UNITED
STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
For
the quarterly period ended
or
For the transition period from _______________ to ________________
Commission
File No.
(Exact name of registrant as specified in its charter)
| (State
or other jurisdiction of incorporation or organization) |
(I.R.S. Employer Identification No.) | |
(Address of principal executive offices) |
(zip code) |
(
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act: None
| Title of each class | Trading Symbol | Name of each exchange on which registered |
| OTCPK |
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.
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).
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):
| Large accelerated filer ☐ | Accelerated filer ☐ | |
Smaller
reporting company |
Emerging
growth company |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate
by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐
The number of outstanding shares of the registrant’s common stock, $0.001 par value, on August 12, 2022, was .
FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q (“Report“) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical fact included in this communication, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this communication, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “forecast, “may,” “objective,” “plan,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events.
We caution you that these forward-looking statements are subject to numerous risks and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, anticipated impact of the COVID-19 outbreak, and other factors that may affect our future results and business, generally, including those discussed in the Company’s periodic reports that are filed with the SEC and available on the SEC’s website (http://www.sec.gov).
Should one or more of these risks occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, to reflect events or circumstances after the date of this communication.
2
PART I – FINANCIAL STATEMENTS (Unaudited)
June 30, 2022
CONTENTS
3
PART I – FINANCIAL STATEMENTS
Item 1. Financial Statements
GulfSlope Energy, Inc.
Condensed Balance Sheets
(Unaudited)
| June
30, 2022 |
September
30, 2021 |
|||||||
| Assets | ||||||||
| Current Assets | ||||||||
| Cash | $ | $ | ||||||
| Prepaid Expenses and Other Current Assets | ||||||||
| Total Current Assets | ||||||||
| Property and Equipment, net | ||||||||
| Oil and Natural Gas Properties, Full Cost Method of Accounting, Unproved Properties | ||||||||
| Total Non-Current Assets | ||||||||
| Total Assets | $ | $ | ||||||
| Liabilities and Stockholders’ Equity (Deficit) | ||||||||
| Current Liabilities | ||||||||
| Accounts Payable | $ | $ | ||||||
| Related Party Payable | ||||||||
| Related Party Accrued Interest Payable | ||||||||
| Loans from Related Parties | ||||||||
| Accrued Interest Payable | ||||||||
| Convertible Notes Payable, net of Debt Discount | ||||||||
| Derivative Financial Instruments | ||||||||
| Total Current Liabilities | ||||||||
| Total Liabilities | ||||||||
| Commitments and Contingencies | ||||||||
| Stockholders’ Equity (Deficit) | ||||||||
| Preferred Stock; par value ($); Authorized shares issued or outstanding | ||||||||
| Common Stock; par value ($); Authorized shares; issued and outstanding as of June 30, 2022 and September 30, 2021, respectively | ||||||||
| Additional Paid-in-Capital | ||||||||
| Accumulated Deficit | ( |
) | ( |
) | ||||
| Total Stockholders’ Equity (Deficit) | ( |
) | ||||||
| Total Liabilities and Stockholders’ Equity (Deficit) | $ | $ | ||||||
The accompanying notes are an integral part to these condensed financial statements.
4
GulfSlope Energy, Inc.
Condensed Statements of Operations
(Unaudited)
| For
the Three Months Ended June 30, |
For
the Nine Months Ended June 30, |
|||||||||||||||
| 2022 | 2021 | 2022 | 2021 | |||||||||||||
| Revenues | $ | $ | $ | $ | ||||||||||||
| Impairment of Oil and Natural Gas Properties | ||||||||||||||||
| General and Administrative Expenses | ||||||||||||||||
| Net Loss from Operations | ( |
( |
( |
( |
||||||||||||
| Other Income/(Expenses): | ||||||||||||||||
| Interest Expense | ( |
( |
( |
( |
||||||||||||
| Gain (Loss) on Debt Extinguishment | ( |
( |
||||||||||||||
| Gain (Loss) on Derivative Financial Instruments | ( |
|||||||||||||||
| Net Loss Before Income Taxes | ( |
( |
( |
( |
||||||||||||
| Provision for Income Taxes | ||||||||||||||||
| Net Loss | $ | ( |
$ | ( |
$ | ( |
$ | ( |
||||||||
| Loss Per Share - Basic and Diluted | $ | $ | $ | $ | ||||||||||||
| Weighted Average Shares Outstanding – Basic and Diluted | ||||||||||||||||
The accompanying notes are an integral part to these condensed financial statements.
5
GulfSlope Energy, Inc.
Condensed Statements of Stockholders’ Equity (Deficit)
(Unaudited)
For the Three Months Ended June 30, 2022
| Additional | Total | |||||||||||||||||||
| Common Stock | Paid-in | Accumulated | Stockholders’ | |||||||||||||||||
| Shares | Amount | Capital | Deficit | Deficit | ||||||||||||||||
| Balance at March 31, 2022 | $ | $ | $ | ( |
) | $ | ( |
) | ||||||||||||
| Extension of Warrants in Conjunction with Extension of Convertible Notes | — | |||||||||||||||||||
| Net Loss | — | ( |
) | ( |
) | |||||||||||||||
| Balance at June 30, 2022 | $ | $ | $ | ( |
) | $ | ( |
) | ||||||||||||
For the Three Months Ended June 30, 2021
| Common Stock | Additional Paid-in | Accumulated | Total Stockholders’ | |||||||||||||||||
| Shares | Amount | Capital | Deficit | Equity | ||||||||||||||||
| Balance at March 31, 2021 | $ | $ | $ | ( |
) | $ | ||||||||||||||
| Stock Based Compensation | — | |||||||||||||||||||
| Extension of Warrants in Conjunction with Extension of Convertible Notes | — | |||||||||||||||||||
| Net Loss | — | ( |
) | ( |
) | |||||||||||||||
| Balance at June 30, 2021 | $ | $ | $ | ( |
) | $ | ||||||||||||||
The accompanying notes are an integral part to these condensed financial statements.
6
GulfSlope Energy, Inc.
