EON Resources Inc

Previous wording

References in this report (the “Quarterly Report”) to “we,” “us” or the “Company” refer to HNR Acquisition Corp. References to our “management” or our “management team” refer to our officers and directors, and references to the “Sponsor” refer to HNRAC Sponsors, LLC. References to the Predecessor refer to the business of Pogo Resources, LLC and its subsidiaries prior to the Closing Date. The following discussion and analysis of the Company’s financial condition and results of operations should be read in conjunction with the unaudited consolidated financial statements and the notes thereto contained elsewhere in this Quarterly Report. Certain information contained in the discussion and analysis set forth below includes forward-looking statements that involve risks and uncertainties.

Current wording

References in this report (the “Quarterly Report”) to “we,” “us” or the “Company” refer to EON Resources, Inc. (formerly HNR Acquisition Corp.). References to our “management” or our “management team” refer to our officers and directors, and references to the “Sponsor” refer to HNRAC Sponsors, LLC. References to the Predecessor refer to the business of Pogo Resources, LLC and its subsidiaries prior to the Closing Date. The following discussion and analysis of the Company’s financial condition and results of operations should be read in conjunction with the unaudited consolidated financial statements and the notes thereto contained elsewhere in this Quarterly Report. Certain information contained in the discussion and analysis set forth below includes forward-looking statements that involve risks and uncertainties.

Previous wording

We are an independent oil and natural gas company based in Texas and formed in 2020 that is focused on the acquisition, development, exploration, production and divestiture of oil and natural gas properties in the Permian Basin. The Permian Basin is located in west Texas and southeastern New Mexico and is characterized by high oil and liquids-rich natural gas content, multiple vertical and horizontal target horizons, extensive production histories, long-lived reserves and historically high drilling success rates. HNRA’s properties are in the Grayburg-Jackson Field in Eddy County, New Mexico, which is a sub-area of the Permian Basin. Pogo focuses primarily on production through waterflooding recovery methods.

Current wording

We are an independent oil and natural gas company based in Texas and formed in 2020 that is focused on the acquisition, development, exploration, production and divestiture of oil and natural gas properties in the Permian Basin. The Permian Basin is located in west Texas and southeastern New Mexico and is characterized by high oil and liquids-rich natural gas content, multiple vertical and horizontal target horizons, extensive production histories, long-lived reserves and historically high drilling success rates. Our properties are in the Grayburg-Jackson Field in Eddy County, New Mexico, which is a sub-area of the Permian Basin. Pogo focuses primarily on production through waterflooding recovery methods.

Previous wording

The Company’s assets as mentioned above consist of contiguous leasehold positions of approximately 13,700 gross (13,700 net) acres with an average working interest of 100%. We operate 100% of the net acreage across the Company’s assets, all of which is net operated acreage of vertical wells with average depths of approximately 3,810 feet.

Current wording

Our assets as mentioned above consist of contiguous leasehold positions of approximately 13,700 gross (13,700 net) acres with an average working interest of 100%. We operate 100% of the net acreage across the Company’s assets, all of which is net operated acreage of vertical wells with average depths of approximately 3,810 feet.

Previous wording

Our average daily production for the six months ended June 30, 2024 was 814 barrel of oil equivalent (“BOE”) per day. Our average daily production for the year ended December 31, 2023, was 1,022 BOE per day. The decrease in production is due to an increase in well downtime, water injection flowlines that needed repair or replacement, and the conveyance of the 10% Override royalty interest to Pogo Royalty.

Current wording

Our average daily production for the nine months ended September 30, 2024 was 814 barrel of oil equivalent (“BOE”) per day. Our average daily production for the year ended December 31, 2023, was 1,022 BOE per day. The decrease in production is due to an increase in well downtime, water injection flowlines that needed repair or replacement, and the conveyance of the 10% Override royalty interest to Pogo Royalty.

Previous wording

The price at which our oil and natural gas production are sold typically reflects either a premium or discount to the New York Mercantile Exchange (“NYMEX”) benchmark price. Thus, our operating results are also affected by changes in the oil price differentials between the applicable benchmark and the sales prices we receive for our oil production. Our oil price differential to the NYMEX benchmark price during the six months ended June 30, 2024 and 2023, was $(1.41) and $(0.76) per barrel, respectively. Our natural gas price differential during the six months ended June 30, 2024 and 2023, was $0.35 and $0.09 per one thousand cubic feet (“Mcf”), respectively. Fluctuations in our price differentials and realizations are due to several factors such as gathering and transportation costs, takeaway capacity relative to production levels, regional storage capacity, gain/loss on derivative contracts and seasonal refinery maintenance temporarily depressing demand.

