In Julyaddition to the fixed exercise price noted above, the model incorporates the variable conversion price which is simulated as 80% of the lowest trading price within the ten consecutive days preceding presumed conversion.

The Company’s term loan and August 2017, the three remainingconvertible promissory notes issued in July, August and November 2016 were extended until January 15, 2018 and issued 3,750,000 extension warrants (equal to 25%consisted of the original warrant amount)following as of June 30, 2019.

NOTE 6 – 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:

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 evaluated this transaction including consideringCompany’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 the warrants issuedassets and concluded that modification accounting was required as the present value of future cash flows from the new note, includingliabilities and their placement within the fair value of the warrants issued to extend, are less than 10% of the present value of future cash flows of the old note. When an instrument is modified, any incremental increase in value (in this case the warrants) should be added to the discount of the notes and such discount should be amortized to interest expense using the effective interest rate method over the new remaining life of the note. The fair value of the warrants, $38,946, was determined using the Black-Scholes option pricing model.hierarchy levels.

☐Fair Value on a Recurring Basis

On December 28, 2016, the Company issued a convertible promissory note with 500,000 shares of restricted stock and 550,000 warrants in a private placement to an accredited investor for $50,000 in proceeds. The warrants have a five year term and an exercise price of $0.10. The promissory note has a face value of $55,555, which includes 10% original issue discount (“OID”) and incurs a one-time upfront interest charge of six percent. The holder of the note has the option to convert the note into shares of common stock at a conversion price of $0.02 per share. Approximately $450,000 of additional funding is available under similar terms if the Company and the lender mutually agree to further tranches. The Company evaluated the various financial instruments under ASC 480 and ASC 815 and determined no material instruments or features required fair value accounting. Therefore, in accordance with ASC 470-20-25-2, the Company allocated the proceeds between the convertible note, restricted common stock, and warrants based on their relative fair values. This resulted in an allocation of $8,460 to the restricted stock, $7,969 to the warrants and $33,571 to the convertible note. After such allocation, the Company evaluated the conversion option to discern whether a beneficial conversion feature existed based upon comparing the effective exercise price of the convertible note tofollowing 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 June 30, 2019:

Non-recurring fair value assessments include impaired oil and natural gas property assessments and stock based compensation. During the shares it is convertible into. Thenine months ended June 30, 2019, the Company concluded a beneficial conversion feature existedrecorded an impairment of $4.2 million to its oil and measured such beneficial conversion feature at $33,571. Accordingly, at December 28, 2016, the debt discount associated with these notes was $55,555. Such discount was amortized using the effective interest rate method over the term (seven months) of the convertible note. For the year ended September 30, 2017 amortization of this discount totaled $55,555 and is included in interest expense in the statement of operations. Accrued interest expensenatural gas properties for the year ended September 30, 2017 is $3,333. The note, related OIDexpiration of oil and accrued interest were converted into approximately 5.5 million shares of GulfSlope Energy common stock in a series of conversions beginning on July 10, 2017 and ending with a conversion on September 18, 2017 on which date all were paid in full.natural gas leases whose value was determined to be zero.

On March 14, 2017, the Company issued a convertible promissory note with 1,000,000 shares of restricted stock and 1,100,000 warrants in a private placement to an accredited investor for $100,000 in proceeds. The warrants have a five-year term and an exercise price of $0.10. The promissory note has a face value of $111,111, which includes 10% original issue discount (“OID”), and incurs a one-time upfront interest charge of six percent. The holder of the note has the option to convert the note into shares of common stock at a conversion price of $0.02 per share. Approximately $350,000 of additional funding is available under similar terms if the Company and the lender mutually agree to further tranches. The Company evaluated the various financial instruments under ASC 480 and ASC 815 and determined no material instruments or features required fair value accounting. Therefore, in accordance with ASC 470-20-25-2, the Company allocated the proceeds between the convertible note, restricted common stock, and warrants based on their relative fair values. This resulted in an allocation of $17,250 to the restricted stock, $14,051 to the warrants and $68,699 to the convertible note. After such allocation, the Company evaluated the conversion option to discern whether a beneficial conversion feature existed based upon comparing the effective exercise price of the convertible note to the fair value of the shares it is convertible into. The Company concluded a beneficial conversion feature existed and measured such beneficial conversion feature at $68,699. Accordingly, at March 14, 2017, the debt discount associated with these notes was $111,111. Such discount will be amortized using the effective interest rate method over the term (seven months) of the convertible note. For the year ended September 30, 2017 amortization of this discount totaled $105,841 and is included in interest expense in the statement of operations. Accrued interest expense for the year ended September 30, 2017 is $6,666. In September 2017, $30,000 was converted into 1.5 million shares of stock, leaving a note balance of $81,111 at September 30, 2017. In October 2017, the note balance of $81,111 and accrued interest of $6,600 were converted into approximately 4.3 million shares of GulfSlope Energy common stock. During the quarter ended December 31, 2017 the note and all accrued interest were paid in full.