Condensed Statements of Stockholders’ Equity (Deficit)
(Unaudited)
For the Nine Months Ended June 30, 2022
| Common Stock | Additional Paid-In |
Accumulated | Total Shareholders’ Equity |
|||||||||||||||||
| Shares | Amount | Capital | Deficit | (Deficit) | ||||||||||||||||
| Balance at September 30, 2021 | $ | $ | $ | ( |
) | $ | ||||||||||||||
| Stock Based Compensation | — | |||||||||||||||||||
| Extension of Warrants in Conjunction with Extension of Convertible Notes | — | |||||||||||||||||||
| Net Loss | — | ( |
) | ( |
) | |||||||||||||||
| Balance at June 30, 2022 | $ | $ | $ | ( |
) | $ | ( |
|||||||||||||
For the Nine Months Ended June 30, 2021
| Common Stock | Additional | Additional Shares to Be | Accumulated | Total Shareholders’ Equity | ||||||||||||||||||
| Shares | Amount | Capital | Issued | Deficit | (Deficit) | |||||||||||||||||
| Balance at September 30, 2020 | $ | $ | $ | $ | ( | ) | $ | |||||||||||||||
| Common Stock Issued in Settlement of Debt Interest | ( | ) | ||||||||||||||||||||
| Stock Based Compensation | — | |||||||||||||||||||||
| Extension of Warrants in Conjunction with Extension of Convertible Notes | — | |||||||||||||||||||||
| Net Loss | — | ( | ) | ( | ) | |||||||||||||||||
| Balance at June 30, 2021 | $ | $ | $ | $ | ( | ) | $ | |||||||||||||||
The accompanying notes are an integral part to these condensed financial statements.
7
GulfSlope Energy, Inc.
Condensed Statements of Cash Flows
(Unaudited)
For the Nine Months Ended June 30 |
||||||||
| 2022 | 2021 | |||||||
| OPERATING ACTIVITIES | ||||||||
| Net Loss | $ | ( |
) | $ | ( |
) | ||
| Adjustments to Reconcile Net Loss to Net Cash Used In Operating Activities: | ||||||||
| Impairment of Oil and Natural Gas Properties | ||||||||
| Depreciation | ||||||||
| Stock Based Compensation | ||||||||
| Gain (Loss) on Derivative Financial Instruments | ( |
|||||||
| Debt Discount Amortization | ||||||||
| Loss (Gain) on Debt Extinguishment | ( |
) | ||||||
| Changes in Operating Assets and Liabilities: | ||||||||
| Accounts Receivable | ||||||||
| Prepaid Expenses and Other Current Assets | ( |
) | ( |
) | ||||
| Accounts Payable | ( |
) | ( |
) | ||||
| Accrued Interest Payable | ||||||||
| Operating Lease Liabilities | ||||||||
| Net Cash Used In Operating Activities | ( |
) | ( |
) | ||||
| INVESTING ACTIVITIES | ||||||||
| Insurance Proceeds Received | ||||||||
| Equipment Purchases | ( |
) | ||||||
| Proceeds from Sale of Pipe | ||||||||
| Investments in Oil and Gas Properties | ( |
) | ( |
) | ||||
| Net Cash Provided By (Used In) Investing Activities | ( |
) | ||||||
| FINANCING ACTIVITIES | ||||||||
| Payments on Notes Payable | ( |
) | ||||||
| Net Cash Used In Financing Activities | ( |
) | ||||||
| Net Decrease in Cash | ( |
) | ( |
) | ||||
| Beginning Cash Balance | ||||||||
| Ending Cash Balance | $ | $ | ||||||
| Supplemental Schedule of Cash Flow Activities: | ||||||||
| Cash Paid for Interest, Net of Amounts Capitalized | $ | $ | ||||||
| Non-Cash Financing and Investing Activities: | ||||||||
| Capital Expenditures in Accounts Payable | $ | $ | ||||||
| Warrants issued to Extend Maturity of Debt Instrument | $ | $ | ||||||
| Common Stock Issued upon Conversion of Convertible Notes Payable and Accrued Interest | $ | $ | ||||||
The accompanying notes are an integral part to these condensed financial statements.
8
GulfSlope Energy, Inc.
Notes to Condensed Financial Statements
June 30, 2022
(Unaudited)
NOTE 1 – ORGANIZATION AND NATURE OF BUSINESS
GulfSlope
Energy, Inc. (the “Company” or “GulfSlope”) is an independent oil and natural gas exploration company
whose interests are concentrated in the United States Gulf of Mexico federal waters offshore Louisiana. The Company currently
has under lease
NOTE 2 – SIGNIFICANT ACCOUNTING POLICIES
The condensed financial statements included herein are unaudited. However, these condensed financial statements include all adjustments (consisting of normal recurring adjustments), which, in the opinion of management are necessary for a fair presentation of financial position, results of operations and cash flows for the interim periods. The results of operations for interim periods are not necessarily indicative of the results to be expected for an entire year. The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make estimates and assumptions that affect the amounts reported in the Company’s condensed financial statements and accompanying notes. Actual results could differ materially from those estimates.
Certain information, accounting policies, and footnote disclosures normally included in the financial statements prepared in accordance with GAAP have been omitted pursuant to certain rules and regulations of the Securities and Exchange Commission (“SEC”). The condensed financial statements should be read in conjunction with the audited financial statements for the year ended September 30, 2021, which were included in the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2021 and filed with the Securities and Exchange Commission on December 29, 2021.
Cash
GulfSlope considers highly liquid investments with original maturities to the Company of three months or less to be cash equivalents. There were no cash equivalents at June 30, 2022 and September 30, 2021.
Liquidity / Going Concern
The
Company has incurred accumulated losses as of June 30, 2022 of $
Accounts Receivable
The
Company records an accounts receivable for operations expense reimbursements due from joint interest partners, and also from normal
operations. The Company estimates allowances for doubtful accounts based on the aged receivable balances and historical losses.