Current wording

The price at which our oil and natural gas production are sold typically reflects either a premium or discount to the New York Mercantile Exchange (“NYMEX”) benchmark price. Thus, our operating results are also affected by changes in the oil price differentials between the applicable benchmark and the sales prices we receive for our oil production. Our oil price differential to the NYMEX benchmark price during the nine months ended September 30, 2024 and 2023, was $(2.07) and $(3.22) per barrel, respectively. Our natural gas price differential during the nine months ended September 30, 2024 and 2023, was $0.04 and $0.03 per one thousand cubic feet (“Mcf”), respectively. Fluctuations in our price differentials and realizations are due to several factors such as gathering and transportation costs, takeaway capacity relative to production levels, regional storage capacity, gain/loss on derivative contracts and seasonal refinery maintenance temporarily depressing demand.

Previous wording

Prices for various quantities of natural gas and oil that we produce significantly impact our revenues and cash flows. The following table lists average NYMEX prices for oil and natural gas for the three and six months ended June 30, 2024 and 2023.

Current wording

Prices for various quantities of natural gas and oil that we produce significantly impact our revenues and cash flows. The following table lists average NYMEX prices for oil and natural gas for the three and nine months ended September 30, 2024 and 2023.

Previous wording

For the six months ended June 30, 2024, the average NYMEX oil pricing was $79.64 per barrel of oil or 6% higher than the average NYMEX price per barrel for the six months ended June 30, 2023. Our settled derivatives decreased our realized oil price per barrel by $3.16 and $1.64 in the six months ended June 30, 2024, and 2023, respectively. Our average realized oil price per barrel after reflecting settled derivatives and location differentials was $75.81 and $71.57 for the three months ended June 30, 2024 and 2023, respectively. Our average realized oil price per barrel after reflecting settled derivatives and location differentials was $75.07 and $72.52 for the six months ended June 30, 2024 and 2023, respectively.

Current wording

For the nine months ended September 30, 2024, the average NYMEX oil pricing was $78.50 per barrel of oil or 7% lower than the average NYMEX price per barrel for the nine months ended September 30, 2023. Our settled derivatives decreased our realized oil price per barrel by $2.56 and $3.47 in the nine months ended September 30, 2024, and 2023, respectively. Our average realized oil price per barrel after reflecting settled derivatives and location differentials was $77.12 and $74.23 for the three months ended September 30, 2024 and 2023, respectively. Our average realized oil price per barrel after reflecting settled derivatives and location differentials was $73.87 and $73.03 for the nine months ended September 30, 2024 and 2023, respectively.

Previous wording

The average NYMEX natural gas pricing for the six months ended June 30, 2024, was $2.11 per Mcf, or 13% lower than the average NYMEX price of $2.41 per Mcf for the six months ended June 30, 2023.

Current wording

The average NYMEX natural gas pricing for the nine months ended September 30, 2024, was $2.11 per Mcf, or 14% lower than the average NYMEX price of $2.47 per Mcf for the nine months ended September 30, 2023.

Previous wording

Effective July 1, 2023, the Predecessor transferred to Pogo Royalty, a related party to the Predecessor, an assigned and undivided overriding royalty interest (“ORRI”) equal in amount to ten percent (10%) of the Company’s interest all oil, gas and minerals in, under and produced from each lease. The consideration received for the 10% ORRI was $10. Thus, a loss of $816,011 was recorded as a result of the conveyance in the previous year. Additionally, because of this transaction, our reserve balance was decreased as well our current net production volumes and revenues.

Current wording

Effective July 1, 2023, the Predecessor transferred to Pogo Royalty, a related party to the Predecessor, an assigned and undivided overriding royalty interest (“ORRI”) equal in amount to ten percent (10%) of our interest all oil, gas and minerals in, under and produced from each lease. The consideration received for the 10% ORRI was $10. Thus, a loss of $816,011 was recorded as a result of the conveyance in the previous year. Additionally, because of this transaction, our reserve balance was decreased as well our current net production volumes and revenues.

