work; |
· |
· | changes in asset removal technologies that may result in additional or increased costs; |
· | potential damage or destruction to our pipeline and facilities assets as a result of hurricanes or other events; and |
· | the issuance of new or more stringent decommissioning requirements by regulatory agencies. |
Accordingly, the actual future value of the AROs associated with our pipeline and facilities assets may differ dramatically from our recorded estimate, which could have a material adverse effect on our business, financial condition, results of operations, and liquidity.
ITEM 2. UNREGISTERED SALES OF EQUITYEQUITY SECURITIES AND USE OF PROCEEDS
Sales of Unregistered Securities.
Set forth below is information regarding the sale or issuance of shares of Common Stock by us that were not registered under the Securities Act of 1933 and subsequent to the three months ended March 31, 2022:
On May 12, 2022, we issued an aggregate of 1,853,080 restricted shares of Common Stock to Jonathan Carroll, which represents payment of the common stock component under the LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement for monthly periods from April 30, 2020 through March 31, 2022. The average cost basis was $0.42, the low was $0.27, and the high was $0.64. Currently, management does not intend on paying Mr. Carroll the cash portion of guaranty fees due to Blue Dolphin’s working capital deficits. The cash portion will continue to accrue and be added to the principal balance of the March Carroll Note. See “Note (3)” to our consolidated financial statements for additional disclosures related to Affiliates and working capital deficits, as well as for information related to the LE Amended and Restated Guaranty Fee Agreement and LRM Amended and Restated Guaranty Fee Agreement.
On May 12, 2022, we also issued an aggregate of 252,447 restricted shares of Common Stock to certain of our non-employee, independent directors, which represents payment for services rendered to the Board for the three-month periods ended September 30, 2020, March 31, 2021, September 30, 2021, and March 31, 2022. The average cost basis was $0.55, the low was $0.33, and the high was $0.91.
The sale and issuance of the securities were exempt from registration under the Securities Act in reliance on Section 4(a)(2) of the Securities Act.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
See “Part I, Item. 1. Financial Statements – Notes (10)(3) and (11)(10)” for disclosures related to defaults on our debt.
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Exhibits |
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
None.
ITEM 6. EXHIBITS
Exhibits Index
No. | Description |
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) | |||||
May 16, 2022 | By: | ||||
/s/ JONATHAN P. CARROLL | |||||
Jonathan P. Carroll Chief Executive Officer, President, Assistant Treasurer and Secretary (Principal Executive Officer, Principal Financial Officer, and Principal Accounting Officer) | |||||
Blue Dolphin Energy Company | March 31, |