If the Company determines any account to be uncollectible based on significant delinquency or other factors, the receivable and
the underlying asset are assessed for recovery. As of June 30, 2022 and September 30, 2021, there was
9
Full Cost Method
The
Company uses the full cost method of accounting for its oil and gas exploration and development activities. Under the full cost
method of accounting, all costs associated with successful and unsuccessful exploration and development activities are capitalized
on a country-by-country basis into a single cost center (“full cost pool”). Such costs include property acquisition
costs, geological and geophysical (“G&G”) costs, carrying charges on non-producing properties, costs of drilling
both productive and non-productive wells. Overhead costs, which includes employee compensation and benefits including stock-based
compensation, incurred that are directly related to acquisition, exploration and development activities are capitalized. Interest
expense is capitalized related to unevaluated properties and wells in process during the period in which the Company is incurring
costs and expending resources to get the properties ready for their intended purpose. For significant investments in unproved
properties and major development projects that are not being currently depreciated, depleted, or amortized and on which exploration
or development activities are in progress, interest costs are capitalized. Proceeds from property sales will generally be credited
to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between
capitalized costs and the proved reserves attributable to these costs. A significant alteration would typically involve a sale
of
Proved properties are amortized on a country-by-country basis using the units of production method (“UOP”), whereby capitalized costs are amortized over total proved reserves. The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (“DD&A”), estimated future development costs (future costs to access and develop proved reserves), and asset retirement costs, less related salvage value.
The
costs of unproved properties and related capitalized costs (such as G&G costs) are withheld from the amortization calculation
until such time as they are either developed or abandoned. Unproved properties and properties under development are reviewed for
impairment at least quarterly and are determined through an evaluation that considers, among other factors, seismic data, requirements
to relinquish acreage, drilling results, remaining time in the commitment period, remaining capital plan, and political, economic,
and market conditions. In countries where proved reserves exist, exploratory drilling costs associated with dry holes are transferred
to proved properties immediately upon determination that a well is dry and amortized accordingly. In countries where a reserve
base has not yet been established, impairments are charged to earnings. For the three and nine months ended June 30, 2022, the
Company has taken an impairment of and approximately $
Companies
that use the full cost method of accounting for oil and natural gas exploration and development activities are required to perform
a ceiling test calculation each quarter. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule
4-10. The ceiling test is performed quarterly, on a country-by-country basis, utilizing the average of prices in effect on the
first day of the month for the preceding twelve-month period. The cost center ceiling is defined as the sum of (a) estimated future
net revenues, discounted at
The
Company capitalizes exploratory well costs into oil and gas properties until a determination is made that the well has either
found proved reserves or is impaired. If proved reserves are found, the capitalized exploratory well costs are reclassified to
proved properties. The well costs are charged to expense when the exploratory well costs are determined to be impaired. Capitalized
exploratory well costs have been pending the outcome of exploration activities involving the drilling of the Tau No. 2 well (twin
well). During the nine months ended June 30, 2022 approximately $
As of June 30, 2022, the Company’s oil and gas properties consisted of unproved properties and no proved reserves.
A combination of Biden administration actions regarding oil and gas exploration on federal lands and world events have placed tremendous pressures on the global supply-demand balance for crude oil and related products resulting in volatile commodity prices. The Company has evaluated the effect of these factors on its business and notes these factors have caused a delay in the plans for the Company’s 2022 drilling program. The Company continues to monitor the economic environment and evaluate the impact on the business.
Asset Retirement Obligations
The
Company’s asset retirement obligations will represent the present value of the estimated future costs associated with plugging
and abandoning oil and natural gas wells, removing production equipment and facilities and restoring the seabed in accordance
with the terms of oil and gas leases and applicable state and federal laws. Determining asset retirement obligations requires
estimates of the costs of plugging and abandoning oil and natural gas wells, removing production equipment and facilities and
restoring the sea bed as well as estimates of the economic lives of the oil and gas wells and future inflation rates. The resulting
estimate of future cash outflows will be discounted using a credit-adjusted risk-free interest rate that corresponds with the
timing of the cash outflows. Cost estimates will consider historical experience, third party estimates, the requirements of oil
and natural gas leases and applicable local, state and federal laws, but do not consider estimated salvage values. Asset retirement
obligations will be recognized when the wells drilled reach total depth or when the production equipment and facilities are installed
or acquired with an associated increase in proved oil and gas property costs. Asset retirement obligations will be accreted each
period through depreciation, depletion and amortization to their expected settlement values with any difference between the actual
cost of settling the asset retirement obligations and recorded amount being recognized as an adjustment to proved oil and gas
property costs. Cash paid to settle asset retirement obligations will be included in net cash provided by operating activities
from continuing operations in the statements of cash flows. On a quarterly basis, when indicators suggest there have been material
changes in the estimates underlying the obligation, the Company reassesses its asset retirement obligations to determine whether
any revisions to the obligations are necessary. At least annually, the Company will assess all of its asset retirement obligations
to determine whether any revisions to the obligations are necessary. Future revisions could occur due to changes in estimated
costs or well economic lives, or if federal or state regulators enact new requirements regarding plugging and abandoning oil and
natural gas wells. The Company drilled
10
Derivative Financial Instruments
The accounting treatment of derivative financial instruments requires that the Company record certain embedded conversion options and warrants as liabilities at their fair value as of the inception date of the agreement and at fair value as of each subsequent balance sheet date with any change in fair value recorded as income or expense. The Company estimates the fair value of these instruments primarily using Monte-Carlo valuation models. The significant assumptions used in estimating the fair value include the exercise price, volatility of the stock underlying the instrument, risk-free interest rate, estimated fair value of the stock underlying the instrument and the estimated life of the instrument.
Basic income (loss) per share (“EPS“) is computed by dividing net income (loss) (the numerator) by the weighted average number of common shares outstanding for the period (denominator). Diluted EPS is computed by dividing net income (loss) by the weighted average number of common shares and potential common shares outstanding (if dilutive) during each period. Potential common shares include stock options, warrants, and convertible notes payable. The number of potential common shares outstanding relating to stock options and warrants, is computed using the treasury stock method. The number of potential common shares related to convertible notes payable is determined using the if-converted method.