On October 16, 2017, the Company issued a convertible promissory note with 1,000,000 shares of restricted stock and 1,100,000 warrants in a private placement to an accredited investor for $100,000 in proceeds. The warrants have a five-year term and an exercise price of $0.10. The promissory note has a face value of $110,000, which includes 10% original issue discount (“OID”), and incurs a one-time upfront interest charge of six percent. The holder of the note has the option to convert the note into shares of common stock at a conversion price of $0.02 per share. Approximately $250,000 of additional funding is available under similar terms if the Company and the lender mutually agree to further tranches. The Company evaluated the various financial instruments under ASC 480 and ASC 815 and determined no material instruments or features required fair value accounting. Therefore, in accordance with ASC 470-20-25-2, the Company allocated the proceeds between the convertible note, restricted common stock, and warrants based on their relative fair values. This resulted in an allocation of $21,287 to the restricted stock, $20,175 to the warrants and $58,538 to the convertible note. After such allocation, the Company evaluated the conversion option to discern whether a beneficial conversion feature existed based upon comparing the effective exercise price of the convertible note to the fair value of the shares it is convertible into. The Company concluded a beneficial conversion feature existed and measured such beneficial conversion feature at $58,538. Accordingly, at October 16, 2017, the debt discount associated with these notes was $110,000. Such discount will be amortized using the effective interest rate method over the term (seven months) of the convertible note. For the quarter ended December 31, 2017 amortization of this discount totaled $39,434 and is included in interest expense in the statement of operations. Accrued interest expense for the quarter ended December 31, 2017 is $6,600.

On December 15, 2017, the Company issued a convertible promissory note with 1,000,000 shares of restricted stock and 1,100,000 warrants in a private placement to an accredited investor for $100,000 in proceeds. The warrants have a five-year term and an exercise price of $0.10. The promissory note has a face value of $110,000, which includes 10% original issue discount (“OID”), and incurs a one-time upfront interest charge of six percent. The holder of the note has the option to convert the note into shares of common stock at a conversion price of $0.02 per share. Approximately $150,000 of additional funding is available under similar terms if the Company and the lender mutually agree to further tranches. The Company evaluated the various financial instruments under ASC 480 and ASC 815 and determined no material instruments or features required fair value accounting. Therefore, in accordance with ASC 470-20-25-2, the Company allocated the proceeds between the convertible note, restricted common stock, and warrants based on their relative fair values. This resulted in an allocation of $27,807 to the restricted stock, $27,212 to the warrants and $44,981 to the convertible note. After such allocation, the Company evaluated the conversion option to discern whether a beneficial conversion feature existed based upon comparing the effective exercise price of the convertible note to the fair value of the shares it is convertible into. The Company concluded a beneficial conversion feature existed and measured such beneficial conversion feature at $44,981. Accordingly, at December 15, 2017, the debt discount associated with these notes was $110,000. Such discount will be amortized using the effective interest rate method over the term (seven months) of the convertible note. For the quarter ended December 31, 2017 amortization of this discount totaled $8,302 and is included in interest expense in the statement of operations. Accrued interest expense for the quarter ended December 31, 2017 is $6,600.

NOTE 67 – COMMON STOCK/PAID IN CAPITAL

As discussed in Note 5, between June and November 2016, the Company issued 27.9 million warrants in conjunction with convertible notes payable.the Bridge Financing Notes. The warrants have an exercise price of $0.03 and a term of the earlier of 3three years or upon a change of control. Based upon the allocation of proceeds between the convertible notes payable and the warrants, approximately $452,422 was allocated to the warrants. During June through August 2017, the maturity date of all of the Bridge Financing Notes was extended to January 15, 2018, in exchange for the issuance of 25% additional warrants. The warrants have an exercise price of $0.03 and the same expiration date (three years from original transaction) as the original warrants.

On January 15, 2018, the maturity date of the Bridge Financing Notes was extended to April 16, 2018, in exchange for the issuance of 10% additional warrants (see Note 5 for status of notes). The warrants have an exercise price of $0.10 per share and the same expiration date (three years from original transaction) as the original warrants. Through June 30, 2019, approximately 3.3 million warrants have been exercised, approximately 4.0 million have expired and approximately 30.5 million remain outstanding.

The fair value of the warrants werewas determined using the Black Scholes valuation model with the following key assumptions:

(1) Fair market value on the date of agreement agreement.

(2) Average term.

Below is a summary of warrants issued in conjunction with convertible notes which were paid in full as of September 30, 2018. The warrants are outstanding at June 30, 2019.

During the period December 2016 through December 2017nine months ended June 30, 2019, the Company issued 3,500,000approximately 19.3 million shares of restrictedcommon stock and approximately 9.7 million warrants to Lucas Hoppelaccredited investors in a private placement. The funds were received in the prior fiscal year and included as part of financing transactions (see Note 5).

As discussed in Note 5, ina liability because the transaction did not close until the current fiscal year and it was moved to equity during  the quarter ended December 2016, the Company issued 550,000 warrants in conjunction with a convertible note payable. The warrants have an exercise price of $0.10 and a term of the earlier of 5 years or upon a change of control.31, 2018. Based upon the allocation of proceeds between the convertible note payablecommon stock and the warrants, approximately $13,188 was allocated to the warrants. In March 2017, the Company issued 1,100,000 warrants in conjunction with a convertible note payable. The warrants have an exercise price of $0.10 and a term of the earlier of 5 years or upon a change of control. Based upon the allocation of proceeds between the convertible note payable and the warrants, approximately $14,051 was allocated to the warrants. In October 2017, the Company issued 1,100,000 warrants in conjunction with a convertible note payable. The warrants have an exercise price of $0.10 and a term of the earlier of 5 years or upon a change of control. Based upon the allocation of proceeds between the convertible note payable and the warrants, approximately $20,175 was allocated to the warrants. In December 2017, the Company issued 1,100,000 warrants in conjunction with a convertible note payable. The warrants have an exercise price of $0.10 and a term of the earlier of 5 years or upon a change of control. Based upon the allocation of proceeds between the convertible note payable and the warrants, approximately $27,212$259,000 was allocated to the warrants.