Previous wording

Our revenues vary from year to year primarily as a result of changes in realized commodity prices and production volumes. For the three months ended June 30, 2024, our oil and natural gas sales decreased 26% from the three months ended June 30, 2023, driven by a 7% increase in realized prices, excluding the effect of settled commodity derivatives, and a 34% decrease in production volumes, and $83,478 in derivative instrument losses in the three months ended June 30, 2024. Realized production from oil and gas properties decreased due to the sale of the ORRI of 10% by the Predecessor in July 2023 and actual decrease in production due to an increase in well downtime, and the impact of water injection flowlines that needed repair or replacement.

Current wording

Our revenues vary from year to year primarily as a result of changes in realized commodity prices and production volumes. For the three months ended September 30, 2024, our oil and natural gas sales decreased 18% from the three months ended September 30, 2023, driven by a 6% increase in realized prices, excluding the effect of settled commodity derivatives, and a 17% decrease in production volumes, and $1,900,662 in derivative instrument gains in the three months ended September 30, 2024. Realized production from oil and gas properties decreased due to the sale of the ORRI of 10% by the Predecessor in July 2023 and actual decrease in production due to an increase in well downtime, and the impact of water injection flowlines that needed repair or replacement.

Previous wording

We enter into commodity derivatives instruments to manage the price risk attributable to future oil production. We recorded a loss on derivative contracts of $83,478 for the three months ended June 30, 2024, compared to a gain of $346,009 for the three months ended June 30, 2023. Higher commodity prices in the three months ended June 30, 2024, resulted in realized losses of $261,448 compared to realized losses of $131,665 for the three months ended June 30, 2023. For the three months ended June 30, 2024, unrealized gains were $177,970 compared to unrealized gains of $477,674 for the three months ended June 30, 2023.

Current wording

We enter into commodity derivatives instruments to manage the price risk attributable to future oil production. We recorded a gain on derivative contracts of $1,900,662 for the three months ended September 30, 2024, compared to a loss of $1,436,100 for the three months ended September 30, 2023. Higher commodity prices in the three months ended September 30, 2024, resulted in realized losses of $107,969 compared to realized losses of $600,740 for the three months ended September 30, 2023. For the three months ended September 30, 2024, unrealized gains were $2,008,631 compared to unrealized losses of $835,360 for the three months ended September 30, 2023.

Previous wording

For the three months ended June 30, 2024, our average realized oil price per barrel after reflecting settled derivatives was $75.81 compared to $71.57, for the three months ended June 30, 2023. For the three months ended June 30, 2024, our settled derivatives decreased our realized oil price per barrel by $4.29 compared to decreasing the price per barrel by $1.46 for the three months ended June 30, 2023. As of June 30, 2024, we ended the period with a $1,214,436 net derivative liability compared to a net asset of $467,687 as of December 31, 2023.

Current wording

For the three months ended September 30, 2024, our average realized oil price per barrel after reflecting settled derivatives was $77.12 compared to $74.23 for the three months ended September 30, 2023. For the three months ended September 30, 2024, our settled derivatives decreased our realized oil price per barrel by $1.61 compared to decreasing the price per barrel by $7.80 for the three months ended September 30, 2023. As of September 30, 2024, we ended the period with a $794,195 net derivative asset compared to a net asset of $467,687 as of December 31, 2023.

Previous wording

Other revenue was $130,230 for the three months ended June 30, 2024, compared to $147,978 for the three months ended June 30, 2023. The revenue is related to providing water services to a third party. The contract is for one year starting on September 1, 2022, and can be renewed by mutual agreement.

Current wording

Other revenue was $98,452 for the three months ended September 30, 2024, compared to $143,714 for the three months ended September 30, 2023. The revenue is related to providing water services to a third party. The contract is for one year starting on September 1, 2022, and can be renewed by mutual agreement.

Previous wording

Lease operating expenses were $2,094,181 for the three months ended June 30, 2024, compared to $1,981,362 for the three months ended June 30, 2023. On a per unit basis, production expenses increased 59% from $18.60 per BOE for the three months ended June 30, 2023, to $29.50 per BOE for the three months ended June 30, 2024, due primarily to increases in proactive maintenance activities.

Current wording

Lease operating expenses were $2,136,732 for the three months ended September 30, 2024, compared to $2,449,140 for the three months ended September 30, 2023. On a per unit basis, production expenses increased 4.8% from $26.60 per BOE for the three months ended September 30, 2023, to $27.87 per BOE for the three months ended September 30, 2024, due primarily to increases in proactive maintenance activities.

Previous wording

We pay production taxes, transportation and processing costs based on realized oil and natural gas sales. Production taxes, transportation and processing costs were $408,985 for the three months ended June 30, 2024, compared to $590,842 for the three months ended June 30, 2023. As a percentage of oil and natural gas sales, these costs were 8% and 9% in the three months ended June 30, 2024, and 2023, respectively. Production taxes, transportation, and processing as a percent of total oil and natural gas sales are consistent with historical trends.