As the Company has incurred losses for the three and nine months ended June 30, 2022 and 2021, the potentially dilutive shares are anti-dilutive and are thus not added into the loss per share calculations. As of June 30, 2022 and 2021, there were and potentially dilutive shares, respectively.
Use of Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Recently Adopted Accounting Pronouncements
In May 2021, Financial Accounting Standards Board (“FASB”) issued ASU 2021-04, Earnings Per Share (Topic 260), Debt-Modifications and Extinguishments (Subtopic 470-50), Compensation-Stock Compensation (Topic 718), and Derivatives and Hedging-Contracts in Entity’s Own Equity (Subtopic 815-40): Issuer’s Accounting for Certain Modifications or Exchanges of Freestanding Equity-Classified Written Call Options. ASU 2021-04 provides clarification and reduces diversity in an issuer’s accounting for modifications or exchanges of freestanding equity-classified written call options (such as warrants) that remain equity classified after modification or exchange. An issuer measures the effect of a modification or exchange as the difference between the fair value of the modified or exchanged warrant and the fair value of that warrant immediately before modification or exchange. ASU 2021-04 introduces a recognition model that comprises four categories of transactions and the corresponding accounting treatment for each category (equity issuance, debt origination, debt modification, and modifications unrelated to equity issuance and debt origination or modification). ASU 2021-04 is effective for all entities for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years. An entity should apply the guidance provided in ASU 2021-04 prospectively to modifications or exchanges occurring on or after the effective date. Early adoption is permitted for all entities, including adoption in an interim period. If an entity elects to early adopt ASU 2021-04 in an interim period, the guidance should be applied as of the beginning of the fiscal year that includes that interim period. The Company has elected to early adopt this standard and in accordance with this standard was accounted for prospectively as of the beginning of the year. The early adoption of this standard impacted the accounting for the modification of investor warrants discussed in Note 6 and resulted in the recording of a loss on debt extinguishment of approximately $85,000. Historically the cost associated with the warrant modification was capitalized to deferred loan cost and amortized over the debt extension period.
11
Recent Accounting Pronouncements
In August 2020, the FASB issued ASU No. 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity (ASU 2020-06), which simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts in an entity’s own equity. Additionally, ASU 2020-06 requires the application of the if-converted method to calculate the impact of convertible instruments on diluted earnings per share (EPS), which is consistent with the Company’s accounting treatment under the current standard. ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted for fiscal years beginning after December 15, 2020. ASU No. 2020-06 can be adopted on either a fully retrospective or modified retrospective basis. The adoption of ASU 2020-06 is not expected to have a material impact on the Company’s financial statements or disclosures.
The Company has evaluated all other recent accounting pronouncements and believes either they are not applicable or that none of them will have a significant effect on the Company’s financial statements.
NOTE 3 – OIL AND NATURAL GAS PROPERTIES
The Company currently has under lease federal Outer Continental Shelf blocks and has licensed 2.2 million acres of three-dimensional (3-D) seismic data in its area of concentration. Our lease expires on October 31, 2025.
The
Company, as the operator of two wells drilled in the United States Gulf of Mexico, has incurred tangible and intangible drilling
costs for the wells in process and has billed its working interest partners for their respective share of the drilling costs to
date. The intangible drilling and all other costs related to the first well have been impaired. The second well, Tau, was drilled
to a measured depth of
As
of June 30, 2022, the Company’s oil and natural gas properties consisted of unproved properties, wells in process and no
proved reserves. During the nine months ended June 30, 2022 and 2021, an impairment charge of approximately $
NOTE 4 – RELATED PARTY TRANSACTIONS
During
April 2013 through September 2017, the Company entered into convertible promissory notes whereby it borrowed a total of approximately
$
On
November 15, 2016, a family member of the CEO entered into a $
Domenica
Seitz CPA, related to John Seitz, has provided accounting services to the Company through September 30, 2020 as a consultant and
beginning October 2020 as an employee. During the three months ended June 30, 2022 and 2021, the services provided were valued
at approximately $
NOTE 5 – NOTE PAYABLE
On
April 16, 2020, GulfSlope Energy, Inc. entered into a promissory note (the “Note”) evidencing an unsecured $
12
NOTE 6 – CONVERTIBLE NOTES PAYABLE
The Company’s convertible promissory notes consisted of the following as of September 30, 2021 and June 30, 2022.
| September 30, 2021 | June 30, 2022 | |||||||||||||||||||||||
| Notes | Discount | Notes,
Net of Discount |
Notes | Discount | Notes
Net of Discount |
|||||||||||||||||||
| Bridge Financing Notes | $ | $ | ( |
) | $ | $ | $ | — | $ | |||||||||||||||
| Total | $ | $ | ( |
) | $ | $ | $ | — | $ | |||||||||||||||
Bridge Financing Notes
Between
June and November 2016, the Company issued eleven convertible promissory notes (“Bridge Financing Notes”) with associated
warrants in a private placement to accredited investors for total gross proceeds of $
June 2019 Convertible Debenture
In
November 2020, the Company made a $
NOTE 7 – FAIR VALUE MEASUREMENT
Fair value is defined as the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories:
| Level 1: | Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. |
| Level 2: | Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that the Company values using observable market data. Substantially all of these inputs are observable in the marketplace throughout the term of the derivative instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange traded derivative financial instruments as well as warrants to purchase common stock and long-term incentive plan liabilities calculated using the Black-Scholes model to estimate the fair value as of the measurement date. |
| Level 3: | Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e. supported by little or no market activity). |
As required by ASC 820-10, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
13
Fair Value on a Recurring Basis
The following table sets forth by level within the fair value hierarchy the Company’s derivative financial instruments that were accounted for at fair value on a recurring basis as of September 30, 2021 and June 30, 2022, respectively:
| Description | Quoted Prices in Active
Markets Identical
Assets |
Significant Observable |
Significant Other Unobservable Inputs |
Total
Fair Value as of |
||||||||||||
| Derivative Financial Instrument at September 30, 2021 | $ | $ | ( |
) | $ | $ | ( |
) | ||||||||
| Derivative Financial Instrument at June 30 , 2022 | $ | $ | ( |
) | $ | $ | ( |
) | ||||||||
The change in derivative financial instruments for the nine months ended June 30, 2022 is as follows:
| September 30, 2021 balance | $ | ( |
) | |
| New derivative instruments issued | ||||
| Derivative instruments extinguished | ||||
| Change in fair value | ||||
| June 30, 2022 balance | $ | ( |
) |
Non-recurring
fair value assessments include impaired oil and natural gas property assessments and stock-based compensation. An impairment charge
of approximately $
NOTE 8 – COMMON STOCK/PAID IN CAPITAL
Nine Months Ended June 30, 2021
In
October 2020, the Company issued approximately common shares with a fair value of approximately $
Stock-based compensation cost is measured at the grant date, based on the estimated fair value of the award using the Black Scholes option pricing model, and is recognized over the vesting period. The Company recognized stock-based compensation of and approximately $ for the three months ended June 30, 2022 and 2021, respectively. Of the $ of stock compensation expense for the three months ended June 30, 2021 all was recorded as general and administrative expense. The Company recognized stock-based compensation of approximately $ and $ for the nine months ended June 30, 2022 and 2021, respectively. All of these amounts were recorded as general and administrative expense for each respective period.