The fair value of the warrants werewas determined using the Black Scholes valuation model with the following key assumptions:

As discussed in Note 5, as of March 6, 2019, the Company had borrowed a total of $10.0 million under the Term Loan Facility and issued to Delek GOM warrants to purchase approximately 238 million shares of common Stock and Delek GOM fully exercised the warrants through a Loan Reduction Exercise and was issued approximately 238 million shares of common stock. Upon receiving the proceeds, the Company allocated the proceeds between debt and warrants on a relative fair value basis, recording a debt discount of approximately $5.1 million. The exercise of the warrants through the extinguishment of the loan was accounted for as a standard warrant exercise and an extinguishment of debt including a recognition of a loss in the amount of the debt discount of approximately $5.1 million. On April 19, 2019, the Company borrowed $1.0 million under the Term Loan Facility and issued to Delek warrants to purchase 23,809,524 shares of stock. the Company allocated the proceeds between debt and warrants on a relative fair value basis, recording a debt discount of approximately $0.5 million. As of June 30, 2019, the warrants have not been exercised and the term loan is still outstanding.

As disclosed in Note 5, the Company issued warrants to purchase an aggregate of 50 million shares of common stock at an exercise price of $0.04 per share in conjunction with the issuance of the Convertible Debentures. Such warrants expire on the fifth anniversary of issuance. The fair value of the warrants was determined utilizing a Geometric Brownian Motion Stock Path Based Monte Carlo Simulation.

NOTE 8 – STOCK-BASED COMPENSATION

On January 1, 2017, 33.5 million stock options, with an exercise price of $0.0278 per share, were granted to 6 employees and 2 directors of the Company. The CEO was not included in the award. The stock options vested 50% on January 1, 2017, and 50% on January 1, 2018. The stock options are exercisable for seven years from the original grant date of January 1, 2017, until January 1, 2024.

On May 1, 2018, 500,000 stock options, with an exercise price of $0.065 per share were granted to an employee. The stock options vested on the issue date. The stock options are exercisable for approximately 7.5 years from the date of grant of May 1, 2018 to December 31, 2025.

On June 1, 2018, 67.5 million stock options, with an exercise price of $0.075 per share were granted to employees, directors and contractors. 18.5 million of the stock options vested on June 1, 2018, 24 million vested on June 1, 2019 and 25 million will vest on June 1, 2020 provided the holder continues to serve as an employee or a director on the vesting date. The stock options are exercisable for approximately 7.5 years from the grant date of June 1, 2018, to December 31, 2025. 49 million of these stock options were awarded from the Company’s 2018 Omnibus Incentive Plan and 18.5 million stock options were inducement awards.

On January 2, 2019 the Company issued 1 million stock options to a former employee and contractor. 50% of the stock options vested on the issue date and the remainder will vest in July 2019. The stock options were valued at approximately $35,000 to be recognized over the service period of seven months. The stock options are exercisable until December 31, 2025.

The fair value of the stock-options granted during 2018 and 2019 were determined using the Black Scholes valuation model with the following key assumptions:

NOTE 7– STOCK-BASED COMPENSATIONThe following table summarizes the Company’s stock option activity during the nine months ended June 30, 2019:

There was approximately $0.4 million of intrinsic value for the options outstanding as of June 30, 2019. As of June 30, 2019, there was approximately $1.5 million of unrecognized stock-based compensation expense to be recognized over a period of 1 year.

Stock-based compensation cost is measured at the grant date, based onusing the estimated fair value of the award, and is recognized over the required vesting period. The Company recognized $93,381$415,111 and $0$1,371,150 in stock-basedstock based compensation during the three months ended December 31, 2017,June 30, 2019 and December 31, 2016,June 30, 2018, respectively. For the three months ended December 31, 2017, aA portion of these costs, $27,875$229,255 and $585,858, were capitalized to unproved properties for the three months ended June 30, 2019 and June 30, 2018, respectively, with the remainder were recorded as general and administrative expenses.

expenses for each respective period. The following table summarizes the Company’sCompany recognized $1,217,214 and $1,464,534 in stock option activity during the threebased compensation for nine months ended December 31, 2017:

Stock-based compensation cost is measured at the grant date, based on the estimated fair value of the award,June 30, 2019 and is recognized over the required vesting period.  For the quarter ended December 31, 2017 and 2016 there was $93,381 and $0 in stock-based compensation cost,2018, respectively. For the quarter ended December 31, 2017 aA portion of these costs, $27,875,$659,196 and $613,733, were capitalized to unproved properties for the nine months ended June 30, 2019 and the remainder were recorded as general and administrative expenses.2018, respectively.

The intrinsic value of the options outstanding as of December 31, 2017 was $1.2 million.  As of December 31, 2017 there was no unrecognized stock-based compensation.

NOTE 89 – COMMITMENTS AND CONTINGENCIES

In March 2013,July 2018, the Company licensed certain seismic data pursuantentered into a thirty-nine month lease for approximately 5,000 square feet of office space. Annual base rent is approximately $94 thousand for the first 18 months, increasing to approximately $97 thousand and $99 thousand, respectively during the remaining term of the lease.

The Company reached an agreement with a vendor in August 2018 for $4,012,260. Asthe settlement of December 31, 2017, the Company hasapproximately $1 million in debt. The vendor was paid $3,009,195approximately $0.16 million in cash and 10 million shares of GulfSlope common stock. The agreement contains a provision that upon the sale of the common stock if the original debt is obligatednot fully satisfied, full payment will be made under a mutually agreed payment plan. If the stock is sold for a gain any surplus in excess of $1.3 million shall be a credit against future purchases from the vendor. The agreement was determined to pay $1,003,065 during fiscal 2018.

meet the definition of a derivative in accordance with ASC 815. At June 30, 2019 there is a derivative financial instrument liability of approximately $0.5 million.

In October 2017,2018, the Company purchased a directors and officers’ insurance policy for $171,360approximately $160,000 and financed $156,718$146,000 of the premium by executing a note payable. The balance of the note payable at December 31, 2017June 30, 2019, is $128,807.approximately $41,000.