Current wording

We pay production taxes, transportation and processing costs based on realized oil and natural gas sales. Production taxes, transportation and processing costs were $489,524 for the three months ended September 30, 2024, compared to $602,449 for the three months ended September 30, 2023. As a percentage of oil and natural gas sales, these costs were 9% and 9% in the three months ended September 30, 2024, and 2023, respectively. Production taxes, transportation, and processing as a percent of total oil and natural gas sales are consistent with historical trends.

Previous wording

Depletion, depreciation and amortization (“DD&A”) was $522,542 for the three months ended June 30, 2024, compared to $441,611 for the three months ended June 30, 2023. DD&A was $7.36 per BOE for the three months ended June 30, 2024 compared to $4.15 per BOE for the three months ended June 30, 2023. The aggregate increase in DD&A expense for the three months ended June 30, 2024, compared to the three months ended June 30, 2023, was driven by the increase in the oil and gas properties balance due the recognition of the reserves at fair value as a result of the acquisition of the Pogo business by the Company on November 15, 2023.

Current wording

Depletion, depreciation and amortization (“DD&A”) was $507,626 for the three months ended September 30, 2024, compared to $426,838 for the three months ended September 30, 2023. DD&A was $6.62 per BOE for the three months ended September 30, 2024 compared to $4.64 per BOE for the three months ended September 30, 2023. The aggregate increase in DD&A expense for the three months ended September 30, 2024, compared to the three months ended September 30, 2023, was driven by the increase in the oil and gas properties balance due the recognition of the reserves at fair value as a result of the acquisition of the Pogo business by us on November 15, 2023.

Previous wording

Accretion expense was $40,526 for the three months ended June 30, 2024, compared to $267,568 for the three months ended June 30, 2023. Accretion expense was $0.57 per BOE for the three months ended June 30, 2024, compared to $2.51 per BOE for the three months ended June 30, 2023. The aggregate decrease in accretion expense for the three months ended June 30, 2024, compared to the three months ended June 30, 2023, was driven by changes in certain assumptions, specifically the inflation factor and discount rate as a result of the acquisition date where we revised our estimates as part of its fair value estimates for the acquired business on November 15, 2023

Current wording

Accretion expense was $10,395 for the three months ended September 30, 2024, compared to $200,789 for the three months ended September 30, 2023. Accretion expense was $0.14 per BOE for the three months ended September 30, 2024, compared to $2.18 per BOE for the three months ended September 30, 2023. The aggregate decrease in accretion expense for the three months ended September 30, 2024, compared to the three months ended September 30, 2023, was driven by changes in certain assumptions, specifically the inflation factor and discount rate as a result of the acquisition date where we revised our estimates as part of its fair value estimates for the acquired business on November 15, 2023.

Previous wording

General and administrative expenses were $2,323,662 for the three months ended June 30, 2024, compared to $857,963 for the three months ended June 30, 2023. The increase in general and administrative expenses is primarily due to increased cost of outsourced legal, professional, and accounting services from being a public company, and stock-based compensation in the current period of $490,720.

Current wording

General and administrative expenses were $2,235,263 for the three months ended September 30, 2024, compared to $981,751 for the three months ended September 30, 2023. The increase in general and administrative expenses is primarily due to increased cost of outsourced legal, professional, and accounting services from being a public company, and stock-based compensation in the current period of $326,995.

Previous wording

Interest expense was $2,030,317 for the three months ended June 30, 2024, compared to $559,846 for the three months ended June 30, 2023. The Successor period interest expense is driven by the Senior Secured term loan entered into as part of the Closing, and the Private Notes Payable. The Predecessor interest expense for the three months ended June 30, 2023 relates to the Predecessor’s revolving credit facility outstanding and an increase in the weighted average interest rate. This revolving credit facility was not assumed in the Acquisition. Amortization of financing costs was $662,076 and was primarily associated with discount on the Company’s Private Notes Payable.

Current wording

Interest expense was $1,841,848 for the three months ended September 30, 2024, compared to $554,262 for the three months ended September 30, 2023. The Successor period interest expense is driven by the Senior Secured term loan entered into as part of the Closing, and the Private Notes Payable. The Predecessor interest expense for the three months ended September 30, 2023 relates to the Predecessor’s revolving credit facility outstanding and an increase in the weighted average interest rate. This revolving credit facility was not assumed in the Acquisition. Amortization of financing costs was $507,701 and was primarily associated with discount on our Private Notes Payable.