| Number of Options | Weighted
Average Exercise Price |
Weighted
Average Remaining Contractual Term (In years) |
||||||||||
| Outstanding at September 30, 2021 | $ | |||||||||||
| Granted | ||||||||||||
| Exercised | — | — | ||||||||||
| Cancelled | — | — | ||||||||||
| Outstanding at June 30, 2022 | $ | |||||||||||
| Vested and expected to vest | $ | |||||||||||
| Exercisable at June 30, 2022 | $ | |||||||||||
As of June 30, 2022, there was no unrecognized stock-based compensation expense.
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NOTE 10 – COMMITMENTS AND CONTINGENCIES
From time to time, the Company may become involved in litigation relating to claims arising out of its operations in the normal course of business. No legal proceedings, government actions, administrative actions, investigations, or claims are currently pending against us or involve the Company.
In
July 2018, the Company entered into a month
lease for approximately
The
Company reached an agreement in August 2018 for the settlement of approximately $
NOTE 11 – SUBSEQUENT EVENTS
The Company completed a review and analysis of all events that occurred after the condensed balance sheet date to determine if any such events must be reported and has determined that there are no other subsequent events to be disclosed.
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Forward-looking Statements
The following discussion and analysis should be read in conjunction with our accompanying unaudited condensed consolidated financial statements and the notes to those financial statements included in Item 1 of this Quarterly Report on Form 10-Q. The following discussion contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (the “Exchange Act”). These forward-looking statements involve risks, uncertainties and assumptions. If the risks or uncertainties materialize or the assumptions prove incorrect, our results may differ materially from those expressed or implied by such forward-looking statements and assumptions. All statements other than statements of historical fact are statements that could be deemed forward-looking statements, such as those statements that address activities, events or developments that we expect, believe or anticipate will or may occur in the future. These statements are based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate in the circumstances. Known material risks that may affect our financial condition and results of operations are discussed in Item 1A, Risk Factors of our Annual Report on Form 10-K for the year ended September 30, 2021 and this Quarterly Report on Form 10-Q, Part II, Item 1A, Risk Factors, and may be discussed or updated from time to time in subsequent reports filed with the Securities and Exchange Commission. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We assume no obligation, nor do we intend to update these forward-looking statements. Unless the context requires otherwise, references in this Quarterly Report on Form 10-Q to “GulfSlope” “we,” “us,” “our” and the “Company” refer to GulfSlope Energy, Inc.
Overview
GulfSlope Energy, Inc. is an independent crude oil and natural gas exploration and production company whose interests are concentrated in the United States Gulf of Mexico federal waters. We are a technically driven company and we use our licensed 2.2 million acres of advanced three-dimensional (“3-D”) seismic data to identify, evaluate, and acquire assets with attractive economic profiles. GulfSlope Energy commenced commercial operations in March 2013. GulfSlope Energy was originally organized as a Utah corporation in 2004 and became a Delaware corporation in 2012. We have focused our operations in the US Gulf of Mexico because we believe this area provides us with favorable geologic and economic conditions, including multiple reservoir formations, comprehensive geologic databases, extensive infrastructure, relatively favorable royalty regime, and an attractive acquisition market and because our management and technical teams have significant experience and technical expertise in this geologic province. Additionally, we licensed 2.2 million acres of advanced 3-D seismic data, a significant portion of which has been enhanced by new, state-of-the-art reprocessing and noise attenuation techniques including reverse time migration depth imaging. We have used our broad regional seismic database and our reprocessing efforts to generate and high-grade oil and natural gas prospects. The use of our extensive seismic database, coupled with our ability, knowledge, and expertise to effectively reprocess this seismic data, allows us to further optimize our drilling operations and to effectively evaluate acquisition and joint venture opportunities. We consistently assess our prospect inventory in order to deploy capital as efficiently as possible. We have given preference to areas with water depths of 450 feet or less where production infrastructure already exists, which will allow for any discoveries to be developed rapidly and cost effectively with the goal to reduce economic risk while increasing returns
We have historically operated our business with working capital deficits and these deficits have been funded by equity and debt investments and loans from management. As of June 30, 2022, we had $0.245 million of cash on hand. The Company estimates that it will need to raise a minimum of $10.0 million to meet its obligations and planned expenditures through August 2023. The Company plans to finance operations and planned expenditures through equity and/or debt financings, farm-out agreements, and/or other transactions. There are no assurances that financing will be available with acceptable terms, if at all.
Competitive Advantages
Experienced management. Our management team has a track record of finding, developing and producing oil and natural gas in various hydrocarbon producing basins including the US Gulf of Mexico. Our team has significant experience in acquiring and operating oil and natural gas producing assets worldwide with particular emphasis on conventional reservoirs. We deployed a technical team with over 150 years of combined industry experience finding and developing oil and natural gas in the development and execution of our technical strategy. We believe the application of advanced geophysical techniques on a specific geographic area with unique geologic features such as conventional reservoirs whose trapping configurations have been obscured by overlying salt layers provides us with a competitive advantage.