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.

NOTE 910 – SUBSEQUENT EVENTS

Additional insurance proceeds of approximately $2.5 million were received in July and August 2019 for 100% working interest related to the Tau well incident (see Note 3).

On January 8, 2018, GulfSlope Energy, Inc. (the “Company”) entered into a participation agreement (the “Agreement”) with Delek GOM Investments, LLC, a subsidiary of Delek Group Ltd. (“Delek”), and Texas South Energy, Inc. (“Texas South”) (collectively, the “Parties”) for the Company’s interests in its Gulf of Mexico oil and gas leases (the “Farm-out”). The Agreement sets out the terms and conditions of the Parties’ participation in the drilling of a multi-phase exploration program targeting the Company’s prospects (the “Prospects”) located on the Company’s existing leases (the “Leases”). Under the terms of the Agreement, the Parties have committed to drill the Company’s “Canoe” and “Tau” prospects (the “Initial Phase”) with Delek having the option to participate in two additional two-well drilling phases and a final, three-well drilling phase (collectively, the “Phases”). In each Phase, Delek will earn a 75% working interest upon paying 90% of the exploratory costs associated with drilling each exploratory well. The Company will retain a 20% working interest while paying 8% of the exploratory costs associated with drilling each well. In addition, Delek will pay the Company approximately $1.1 million in cash for each Prospect exploration plan filed with BOEM and/or BSEE. Also, each Party will be responsible for its pro rata share (based on working interest) of delay rentals associated with the Prospects. The Company will be the Operator during exploratory drilling of the Prospect, however, subsequent to a commercial discovery, Delek will have the right to become the Operator. Delek will have the right to terminate this Agreement at the conclusion of any drilling Phase. Delek will also have the option to purchase up to 5% of the Company’s common stock, par value $0.001 per share (the “Common Stock”), upon fulfilling its obligation for each Phase (maximum of 20% in the aggregate) at a price per share equal to a 10% discount to the 30-day weighted average closing price for the Common Stock preceding the acquisition. This option will expire January 8, 2020. The foregoing description of the Agreement does not purport to be a complete description of the terms, provisions and conditions of such document, and represents only a summary of certain of the principal terms, provisions and conditions thereof. The Company will assign an eight-tenths of one percent of eight/eights net profits interest in certain of the Company’s oil and gas leases to include Vermilion Area, South Addition 378, Ship Shoal Area, South Addition 336, and Ship Shoal Area, South Addition 351, to Hi-View Investment Partners, LLC (“Hi-View”) in consideration for consulting services provided pursuant to a non-exclusive consulting engagement dated October 25, 2017, by and between Hi-View, the Company, and Texas South (the ”Advisory Agreement”). Hi-View will be entitled to additional assignments on the same terms and conditions as described above related to any of the Leases whereby Delek elects to participate in drilling of an exploratory well. In addition, the Company issued an aggregate of eighty million shares of Common Stock to Hi-View in consideration for consulting services provided pursuant to the Advisory Agreement. In the event that Delek has not funded the approximately one million one hundred thousand payment referenced above within six months of execution of this Agreement, then the Common Stock will be returned by Hi-View to the Company.

On January 1, 2018, the Company executed the third amendment to the March 2014 farm-out agreement with Texas South under which Texas South will acquire 20% of GulfSlope’s interest in two prospects for $225,000.

In January 2018 the maturity date of convertible promissory notes (bridge financing) that matured on January 15, 2018 was extended to April 16, 2018 in exchange for 2.79 million additional warrants.

In February 2018, the Company executed a drilling rig contract with Atlantic Maritime Services LLC, a wholly owned subsidiary of Rowan Companies plc, to secure and utilize the Rowan Ralph Coffman jackup drilling rig for the Company’s 2018 Gulf of Mexico drilling program.GulfSlope anticipates spudding the first well in mid-2018 on Vermilion Area, South Addition Block 378 (Canoe Shallow prospect) and the second well on Ship Shoal Area, South Addition Blocks 336 / 351 (Tau prospect) shortly thereafter. Initial drilling on both prospects is expected to be completed before the end of the year.The Ralph Coffman is a high specification jackup rig that can drill to 35,000 feet. The rig is currently being mobilized from Trinidad and is anticipated to arrive in the Gulf of Mexico shortly.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Forward-looking Statements

The following discussion highlights the principal factors that have affected our financial condition and results of operations as well as our liquidity and capital resources for the periods described. This discussion contains forward-looking statements. Please see “Forward-Looking Statements” above.

Historical Operations

GulfSlope Energy, Inc. is an independent oil and natural gas exploration and production company whose interests are concentrated in the United States, Gulf of Mexico federal waters offshore Louisiana.Louisiana in 450 feet or less of water depth. The Company has leased twelveunder lease seven federal Outer Continental Shelf blocks (referred to as “leases” in this report) and licensed 2.2 million acres (440 blocks) of three-dimensional (3-D) seismic data in its area of concentration.

Approximately half of this data has been reprocessed utilizing Reverse Time Migration (RTM) to more accurately define the imaging below salt. Since March 2013, we have been singularly focused on identifying high-potential oil and natural gas prospects located on the shelf in the U.S. GOM. We have evaluated our licensed 3-D seismic data using advanced interpretation technologies. As a result of these analyses, we have identified and acquired leases on multiple prospects that we believe may contain economically recoverable hydrocarbon deposits, and we plan to continue to conduct more refined analyses of our prospects as well as target additional lease and property acquisitions. 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. Recent actions of the Bureau of Ocean Energy Management (“BOEM”) have reduced the royalty rate for leases acquired in future lease sales in water depths of less than 200 meters (approximately 656 feet) from 18.75% to 12.5%, which further enhances the economics for the drilling of any leases acquired after August 2017 in these water depths. This reduced royalty applies to three of the Company’s leases.