Previous wording

The change in fair value of forward purchase agreement consisted of a loss of $23,717 for the three months ended June 30, 2024 for the Successor related to the inputs used in the Company’s fair value estimate of the FPA Put Option. The key inputs to the fair value estimate include the Company’s stock price, which declined during the Successor period, and the likelihood, timing and price of a potential dilutive offering.

Current wording

The change in fair value of forward purchase agreement consisted of a loss of $4,209,294 for the three months ended September 30, 2024 for the Successor related to the inputs used in our fair value estimate of the FPA Put Option, primarily the decline in our stock price during the three months ended September 30, 2024. The key inputs to the fair value estimate include our stock price, which declined during the Successor period, and the likelihood, timing and price of a potential dilutive offering.

Previous wording

The change in fair value of warrant liabilities consisted of a loss of $277,167 for the three months ended June 30, 2024 related to fluctuations in the trading price of the Company’s warrants, a portion of which are accounted for as liabilities due to the redemption provisions in those issued to Private Note holders.

Current wording

The change in fair value of warrant liabilities consisted of a loss of $137,911 for the three months ended September 30, 2024 related to fluctuations in the trading price of our warrants, a portion of which are accounted for as liabilities due to the redemption provisions in those issued to Private Note holders.

Previous wording

Six months ended June 30, 2024 (Successor) Compared to six months ended June 30, 2023

Current wording

Nine months ended September 30, 2024 (Successor) Compared to nine months ended September 30, 2023

Previous wording

Our revenues vary from year to year primarily as a result of changes in realized commodity prices and production volumes. For the six months ended June 30, 2024, our oil and natural gas sales decreased 27% from the six months ended June 30, 2023, driven by a 4% increase in realized prices, excluding the effect of settled commodity derivatives, and a 31% decrease in production volumes, and approximately $2,080,725 in derivative instrument losses in the six months ended June 30, 2024. Realized production from oil and gas properties decreased due to the sale of the ORRI of 10% by the Predecessor in July 2023, and actual decrease in production due to an increase in well downtime, and the impact of water injection flowlines that needed repair or replacement.

Current wording

Our revenues vary from year to year primarily as a result of changes in realized commodity prices and production volumes. For the nine months ended September 30, 2024, our oil and natural gas sales decreased 24% from the nine months ended September 30, 2023, driven by a 2% increase in realized prices, excluding the effect of settled commodity derivatives, and a 25% decrease in production volumes, and approximately $180,063 in derivative instrument losses in the nine months ended September 30, 2024. Realized production from oil and gas properties decreased due to the sale of the ORRI of 10% by the Predecessor in July 2023, and actual decrease in production due to an increase in well downtime, and the impact of water injection flowlines that needed repair or replacement.

Previous wording

We enter into commodity derivatives instruments to manage the price risk attributable to future oil production. We recorded a loss on derivative contracts of $2,080,725 for the six months ended June 30, 2024, compared to a gain of $763,043 for the six months ended June 30, 2023. Higher commodity prices in the six months ended June 30, 2024, resulted in realized losses of $398,602 compared to realized losses of $298,655 for the six months ended June 30, 2023. For the six months ended June 30, 2024, unrealized losses were $1,682,123 compared to unrealized gains of $1,061,698 for the six months ended June 30, 2023.

Current wording

We enter into commodity derivatives instruments to manage the price risk attributable to future oil production. We recorded a loss on derivative contracts of $180,063 for the nine months ended September 30, 2024, compared to a loss of $673,057 for the nine months ended September 30, 2023. Higher commodity prices in the nine months ended September 30, 2024, resulted in realized losses of $506,571 compared to realized losses of $899,395 for the nine months ended September 30, 2023. For the nine months ended September 30, 2024, unrealized gains were $326,508 compared to unrealized gains of $226,338 for the nine months ended September 30, 2023.

Previous wording

For the six months ended June 30, 2024, our average realized oil price per barrel after reflecting settled derivatives was $75.07 compared to $72.52, for the six months ended June 30, 2023. For the six months ended June 30, 2024, our settled derivatives decreased our realized oil price per barrel by $3.16 compared to decreasing the price per barrel by $1.64 for the six months ended June 30, 2023. As of June 30, 2024, we ended the period with a $1,214,436 net derivative liability compared to a net asset of $467,687 as of December 31, 2023.