Advanced seismic image processing. Commercial improvements in 3-D seismic data imaging and the development of advanced processing algorithms, including pre-stack depth, beam, and reverse time migration have allowed the industry to better distinguish hydrocarbon traps and identify previously unknown prospects. Specifically, advanced processing techniques improve the definition of the seismic data from a scale of time to a scale of depth, thus locating the images in three dimensions. The Company has invested significant technical person hours in the reprocessing and interpretation of seismic data. We believe the proprietary reprocessing and interpretation and the contiguous nature of our licensed 3-D seismic data gives us an advantage over other exploration and production companies operating in our core area.
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Industry leading position in our core area. We have licensed 2.2 million acres of 3-D seismic data which covers over 440 Outer Continental Shelf (“OCS”) Federal lease blocks on the highly prolific Louisiana outer shelf, offshore US Gulf of Mexico. We believe the proprietary and state-of-the-art reprocessing of our licensed 3-D seismic data, along with our proprietary and leading-edge geologic depositional and petroleum trapping models, gives us an advantage in identifying and high grading drilling and acquisition opportunities in our core area.
Technical Strategy
We believe that a major obstacle to identifying potential hydrocarbon accumulations globally has been the inability of seismic technology to accurately image deeper geologic formations because of overlying massive, extensive, and complex salt bodies. Large and thick laterally extensive subsurface salt layers highly distort the seismic ray paths traveling through them, which often has led to misinterpretation of the underlying geology and the potential major accumulations of oil and gas. We believe the opportunity exists for a technology-driven company to extensively apply advanced seismic acquisition and processing technologies, with the goal of achieving attractive commercial discovery rates for exploratory wells, and their subsequent appraisal and development, potentially having a very positive impact on returns on invested capital. These tools and techniques have been proven to be effective in deep water exploration and production worldwide, and we are using them to identify and drill targets below the salt bodies in an area of the shallower waters of the US Gulf of Mexico where industry activity has largely been absent for over 20 years. GulfSlope management led the early industry teams in their successful efforts to discover and develop five new fields below the extensive salt bodies in our core area during the 1990’s, which have produced over 125 million barrels of oil equivalent.
Our technical approach to exploration and development is to deploy a team of highly experienced geo-scientists who have current and extensive understanding of the geology and geophysics of the petroleum system within our core area, thereby decreasing the traditional timing and execution risks of advancing up a learning curve. For data licensing, re-processing and interpretation, our technical staff has prioritized specific geographic areas within our 2.2 million acres of seismic coverage, with the goal to optimize capital outlays.
Modern 3-D seismic datasets with acquisition parameters that are optimal for improved imaging at multiple depths are readily available in many of these sub-basins across our core area and can be licensed on commercially reasonable terms. The application of state-of-the-art seismic imaging technology is necessary to optimize delineation of prospective structures and to detect the presence of hydrocarbon-charged reservoirs below many complex salt bodies. An example of such a seismic technology is reverse time migration, which we believe to be the most accurate, fastest, and yet affordable, seismic imaging technology for critical depth imaging available today.
Lease Strategy
Our prospect identification and analytical strategy is based on a thorough understanding of the geologic trends within our core area. Exploration efforts have been focused in areas where lease acquisition opportunities are readily available. We entered into two master 3-D license agreements, together covering approximately 2.2 million acres and we have completed advanced processing on select areas within this licensed seismic area exceeding one million acres. We can expand this coverage and perform further advanced processing, both with currently licensed seismic data and seismic data to be acquired. We have sought to acquire and reprocess the highest resolution data available in the potential prospect’s direct vicinity. This includes advanced imaging information to further our understanding of a particular reservoir’s characteristics, including both trapping mechanics and fluid migration patterns. Reprocessing is accomplished through a series of model building steps that incorporate the geometry of the geology to optimize the final image. Our integration of existing geologic understanding and enhanced seismic processing and interpretation provides us with unique insights and perspectives on existing producing areas and especially underexplored formations below and adjacent to salt bodies that are highly prospective for hydrocarbon production.
We currently hold one lease, and we are evaluating the acquisition of additional leases in our core area. Our lease has a five-year primary term, expiring on October 31, 2025. The Bureau of Ocean Energy Management’s (“BOEM”) regulatory framework provides multiple options for leaseholders to apply to receive extensions of lease terms under specified conditions. GulfSlope is exploring all options contained in BOEM’s regulatory framework to extend the terms of the lease. Additional prospective acreage can be obtained through future lease sales, farm-in, or purchase. As is consistent with a prudent and successful exploration approach, we believe that additional seismic licensing, acquisition, processing, and/or interpretation may become highly advantageous, to more precisely define the most optimal drillable location(s), particularly for development of discoveries.
Acquisition Strategy
We are encouraged by a combination of macroeconomic factors that make the US Gulf of Mexico an attractive target for producing property acquisitions. Transaction activity has remained low despite the ongoing recovery of commodity prices for oil and gas. Current holders of production are dominated by the historically active major oil and gas companies and a smaller set of pure play companies. Compelling motivations exist for many of these companies to divest, as US Gulf of Mexico producing assets may no longer be core holdings, given the competition for capital within their portfolios. Multiple existing holders of production have stated their intention to exit the US Gulf of Mexico. GulfSlope is a proven qualified operator in the US Gulf of Mexico and the management team has broad and deep offshore experience.
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Accordingly, we continue to identify and evaluate potential producing property acquisitions in the offshore US Gulf of Mexico, taking advantage of our highly specialized subsurface and engineering capabilities, knowledge, and expertise. Any merger or acquisition is likely to be financed through the issuance of debt and/or equity securities.