The Company has invested significant technical person hours in the proprietaryreprocessing and interpretation and the associated high-end reprocessing of this seismic data. The result of this proprietary interpretation has been the identification of multiple prospects that we believe may have substantial potential hydrocarbon deposits. Based on this analysis, we currently have twelve blocks under lease in the federal waters of Offshore Gulf of Mexico. 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 (“E&P”) companies operating in our focuscore area. We have identified nine prospects that are covered by our leases and throughout this Report we refer to these acquired leases as our “portfolio.”

In March 2014 and 2015, we participated in the Central Gulf of Mexico Lease Sales 231 and 235 and were awarded twenty-three blocks through a competitive bid process.  After evaluating our leasehold position we relinquished six lease blocks in 2016 and six lease blocks in 2017. In August 2017 we competitively bid at the Central Gulf of Mexico Lease Sale 249 and were awarded one block, leaving the Company with twelve Outer Continental Shelf blocks, and nine prospects that we believe may contain economically recoverable hydrocarbon deposits.

Through December 31, 2017, we have spent approximately $26.5 million on the acquisition, reprocessing, and interpretation of seismic data associated with our seismic license agreements and these costs were capitalized as oil and gas exploration costs which are subject to periodic evaluation for impairment. Approximately $19.5 million of these seismic-related expenses were impaired for accounting purposes. Approximately $7.0 million of our exploration expenditures remain capitalized. These capitalized exploration costs when added with our lease acquisition and annual lease rental costs of $10.5 million and netted with the $11.0 million received from the sale of working interests and the impairment of relinquished leases of $4.7 million, results in the $1.8 million reflected as Unproved Oil and Natural Gas Properties on our Condensed Balance Sheet as of December 31, 2017.

We have historically operated our business with working capital deficits and these deficits have historically been funded by equity investments and loans from management. As of December 31, 2017,June 30, 2019, we had $0.1$2.3 million of cash on hand.hand, $2.0 million of this amount is for the payment of joint payables from drilling operations. The Company estimates that it will need to raise a minimum of $10$10.0 million to meet its obligations and planned expenditures through FebruarySeptember 2020. 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, which amounted to $11.6 million of current principal and interest as of June 30, 2019. The Company plans to finance its operations through the issuance of equity andand/or debt financings. Therefinancings; however, there are no assurances that financing will be available with acceptable terms, if at all.

Competitive Advantages

Current OperationsExperienced management. Our management has significant experience in finding and developing oil and natural gas. Our team has a track record of discovering and developing multi-billion dollar projects worldwide. The Company’s management team has over 200 years of combined industry experience exploring, discovering, and developing oil and natural gas. We successfully deployed a technical team with over 150 years of combined industry experience exploring for 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 correctly locating the images in three dimensions. Our technical team has significant experience utilizing advanced seismic image processing techniques in our core area, and we apply the industry’s most advanced noise reduction technology to generate clearer images.

Industry leading position in our core area. We have licensed 2.2 million acres of 3D seismic data which covers over 440 OCS Federal lease blocks on the highly prolific Louisiana outer shelf, offshore 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 reservoir sand and petroleum trapping models, gives us an advantage in assembling a high-quality drilling portfolio in our core area. We continuously work to identify additional leasing opportunities to further enhance our drilling portfolio.

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 drill targets below the salt bodies in an area of the shallower waters of the GOM where industry activity has largely been absent for over 20 years. In 2016,fact, 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 initial 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 they 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 and Acquisition 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 seven leases that comprise five prospects and we intend to evaluate additional potential sources for growth opportunities with companies that hold active leases in our core area. Our leases have a five-year primary term, expiring in 2020, 2022 and 2023. BOEM’s 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. Additional prospective acreage can be obtained through 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, in order to more precisely define the most optimal drillable location(s), particularly for development of discoveries.

We continue to evaluate potential producing property acquisitions in the offshore GOM, taking advantage of our highly specialized subsurface and engineering capabilities, knowledge, and expertise to identify attractive opportunities. Any merger or acquisition is likely to be financed through a combination of debt and equity.

Drilling and other Exploratory and Development Strategies

With our success in the leasing of our targeted prospects, 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 completedas a means to fund development or additional exploration projects as an alternative to potential equity or debt offerings. However, if a reasonable value were not received from the technical workmarket 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 seven sub-salta promoted basis in order to substantially reduce capital development requirements. We will also evaluate and seek to acquire producing properties that have a strategic relationship to our core area.

Current Operations

The Company is currently conducting pre-drill operations on two prospects and has declared these to be drill ready. The Company estimates the cost to drill the exploration wells on these prospects to be approximately $200 million. The recoverable resource potential is estimated to be more than 800 mmboe (million barrels oil equivalent) on a gross (100% working interest) and unrisked basis. Additional prospects are expected to be advanced to the drill ready stage through new seismic reprocessing and/or additional seismic acquisition.we anticipate spudding one well in late 2019. The Company continues to be active in the evaluation of potential mergers and acquisitions that it deems to be attractive opportunities. Any such merger or acquisition is likely to be financed through a combination of debt and equity.

As a result of the extensive reprocessing and mapping of its licensed 3D, seismic data, the Company also developed two shallow depth prospects with drilling depths of approximately 5,000 feet.