Current wording

For the nine months ended September 30, 2024, our average realized oil price per barrel after reflecting settled derivatives was $73.87 compared to $73.03, for the nine months ended September 30, 2023. For the nine months ended September 30, 2024, our settled derivatives decreased our realized oil price per barrel by $2.56 compared to decreasing the price per barrel by $3.47 for the nine months ended September 30, 2023. As of September 30, 2024, we ended the period with a $794,195 net derivative asset compared to a net asset of $467,687 as of December 31, 2023.

Previous wording

Other revenue was $260,818 for the six months ended June 30, 2024, compared to $317,721 for the six months ended June 30, 2023. The revenue is related to providing water services to a third party. The contract is for one year starting on September 1, 2022, and can be renewed by mutual agreement.

Current wording

Other revenue was $359,270 for the nine months ended September 30, 2024, compared to $461,435 for the nine months ended September 30, 2023. The revenue is related to providing water services to a third party. The contract is for one year starting on September 1, 2022, and can be renewed by mutual agreement.

Previous wording

Lease operating expenses were $4,393,699 for the six months ended June 30, 2024, compared to $4,905,164 for the six months ended June 30, 2023. On a per unit basis, production expenses increased 16% from $23.04 per BOE for the six months ended June 30, 2023, to $29.92 per BOE for the six months ended June 30, 2024, due primarily to increases in proactive maintenance activities.

Current wording

Lease operating expenses were $6,530,431 for the nine months ended September 30, 2024, compared to $7,354,304 for the nine months ended September 30, 2023. On a per unit basis, production expenses increased 18% from $24.12 per BOE for the nine months ended September 30, 2023, to $28.54 per BOE for the nine months ended September 30, 2024, due primarily to increases in proactive maintenance activities.

Previous wording

We pay production taxes, transportation and processing costs based on realized oil and natural gas sales. Production taxes, transportation and processing costs were $837,265 for the six months ended June 30, 2024, compared to $1,171,861 for the six months ended June 30, 2023. As a percentage of oil and natural gas sales, these costs were 8% and 8% in the six months ended June 30, 2024, and 2023, respectively. Production taxes, transportation, and processing as a percent of total oil and natural gas sales are consistent with historical trends.

Current wording

We pay production taxes, transportation and processing costs based on realized oil and natural gas sales. Production taxes, transportation and processing costs were $1,326,789 for the nine months ended September 30, 2024, compared to $1,774,310 for the nine months ended September 30, 2023. As a percentage of oil and natural gas sales, these costs were 9% and 9% in the nine months ended September 30, 2024, and 2023, respectively. Production taxes, transportation, and processing as a percent of total oil and natural gas sales are consistent with historical trends.

Previous wording

Depletion, depreciation and amortization (“DD&A”) was $998,616 for the six months ended June 30, 2024, compared to $858,992 for the six months ended June 30, 2023. DD&A was $6.80 per BOE for the six months ended June 30, 2024 compared to $4.04 per BOE for the six months ended June 30, 2023. The aggregate increase in DD&A expense for the six months ended June 30, 2024, compared to the six months ended June 30, 2023, was driven by the increase in the oil and gas properties balance due the recognition of the reserves at fair value as a result of the acquisition of the Pogo business by the Company on November 15, 2023.

Current wording

Depletion, depreciation and amortization (“DD&A”) was $1,506,242 for the nine months ended September 30, 2024, compared to $1,285,830 for the nine months ended September 30, 2023. DD&A was $6.58 per BOE for the nine months ended September 30, 2024 compared to $4.22 per BOE for the nine months ended September 30, 2023. The aggregate increase in DD&A expense for the nine months ended September 30, 2024, compared to the nine months ended September 30, 2023, was driven by the increase in the oil and gas properties balance due to the recognition of the reserves at fair value as a result of the acquisition of the Pogo business by us on November 15, 2023.