Drilling and other Exploratory and Development Strategies
Our plan has been to partner with other entities which could include oil and gas companies and/or financial investors. Our goal is to diversify risk and minimize capital exposure to exploration drilling costs. We expect a portion of our exploration costs to be paid by our partners through these transactions, in return for our previous investment in prospect generation and delivery of an identified prospect on acreage we control. Such arrangements are a commonly accepted industry method of proportionately recouping pre-drill cost outlays for seismic, land, and associated interpretation expenses. We cannot assure you, however, that we will be able to enter into any such arrangements on satisfactory terms. In any drilling, we expect that our retained working interest will be adjusted based upon factors such as geologic risk and well cost. Early monetization of a discovered asset or a portion of a discovered asset is an option for the Company as a means to fund development of additional exploration projects as an alternative to potential equity or debt offerings. However, if a reasonable value were not received from the market at the discovery stage, then we may elect to retain (subject to lease terms) the discovery asset undeveloped, until a reasonable offer is received in line with our perceived market value, or we may elect to seek development partners on a promoted basis in order to substantially reduce capital development requirements.
Recent Developments
The turmoil of the past few years regarding the Covid 19 pandemic, the wild swings in commodity pricing and the actions taken by the Biden administration actively opposing oil and gas activities on Federal lands, have all combined to create great uncertainty and confusion regarding future industry activity in exploration for new reserves of oil and gas. At the present time, the Company has been unable to secure adequate terms for partnering in the redrill of the Tau well. The Company believes that the current shortages of oil and gas will force the re-evaluation of the industry pause in exploration activity, and accordingly has shifted its focus to the re-drill of the Tau Prospect from the second lease on which more time exits to conduct this activity. This lease expires in 2025.
The Company has been and continues to be active in the evaluation of potential mergers and producing property acquisitions that it deems attractive opportunities. Any such merger or acquisition is likely to be financed through a combination of debt and equity. As a qualified operator in the U S Gulf of Mexico, the Company has the ability to acquire operated production.
The Company is in the process of raising capital to cover general and administrative expenses for the next 15 months.
Significant Accounting Policies
The Company uses the full cost method of accounting for its oil and gas exploration and development activities. Under the full cost method of accounting, all costs associated with successful and unsuccessful exploration and development activities are capitalized on a country-by-country basis into a single cost center (“full cost pool“). Such costs include property acquisition costs, geological and geophysical (“G&G”) costs, carrying charges on non-producing properties, costs of drilling both productive and non-productive wells. Overhead costs, which includes employee compensation and benefits including stock-based compensation, incurred that are directly related to acquisition, exploration and development activities are capitalized. Interest expense is capitalized related to unevaluated properties and wells in process during the period in which the Company is incurring costs and expending resources to get the properties ready for their intended purpose. For significant investments in unproved properties and major development projects that are not being currently depreciated, depleted, or amortized and on which exploration or development activities are in progress, interest costs are capitalized. Proceeds from property sales will generally be credited to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to these costs. A significant alteration would typically involve a sale of 25% or more of the proved reserves related to a single full cost pool.
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Proved properties are amortized on a country-by-country basis using the units of production method (“UOP”), whereby capitalized costs are amortized over total proved reserves. The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (“DD&A”), estimated future development costs (future costs to access and develop proved reserves), and asset retirement costs, less related salvage value.
The costs of unproved properties and related capitalized costs (such as G&G costs) are withheld from the amortization calculation until such time as they are either developed or abandoned. Unproved properties and properties under development are reviewed for impairment at least quarterly and are determined through an evaluation considering, among other factors, seismic data, requirements to relinquish acreage, drilling results, remaining time in the commitment period, remaining capital plan, and political, economic, and market conditions. In countries where proved reserves exist, exploratory drilling costs associated with dry holes are transferred to proved properties immediately upon determination that a well is dry and amortized accordingly. In countries where a reserve base has not yet been established, impairments are charged to earnings.
Companies that use the full cost method of accounting for oil and natural gas exploration and development activities are required to perform a ceiling test calculation each quarter. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test is performed quarterly, on a country-by-country basis, utilizing the average of prices in effect on the first day of the month for the preceding twelve-month period. The cost center ceiling is defined as the sum of (a) estimated future net revenues, discounted at 10% per annum, from proved reserves, (b) the cost of properties not being amortized, if any, and (c) the lower of cost or market value of unproved properties included in the cost being amortized. If such capitalized costs exceed the ceiling, the Company will record a write-down to the extent of such excess as a non-cash charge to earnings. Any such write-down will reduce earnings in the period of occurrence and results in a lower depreciation, depletion and amortization rate in future periods. A write-down may not be reversed in future periods even though higher oil and natural gas prices may subsequently increase the ceiling.
The Company capitalizes exploratory well costs into oil and gas properties until a determination is made that the well has either found proved reserves or is impaired. If proved reserves are found, the capitalized exploratory well costs are reclassified to proved properties. The well costs are charged to expense when the exploratory well costs are determined to be impaired. Capitalized exploratory well costs have been pending the outcome of exploration activities involving the drilling of the Tau No. 2 well (twin well). During the quarter ended March 31, 2022 approximately $3.1 million of these suspended well costs have been impaired. The impairment charge was recorded because without the commencement of drilling the Tau #2 well or a lease extension being granted, one of the Tau Prospect lease blocks expired on June 30, 2022. Since the Tau prospect extends over two lease blocks, costs associated with the remaining Tau lease block remain capitalized.
As of June 30, 2022, the Company’s oil and gas properties consisted of unproved properties and no proved reserves.
Property and equipment are carried at cost. We assess the carrying value of our property and equipment for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.
There has been no change to our critical accounting policies as included in our annual report on Form 10-K as of September 30, 2021, which was filed with the Securities and Exchange Commission on December 29, 2021.
Three Months Ended June 30, 2022, Compared to Three Months Ended June 30, 2021
There was no revenue during the three months ended June 30, 2022 and 2021. We incurred no impairment of oil and natural gas properties for the three months ended June 30, 2022 and 2021. General and administrative expenses were approximately $0.4 million for the three months ended June 30, 2022, and 2021. Net interest expense was approximately $0.1 for the three months ended June 30, 2022 and 2021. Loss on debt extinguishment was approximately $0.1 million for the three months ended June 30, 2022 and nil for the three month ended June 30, 2021, respectively. Gain on derivative financial instruments was approximately $0.3 million for the three months ended June 30, 2022 and approximately $0.1 million for the three months ended June 30, 2021.