On January 8, 2018, the Company signed comprehensive documents related to partnering with Delek Group and Texas South to participate in the drilling of nine currently leased prospects. The initial phase (Phase I) consists of a commitment to drill the Canoe Prospect (VR378) to approximately 5000’ and the Tau Prospect (SS336 and SS351) to approximately 26,000’. The Company will fund 8%commenced drilling operations at the Canoe prospect in August 2018. The well completed drilling in August 2018 and based on Logging-While-Drilling (LWD) and Isotube analysis of hydrocarbon samples, oil sands were encountered in the northwest center of the block. The well was drilled to a total of 5,765 feet measured depth (5,700 feet true vertical depth) and encountered no problems while drilling. A full integration of the well costsinformation and retainseismic data is being performed for further evaluation of the shallow potential of the wellbore and the block, and to define commerciality of these oil pays. The well was temporarily abandoned, and multiple open hole plugs were set across several intervals. The well is equipped with a 20%mud-line suspension system for possible future re-entry. A deeper subsalt prospect on the Canoe lease block, for which the block was originally leased, is drill-ready, due to further seismic enhancement.

The Tau Prospect is located approximately six miles northeast of the Mahogany Field, discovered in 1993. The Mahogany Field is recognized as the first commercial discovery below allocthonous salt in the Gulf of Mexico. The Tau Prospect is defined by mapping of 3D seismic reprocessed by RTM methods. Drilling operations on the Tau subsalt prospect commenced in September 2018. The wellbore is designed to test multiple Miocene horizons trapped against a well-defined salt flank, including equivalent reservoir sands discovered and developed at the nearby Mahogany Field. The surface location for Tau is located in 305 feet of water. In January 2019, the Tau well experienced an underground control of well event and as a result, we filed an insurance claim with its insurance underwriters for a net amount of approximately $10.8 million for 100% working interest that is subjectinterest. The insurance claim was subsequently approved. On May 13, 2019, GulfSlope announced the Tau well was drilled to a .8% Net Profits Interest. GulfSlope ismeasured depth of 15,254 feet, as compared to the named operatororiginally permitted 29,857 foot measured depth. Producible hydrocarbon zones were not established to the current depth, but hydrocarbon shows were encountered. Complex geomechanical conditions required two by-pass wellbores, one sidetrack wellbore, and eight casing strings to reach the current depth. Equipment limitations prevent further drilling at this time. In addition, the drilling rig had contractual obligations related to another operator. Due to these factors, the Company has elected to temporarily abandon this well in a manner that would allow for the exploratory wells. Delek has the option to participate in 3 subsequent phases of drilling under the same terms. It also has the right to purchase up to 5% of the outstanding shares of GSPE common stock after each drilling phase forre-entry at a cumulative right to purchase 20% of the shares outstanding. The Company will receive a partial recoupment of sunk costs of $1.1M for each prospect to be drilled.

later time. The Company is currently preparing the extensive documentation required for the permitsevaluating various options related to drill the exploratory wells on the Canoefuture operations in this wellbore and Tau Prospects and expects to file the permit applications for both wells in March 2018. Drilling operations are expected to commence mid-2018, subject to receipttesting of the required permits to drill.

deeper Tau prospect.

The Company has contracted with Atlantic Maritime Services LLC,completed the shallow hazard seismic survey for a third planned well and the detailed engineering and permitting process for the usedrilling of the Rowan Ralph Coffman jackup drilling rigthat well. The exploration plan for these two wells. The rig is currently being mobilized from Trinidad to the U. S. Gulf of Mexico.

GulfSlope estimates that it’s net working interest for these two prospects could hold over 50 mmboe recoverable oil and gas and estimates the net cost to the Company to drill these two wells is approximately $4 million.   

this well was approved by BOEM in July 2019.

The Company has incurred accumulated losses for the period from inception to December 31, 2017June 30, 2019, of approximately $39.7$54.6 million, and has a netnegative working capital deficiency.of $20.6 million for the nine months ended June 30, 2019. For the nine months ended June 30, 2019, the Company has generated losses of $12.7 million and negative cash flows from operations of $7 million. Further losses are anticipated in developing its business. As a result, there exists substantial doubt about the Company’s ability to continue as a going concern on its report for the year ended September 30, 2017.concern. As of December 31, 2017,June 30, 2019, the Company had approximately $0.1$2.3 million of unrestricted cash on hand.hand, $2.0 million of this amount is for the payment of joint payables from drilling operations. The Company estimates that it will need to raise a minimum of $10  million to meet its obligations and planned expenditures through FebruarySeptember 2020. 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, which amounted to $11.6 million of current principal and interest as of June 30, 2019. These expenditures include the Company’s drilling costs, lease rentals to the BOEM, general and administrative expenses, and costs associated with seismic acquisition and processing. The Company plans to finance the Company through best-efforts equity and/or debt financings and farm-out agreements. The Company also plans to extend the agreements associated with loans from related parties, the accrued interest payable on these loans, as well as the Company’s accrued liabilities. The Company plansThough, it is uncertain as to financewhether the Company through best-efforts equity and/will be able to successfully implement these plans or debt financings.that acceptable financing terms will be obtained. The accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Significant Accounting Policies

The Company uses the full cost method of accounting for its oil and natural gas exploration and development activities as defined by the Securities and Exchange Commission (“SEC”).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 and overhead charges directly related to acquisition, exploration and development activities. 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.

Proved properties are amortized on a country-by-country basis using the units of production method (UOP). The UOP calculation multiplies the percentage of estimated(“UOP”), whereby capitalized costs are amortized over total proved reserves produced each quarter by the cost of those reserves. The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (DD&A)(“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 limits such pooled costs tois defined as the aggregatesum of the present value of(a) estimated future net revenues, attributable to proved crude oil and natural gas reserves discounted at 10%, plus 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 less any associated tax effects.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.

As of December 31, 2017,June 30, 2019, the Company’s oil and gas properties consisted of wells in process, capitalized exploration and acquisition costs for 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.