Previous wording

Accretion expense was $73,531 for the six months ended June 30, 2024, compared to $608,634 for the six months ended June 30, 2023. Accretion expense was $0.50 per BOE for the six months ended June 30, 2024, compared to $2.86 per BOE for the six months ended June 30, 2023. The aggregate increase in accretion expense for the six months ended June 30, 2024, compared to the six months ended June 30, 2023, was driven by changes in certain assumptions, specifically the inflation factor and discount rate as a result of the acquisition date where we revised our estimates as part of its fair value estimates for the acquired business on November 15, 2023

Current wording

Accretion expense was $83,926 for the nine months ended September 30, 2024, compared to $809,423 for the nine months ended September 30, 2023. Accretion expense was $0.37 per BOE for the nine months ended September 30, 2024, compared to $2.65 per BOE for the nine months ended September 30, 2023. The aggregate decrease in accretion expense for the nine months ended September 30, 2024, compared to the nine months ended September 30, 2023, was driven by changes in certain assumptions, specifically the inflation factor and discount rate as a result of the acquisition date where we revised our estimates as part of its fair value estimates for the acquired business on November 15, 2023

Previous wording

General and administrative expenses were $4,633,486 for the six months ended June 30, 2024, compared to $2,129,379 for the six months ended June 30, 2023. The increase for general and administrative expenses is primarily due to increased cost of outsourced legal, professional, and accounting services from being a public company, and stock-based compensation in the current period of $1,189,968.

Current wording

General and administrative expenses were $6,868,749 for the nine months ended September 30, 2024, compared to $3,111,130 for the nine months ended September 30, 2023. The increase for general and administrative expenses is primarily due to increased cost of outsourced legal, professional, and accounting services from being a public company, and stock-based compensation in the current period of $1,516,933.

Previous wording

Interest expense was $3,890,899 for the six months ended June 30, 2024, compared to $874,938 for the six months ended June 30, 2023. The Successor period interest expense is driven by the Senior Secured Term loan entered into as part of the Closing, and the Private Notes Payable. The Predecessor interest expense for the six months ended June 30, 2023 relates to the Predecessor’s revolving credit facility outstanding and an increase in the weighted average interest rate. This revolving credit facility was not assumed in the Acquisition. Amortization of financing costs was $1,475,257 and was primarily associated with discount on the Company’s Private Notes Payable.

Current wording

Interest expense was $5,732,747 for the nine months ended September 30, 2024, compared to $1,429,200 for the nine months ended September 30, 2023. The Successor period interest expense is driven by the Senior Secured Term loan entered into as part of the Closing, and the Private Notes Payable. The Predecessor interest expense for the nine months ended September 30, 2023 relates to the Predecessor’s revolving credit facility outstanding and an increase in the weighted average interest rate. This revolving credit facility was not assumed in the Acquisition. Amortization of financing costs was $1,982,958 and was primarily associated with discount on our Private Notes Payable.

Previous wording

The change in fair value of forward purchase agreement consisted of a loss of $325,472 for the six months ended June 30, 2024 for the Successor related to the inputs used in the Company’s fair value estimate of the FPA Put Option. The key inputs to the fair value estimate include the Company’s stock price, which declined during the Successor period, and the likelihood, timing and price of a potential dilutive offering.

Current wording

The change in fair value of forward purchase agreement consisted of a loss of $4,534,766 for the nine months ended September 30, 2024 for the Successor related to the inputs used in our fair value estimate of the FPA Put Option, primarily due to the decline in our stock price on a year to date basis. The key inputs to the fair value estimate include our stock price, which declined during the Successor period, and the likelihood, timing and price of a potential dilutive offering.

Previous wording

The change in fair value of warrant liabilities consisted of a loss of $346,888 for the six months ended June 30, 2024 related to fluctuations in the trading price of the Company’s warrants, a portion of which are accounted for as liabilities due to the redemption provisions in those issued to Private Note holders.

Current wording

The change in fair value of warrant liabilities consisted of a loss of $484,799 for the nine months ended September 30, 2024 related to fluctuations in the trading price of our warrants, a portion of which are accounted for as liabilities due to the redemption provisions in those issued to Private Note holders.

Previous wording

As of June 30, 2024, we had outstanding debt of $25,789,250 under our Senior Secured Term Loan, $15,000,000 under the Seller Promissory Note, and $3,881,750 of outstanding private notes payable. A total of $13,663,823 of this is due within one year, including a $5,000,000 estimated excess cash flow payment under the terms of the Senior Secured Term Loan. As of June 30, 2024, we had $3,063,748 of cash and cash equivalents on hand, of which $2,600,000 is in an escrow account pursuant to the requirements of the Senior Secured Term Loan, and had a working capital deficit of $32,552,654. These conditions raise substantial doubt about our ability to continue as a going concern within one year after the date that the financial statements are issued.