Nine Months Ended June 30, 2022, Compared to Nine Months Ended June 30, 2021
There was no revenue during the nine months ended June 30, 2022 and June 30, 2021. We incurred approximately $3.1 million of impairment of oil and natural gas properties for the nine months ended June 30, 2022 and nil for the nine months ended June 30, 2021. This is due to the expiration of our oil and gas lease and the write off of a portion of the capitalized costs of our Tau prospect during the quarter ended March 31, 2022. General and administrative expenses were approximately $1.2 million for the nine months ended June 30, 2022, compared to approximately $1.1 million for the nine months ended June 30, 2021. Interest expense was approximately $0.4 million for the nine months ended June 30, 2022 and June 30, 2021. No interest was capitalized for the quarter ended June 30, 2022 or 2021, respectively. Loss on debt extinguishment was approximately $0.1 million for the nine months ended June 30, 2022 and a gain on debt extinguishment of approximately $0.1 million for the nine months ended June 30, 2021. Gain on derivative financial instrument was approximately $0.1 million for the nine months ended June 30, 2022 compared to a loss of approximately $0.3 million for the nine months ended June 30, 2021.
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Liquidity and Capital Resources
The Company has incurred accumulated losses for the period from inception to June 30, 2022, of approximately $64.8 million, and has a negative working capital of $13.5 million. For the nine months ended June 30, 2021, the Company has generated losses of approximately $4.6 million and net cash used in operations of approximately $1.2 million. As of June 30, 2022, there was $0.245 million of cash on hand. The Company estimates that it will need to raise a minimum of $10 million to meet its obligations and planned expenditures through August 2023. The $10 million is comprised primarily of capital project expenditures as well as general and administrative expenses. It does not include any amounts due under outstanding debt obligations and accrued interest, which amounted to approximately $12.4 million as of June 30, 2022. The Company plans to finance operations and planned expenditures through the issuance of equity securities, debt financings, farm-out agreements, mergers or other transactions. Our policy has been to periodically raise funds through the sale of equity on a limited basis, to avoid undue dilution while at the early stages of execution of our business plan. Short term needs have been historically funded through loans from executive management. There are no assurances that financing will be available with acceptable terms, if at all. If the Company is not successful in obtaining financing, operations would need to be curtailed or ceased. The accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.
For the nine months ended June 30, 2022 and 2021, the Company used approximately $1.2 million of net cash in operating activities. For the nine months ended June 30, 2022, approximately $0.03 million of cash was used in investing activities compared with approximately $0.2 million of cash provided by investing activities for the nine months ended June 30, 2021. For the nine months ended June 30, 2022, the Company used nil in financing activities compared with approximately $0.3 million of cash used in financing activities in payment of notes payable for the nine months ended June 30, 2021.
The Company will need to raise additional funds to cover planned expenditures, as well as any additional, unexpected expenditures that we may encounter. Future equity financings may be dilutive to our stockholders. Alternative forms of future financings may include preferences or rights superior to our common stock. Debt financings may involve a pledge of assets and will rank senior to our common stock. We have historically financed our operations through private equity and debt financings. We do not have any credit or equity facilities available with financial institutions, stockholders or third-party investors, and will continue to rely on best efforts financings. The failure to raise sufficient capital could cause us to cease operations, or the Company would need to sell assets or consider alternative plans up to and including restructuring.
Off-Balance Sheet Arrangements
None.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
Not required for smaller reporting companies.
Item 4. Controls and Procedures.
Evaluation of Disclosure Controls and Procedures
Disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) are designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in rules and forms adopted by the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the principal executive and principal financial officers, to allow timely decisions regarding required disclosures.
Under the supervision and with the participation of our principal executive and principal financial officers, our management evaluated the effectiveness of the design and operation of our disclosure controls and procedures. Based upon that evaluation, our principal executive and principal financial officers concluded that, as of the end of the period covered by this Quarterly Report on Form 10-Q, our disclosure controls and procedures were effective at a reasonable assurance level to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms.
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As noted in the Company’s Annual Report on Form 10-K for the year ended September 30, 2021, the design and operating effectiveness of our controls were adequate to ensure that certain account analysis and accounting judgments related to certain estimates throughout the year were properly accounted for and reviewed in a timely manner.
Limitations on the Effectiveness of Controls
The Company’s management is responsible for establishing and maintaining adequate internal control over financial reporting. The Company’s internal control over financial reporting is designed to provide reasonable assurance as to the reliability of the Company’s financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
Changes in Internal Control Over Financial Reporting
During the fiscal quarter covered by this Report, there has been no change in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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PART II – OTHER INFORMATION
Item 1. Legal Proceedings
From time to time, the Company may become involved in litigation relating to claims arising out of its operations in the normal course of business. No legal proceedings, government actions, administrative actions, investigations or claims are currently pending against us or involve the Company.
Item 1A. Risk Factors
In addition to the other information set forth in this Quarterly Report, you should carefully consider the risk factors and other cautionary statements described under the heading Part I, Item 1A. “Risk Factors” included in our September 30, 2021 Annual Report, and the risk factors and other cautionary statements contained in our other SEC filings, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results. The risks and uncertainties described below should be read together with those disclosed in our 2021 Form 10-K, Annual Report filed with the SEC on December 29, 2021 and our other SEC filings.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
None.
Item 3. Defaults Upon Senior Securities
None.
Item 4. Mine Safety Disclosures
Not applicable.
Item 5. Other Information
None.
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Item 6. Exhibits
The following exhibits are attached hereto or are incorporated by reference:
| (1) | Filed herewith. |
| (2) | Furnished herewith. |
| (3) | Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections. |
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Issuer has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.
GULFSLOPE ENERGY, INC.
(Issuer)
| Date: | 08/15/2022 | By: | /s/ John N. Seitz |
| John N. Seitz, Chief Executive Officer, and Chairman |
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Issuer has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.
GULFSLOPE ENERGY, INC.
(Issuer)
| Date: | 08/15/2022 | By: | /s/ John H. Malanga |
| John H. Malanga, Chief Financial Officer, | |||
| and Chief Accounting Officer |
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