A more complete discussion ofThere has been no change to our critical accounting policies isas included in our annual report on Form 10-K as of September 30, 2017,2018, which was filed with the Securities and Exchange Commission on December 29, 2017.31, 2018.  

Factors Affecting Comparability of Future Results  

Success in Acquiring Oil and Gas Leases or Prospects.   As a result of our 3-D seismic imaging and reprocessing, we currently hold twelve lease blocks in the U.S. Gulf of Mexico, which we believe may potentially contain economically recoverable reserves. 

We have No Proved Reserves. While we have acquired most of the oil and gas properties that we pursued, we have no proved reserves.  We have identified prospects based on available seismic and geological information that indicate the potential presence of oil or gas, and we own the drilling and production rights for these prospects.  Some of our current prospects may require additional seismic data reprocessing and interpretation.  Even when properly used and interpreted, seismic data and visualization techniques are only tools used to assist geoscientists in identifying structures and hydrocarbon indicators and do not enable the interpreter to have certainty as to whether hydrocarbons are, in fact, present in those structures. We do not know if any prospect will contain oil or gas in sufficient quantities or quality to recover drilling and completion costs or to be economically viable. 

Success in the Discovery and Development of Reserves.   Because we have no operating history in the production of oil and gas, our future results of operations and financial condition will be directly affected by our ability to discover and develop reserves through our drilling activities.

Oil and Gas Revenue.   We have not yet commenced oil and gas production. If and when we do commence production, we expect to generate revenue from such production. No oil and gas revenue is reflected in our historical financial statements.

General and Administrative Expenses.   We expect that our general and administrative expenses will increase in future periods when we commence drilling operations.

Demand and Price.   The demand for oil and gas is susceptible to volatility related to, among other factors, the level of global economic activity and may also fluctuate depending on the performance of specific industries. We expect that a decrease in economic activity, in the United States and elsewhere, would adversely affect demand for any oil and gas we may produce. Since we have not generated revenues, these key factors will only affect us if and when we produce and sell hydrocarbons.

For a more complete discussion of the factors affecting comparability of our future results, see the risk factors included in Item 1A our annual report on Form 10-K as of September 30, 2017, which was filed with the Securities and Exchange Commission on December 29, 2017.   

Three Months Ended December 31, 2017June 30, 2019 Compared to Three Months Ended December 31, 2016June 30, 2018

NoThere was no revenue was recorded during the three months ended December 31, 2017June 30, 2019 and 2016.June 30, 2018. We incurred approximately $4.3 million of impairment of oil and natural gas properties for the three months ended June 30, 2019 and zero for the three months ended June 30, 2018. This is due to the expiration of oil and gas leases for the three months ended June 30, 2019. General and administrative expenses were approximately $0.3$0.4 million for the three months ended December 31, 2017,June 30, 2019, compared to approximately $0.8 million for the three months ended June 30, 2018. This decrease in expense is primarily due to a decrease in stock compensation expense. Interest expense was $2.1 million for the three months ended June 30, 2019 compared to $0.2 million for the three months ended December 31, 2016. This increase isJune 30, 2018, primarily due to stock compensation expense. Interest expense was $0.2the day one charge of approximately $1.7 million of interest as the derivative fair value relating to the convertible notes exceeded the proceeds for the three months ended December 31, 2017June 30, 2019. For the three months ended June 30, 2019 there was a loss of $0.1 million for a derivative financial instrument, compared to $0.3 millionzero for the three months ended December 31, 2016.June 30, 2018.

Nine Months Ended June 30, 2019 Compared to Nine Months Ended June 30, 2018

There was no revenue during the nine months ended June 30, 2019 and June 30, 2018. We incurred approximately $4.3 million of impairment of oil and natural gas properties for the nine months ended June 30, 2019 and zero for the nine months ended June 30, 2018, resulting from the expiration of oil and gas leases during the period ended June 30, 2019. General and administrative expenses were approximately $1.0 million for the nine months ended June 30, 2018, compared to approximately $1.2 million for the nine months ended June 30, 2018. This decrease iswas primarily due to a decrease in stock compensation expense of approximately $0.3 million. Interest expense was $2.3 million for the reductionnine months ended June 30, 2019 compared to $0.7 million for the nine months ended June 30, 2018. This increase was primarily due to interest resulting from the day one charge of approximately $1.7 million of interest as the derivative fair value relating to the convertible notes exceeded the proceeds for the nine months ended June 30, 2019 compared to June 30, 2018. Loss on debt extinguishment was approximately $5.1 million for the nine months ended June 30, 2019 and approximately $0.2 million for the nine months ended June 30, 2018. This increase was primarily due to a loan and subsequent warrant exercise resulting in loan extinguishment and the loss on debt discount amortization.   

extinguishment. Loss on derivative financial instrument was $0.01 million and zero for the nine months ended June 30, 2019.