Current wording

As of September 30, 2024, we had outstanding debt of $24,735,391 under our Senior Secured Term Loan, $15,000,000 under the Seller Promissory Note, and $3,875,750 of outstanding private notes payable and $1,019,037 from merchant cash advances. A total of $15,048,293 of this is due within one year, including a $5,000,000 estimated excess cash flow payment under the terms of the Senior Secured Term Loan. As of September 30, 2024, we had $2,746,896 of cash and cash equivalents on hand, of which $2,600,000 is in an escrow account pursuant to the requirements of the Senior Secured Term Loan, and had a working capital deficit of $38,801,444. These conditions raise substantial doubt about our ability to continue as a going concern within one year after the date that the financial statements are issued.

Previous wording

The Company had positive cash flow from operations of $2,250,267 for the six months ended June 30, 2024 and $8,675,037 for the year ended December 31, 2023 on a pro forma basis of the combined Successor and Predecessor periods. Additionally, management’s plans to alleviate this substantial doubt include improving profitability through streamlining costs, maintaining active hedge positions for its proven reserve production, and the issuance of additional shares of Class A common stock through. We have a three-year Common Stock Purchase Agreement with a maximum funding limit of $150,000,000 that can fund our operations and production growth, and be used to reduce liabilities, subject the Company’s Form S-1 Registration Statement, which is in the review process, being declared effective by the Securities and Exchange Commission (“SEC”). However, we may seek additional access to capital and liquidity. We cannot assure you, however, that any additional capital will be available to us on favorable terms or at all. Our capital expenditures could be curtailed if our cash flows decline from expected levels.

Current wording

We had positive cash flow from operations of $3,346,362 for the nine months ended September 30, 2024 and $8,675,037 for the year ended December 31, 2023 on a pro forma basis of the combined Successor and Predecessor periods. Additionally, management’s plans to alleviate this substantial doubt include improving profitability through streamlining costs, maintaining active hedge positions for its proven reserve production, and the issuance of additional shares of Class A Common Stock. We have a three-year Common Stock Purchase Agreement with a maximum funding limit of $150,000,000 that can fund our operations and production growth, and be used to reduce liabilities. Through the date of this filing, we have received $2,464,688 in cash proceeds related to the sale of 1,885,000 shares of common stock under this agreement and expect to continue to utilize it to fund operational needs. We cannot assure you, however, that any additional capital will be available to us on favorable terms or at all. Our capital expenditures could be curtailed if our cash flows decline from expected levels.

Previous wording

Sources and uses of cash for the six months ended June 30, 2024 and 2023, are as follows:

Current wording

Sources and uses of cash for the nine months ended September 30, 2024 and 2023, are as follows:

Previous wording

The decrease in net cash flow provided by operating activities for the six months ended June 30, 2024, as compared to 2023 is primarily due to decreased production volumes, and higher general and administrative and acquisition costs associated with public filings.

Current wording

The decrease in net cash flow provided by operating activities for the nine months ended September 30, 2024, as compared to 2023 is primarily due to decreased production volumes, and higher general and administrative and acquisition costs associated with public filings.

Previous wording

Net cash used in investing activities for the six months ended June 30, 2024 was primarily related to $1,192,769 in development costs for the Company’s reserves. Cash flows used in investing activities in the Predecessor period for the six months ended June 30, 2023 consisted primarily of $4,551,624 of cash paid for oil and gas property costs.

Current wording

Net cash used in investing activities for the nine months ended September 30, 2024 was primarily related to $3,275,667 in development costs for our reserves. Cash flows used in investing activities in the Predecessor period for the nine months ended September 30, 2023 consisted primarily of $4,867,872 of cash paid for oil and gas property costs.

Previous wording

Net cash used by financing activities during the Successor period were primarily related to repayments of the Senior Secured Term Loan of $1,891,454 and Private Notes Payable of $37,750, partially offset by an additional $450,000 in cash proceeds from the Private Notes Payable issued during the six months ended June 30, 2024 Cash flows used in financing activities in the Predecessor period for the six months ended June 30, 2023 consisted primarily of $500,000 in long-term debt repayments.

Current wording

Net cash used by financing activities during the Successor period were primarily related to repayments of the Senior Secured Term Loan of $2,945,312 and Private Notes Payable of $43,750, partially offset by $1,184,272 in cash proceeds from sales of common stock under the Common Stock Purchase Agreement, $967,500 in cash proceeds from merchant cash advances, and an additional $450,000 in cash proceeds from the Private Notes Payable issued during the nine months ended September 30, 2024. Cash flows used in financing activities in the Predecessor period for the nine months ended September 30, 2023 consisted primarily of $2,000,000 in long-term debt repayments.