Liquidity and Capital Resources

The Company has incurred accumulated losses for the period from inception to June 30, 2019, of approximately $54.6 million, and has a negative working capital of $20.6 million. For the nine months ended June 30, 2019, the Company has generated losses of $12.7 million and negative cash flows from operations of $7 million. As of December 31, 2017,June 30, 2019, we had $0.1$2.3 million of cash on hand.hand, $2.0 million of this amount is for joint payables from drilling operations. The Company estimates that it will need to raise a minimum of $10 million to meet its obligations and planned expenditures through FebruarySeptember 2020. 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, which amounted to $11.6 million of current principal and interest as of June 30, 2019. The Company plans to finance its operations through the issuance of equity and debt financings. 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 threenine months ended December 31, 2017,June 30, 2019, the Company used approximately $0.18$7.0  million of net cash in operating activities, compared with approximately $0.10$2.7 million of net cash usedreceived in operating activities for the threenine months ended December 31, 2016,June 30, 2018, due to increased generalapproximately $4.1 million decrease in deposits and administrativean $11.5 million increase in receivables and professional expenses.a $8.8 million increase in accounts  payable and accrued liabilities. For the threenine months ended December 31, 2017June 30, 2019 we receivedused approximately $0.1$9.1 million of cash fromin investing activities compared with approximately $0.06$2.1 million of cash usedreceived in investing activities for the threenine months ended December 31, 2016June 30, 2018, primarily due to a net of $0.1$9.8 million frominvestment in oil and gas properties for the nine months ended June 30, 2019 and approximately $2.9 million received for sale of working interest and offset by approximately $0.8 million investment in oil and gas properties for the threenine months ended December 31, 2017.June 30, 2018. For the threenine months ended December 31, 2017June 30, 2019 we received approximately $0.2$12.8 million of net cash from financing activities, compared with approximately $0.2$0.1 million received in financing activities for the threenine months ended December 31, 2016.   

June 30, 2018. This increase is due to loan proceeds received during the nine months ended June 30, 2019.

We will need to raise additional funds to cover expenditures planned after FebruarySeptember 2019, 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 partythird-party investors, and will continue to rely on best efforts financings. The failure to raise sufficient capital could cause us to cease operations.   

operations, or the Company would need to sell assets or consider alternative plans up to and including restructuring.

Off-Balance Sheet Arrangements

None.

None.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Due to the historical volatility of commodity prices, if and when we commence production, our financial condition, results of operations and capital resources will be highly dependent upon the prevailing market prices of oil and natural gas. These commodity prices are likely to continue to be subject to wide fluctuations and market uncertainties due to a variety of factors that are beyond our control. In the future, we may enter into various derivative instruments to manage our exposure to volatility of commodity market prices. We may use options (including floors and collars) and fixed price swaps to mitigate the impact of downward swings in commodity prices to our cash flow. All contracts will be settled with cash and would not require the delivery of physical volumes to satisfy settlement. While in times of higher commodity prices this strategy may result in our having lower net cash inflows than we would otherwise have if we had not utilized these instruments, management believes the risk reduction benefits of such a strategy would outweigh the potential costs.

At December 31, 2017,June 30, 2019 we had approximately $8.9$12.3 million of fixed-rate debt outstanding. All fixed-rate debt has a weighted average interest rate of 5%. We also had approximately $1.1 million of convertible debt with a weighted average interest rate of 7.6%5.58%. Although near term changes in interest rates may affect the fair value of our fixed-rate debt, they do not expose us to the risk of earnings or cash flow loss.

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 not 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.

As noted in the Company’s Annual Report on Form 10-K for the year ended September 30, 2018, the design and operating effectiveness of our controls were inadequate to ensure that all complex accounting matters are properly accounted for and reviewed in a timely manner. As a result, we failed to accurately record interest on an interest bearing payable and failed to accurately identify and value a fair value financial instrument issued in settlement of a liability. These errors are a result of insufficient control activities related to the review and monitoring of Company contracts to ensure the proper accounting for such contracts.In connection with the restatement of our condensed financial statements, as of March 31, 2019, we identified an additional material weakness in our internal control over financial reporting. This additional material weakness is due to a lack of effective controls over the valuation of accounts receivable which resulted in a material error in the financial statements.Ongoing remediation efforts are being implemented. 

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

DuringManagement has developed a contract review process, increased the fiscaluse of external consultants and is investigating expansion of the accounting department in its ongoing remediation efforts of the material weaknesses reported by management in our Annual Report on Form 10-K and prior quarter covered by this Report,Form 10-Q/A. Other than the ongoing remediation efforts, there hashave been no changechanges in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that hashave materially affected, or isare reasonably likely to materially affect, our internal control over financial reporting.

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

There have been no material changes fromIn addition to the risk factors disclosed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended September 30, 2017,2018, which was filed with the Securities and Exchange Commission on December 29, 2017.31, 2018, we have added the following risk factor:

If we fail to establish and maintain proper internal controls, our ability to produce accurate financial statements or comply with applicable regulations could be impaired

We are required to comply with certain provisions of Section 404 of the Sarbanes-Oxley Act of 2002 (“Sarbanes-Oxley Act”). Section 404 requires that we document and test our internal control over financial reporting and issue management’s assessment of our internal control over financial reporting. In our annual report for the year ended September 30, 2018, we identified and disclosed material weaknesses related to the failure to record interest on an interest bearing payable and failure to accurately value a fair value financial instrument issued in settlement of a liability. These errors are a result of insufficient control activities related to the review and monitoring of Company contracts to ensure the proper accounting for such contracts. In an attempt to remediate the material weaknesses, we have made significant advancements to our processes and internal controls surrounding non-routine and complex arrangements to strengthen our financial reporting processes.

If we fail to comply with the requirements of Section 404 of the Sarbanes-Oxley Act, the accuracy and timeliness of the filing of our annual and quarterly reports may be materially adversely affected and could cause investors to lose confidence in our reported financial information, which could have a negative effect on the trading price of our Common Stock. 

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

During the quarter ended December 31, 2017,June 30, 2019, the Company issued 2,000,000approximately 2.8 million shares of restricted stock for the exercise of warrants.

The offer and sale of the securities described above were made without registration under the Securities Act, and the applicable securities laws of certain states, in reliance upon exemptions provided by Section 4(a)(2) and Regulation D under the Securities Act and in reliance upon similar exemptions under applicable state laws with regard to a lenderthe offer and sale of securities that are made solely to “accredited investors,” as partthat term is defined under Rule 501(a) of two financing transactions.Regulation D, and do not involve any general solicitation.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

The following exhibits are attached hereto or are incorporated by reference:

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)