# Mexco Energy Corp: Form 10-Q for the period ended Dec 31, 2024

- Company: [Mexco Energy Corp](/companies/mxc.md) (CIK 66418)
- Form: 10-Q
- Filed: 2025-02-07
- Accepted by EDGAR: Feb 7, 2025, 16:42 ET
- Period: 2024-12-31
- Accession: 0001493152-25-005426
- Inline XBRL: yes
- Main document: https://www.sec.gov/Archives/edgar/data/66418/000149315225005426/form10-q.htm
- All documents and exhibits: https://www.sec.gov/Archives/edgar/data/66418/000149315225005426/

## Figures reported in this filing

Standardized XBRL line items for the period ended 2024-12-31.

| Line item | Period | Value | XBRL concept |
| --- | --- | ---: | --- |
| Revenue | 3 months, 2024-10-01 to 2024-12-31 | $1.9m | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
| Revenue | 9 months, 2024-04-01 to 2024-12-31 | $5.4m | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
| Operating income | 3 months, 2024-10-01 to 2024-12-31 | $446.4k | us-gaap:OperatingIncomeLoss |
| Operating income | 9 months, 2024-04-01 to 2024-12-31 | $1.2m | us-gaap:OperatingIncomeLoss |
| Interest expense | 3 months, 2024-10-01 to 2024-12-31 | $2.9k | us-gaap:InterestExpenseNonoperating |
| Interest expense | 9 months, 2024-04-01 to 2024-12-31 | $5.0k | us-gaap:InterestExpenseNonoperating |
| Income tax | 3 months, 2024-10-01 to 2024-12-31 | −$18.3k | us-gaap:IncomeTaxExpenseBenefit |
| Income tax | 9 months, 2024-04-01 to 2024-12-31 | $200.0k | us-gaap:IncomeTaxExpenseBenefit |
| Net income | 3 months, 2024-10-01 to 2024-12-31 | $469.1k | us-gaap:NetIncomeLoss |
| Net income | 9 months, 2024-04-01 to 2024-12-31 | $1.1m | us-gaap:NetIncomeLoss |
| Diluted EPS | 3 months, 2024-10-01 to 2024-12-31 | $0.22 | us-gaap:EarningsPerShareDiluted |
| Diluted EPS | 9 months, 2024-04-01 to 2024-12-31 | $0.51 | us-gaap:EarningsPerShareDiluted |
| Basic EPS | 3 months, 2024-10-01 to 2024-12-31 | $0.23 | us-gaap:EarningsPerShareBasic |
| Basic EPS | 9 months, 2024-04-01 to 2024-12-31 | $0.52 | us-gaap:EarningsPerShareBasic |
| Diluted shares (weighted) | 3 months, 2024-10-01 to 2024-12-31 | 2,091,808 shares | us-gaap:WeightedAverageNumberOfDilutedSharesOutstanding |
| Diluted shares (weighted) | 9 months, 2024-04-01 to 2024-12-31 | 2,114,936 shares | us-gaap:WeightedAverageNumberOfDilutedSharesOutstanding |
| Operating cash flow | 9 months, 2024-04-01 to 2024-12-31 | $2.9m | us-gaap:NetCashProvidedByUsedInOperatingActivities |
| Dividends paid | 9 months, 2024-04-01 to 2024-12-31 | $209.0k | us-gaap:PaymentsOfDividends |
| Cash and equivalents | at 2024-12-31 | $910.0k | us-gaap:CashAndCashEquivalentsAtCarryingValue |
| Current assets | at 2024-12-31 | $2.1m | us-gaap:AssetsCurrent |
| Total assets | at 2024-12-31 | $19.5m | us-gaap:Assets |
| Current liabilities | at 2024-12-31 | $582.5k | us-gaap:LiabilitiesCurrent |
| Total liabilities | at 2024-12-31 | $1.5m | us-gaap:Liabilities |
| Shareholders' equity | at 2024-12-31 | $18.0m | us-gaap:StockholdersEquity |

## Management's discussion and analysis

As filed, 23,075 characters.

Unless the context otherwise requires, references to the “Company”, “Mexco”, “we”, “us” or “our” mean Mexco Energy Corporation and its consolidated subsidiaries.

**Cautionary Statements Regarding Forward-Looking Statements.** Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Forward-looking statements include statements regarding our plans, beliefs or current expectations and may be signified by the words “could”, “should”, “expect”, “project”, “estimate”, “believe”, “anticipate”, “intend”, “budget”, “plan”, “forecast”, “predict” and other similar expressions. Forward-looking statements appear throughout this Form 10-Q with respect to, among other things: profitability; planned capital expenditures; estimates of oil and gas production; future project dates; estimates of future oil and gas prices; estimates of oil and gas reserves; our future financial condition or results of operations; and our business strategy and other plans and objectives for future operations. Forward-looking statements involve known and unknown risks and uncertainties that could cause actual results to differ materially from those contained in any forward-looking statement.

While we have made assumptions that we believe are reasonable, the assumptions that support our forward-looking statements are based upon information that is currently available and is subject to change. All forward-looking statements in the Form 10-Q are qualified in their entirety by the cautionary statement contained in this section. We do not undertake to update, revise or correct any of the forward-looking information. It is suggested that these financial statements be read in conjunction with the financial statements and notes thereto included in the Form 10-K.

**Liquidity and Capital Resources.** Historically, we have funded our operations, acquisitions, exploration and development expenditures from cash generated by operating activities, bank borrowings, sales of non-core properties and issuance of common stock. Our primary financial resource is our base of oil and gas reserves. We have pledged our producing oil and gas properties to secure our credit facility. We do not have any delivery commitments to provide a fixed and determinable quantity of its oil and gas under any existing contract or agreement.

Our long-term strategy is on increasing profit margins while concentrating on obtaining reserves with low cost operations by acquiring and developing oil and gas properties with potential for long-lived production. We focus our efforts on the acquisition of royalties and working interests in non-operated properties in areas with significant development potential.

At December 31, 2024, we had working capital of $1,469,195 compared to working capital of $3,259,200 at March 31, 2024, a decrease of $1,790,005 for the reasons set forth below.

### Cash Flows

Changes in the net funds provided by or (used in) each of our operating, investing and financing activities are set forth in the table below:

|  | For the Nine Months Ended December 31, 2024 | 2023 | Change |
| --- | ---: | ---: | ---: |
| Net cash provided by operating activities | $2,941,115 | $3,374,717 | $(433,602) |
| Net cash used in investing activities | $(3,670,019) | $(1,365,030) | $2,304,989 |
| Net cash used in financing activities | $(834,575) | $(666,520) | $168,055 |

**Cash Flow Provided by Operating Activities.** Cash flow from operating activities is primarily derived from the production of our crude oil and natural gas reserves and changes in the balances of non-cash accounts, receivables, payables or other non-energy property asset account balances. Cash flow provided by our operating activities for the nine months ended December 31, 2024 was $2,941,115 in comparison to $3,374,717 for the nine months ended December 31, 2023. This decrease of $433,602 in our cash flow operating activities consisted of an increase in our accounts receivable of $529,751; an increase of $106,391 of our accounts payable and accrued expenses and income tax payable; and, a decrease in our net income for the current nine months of $3,287. Variations in cash flow from operating activities may impact our level of exploration and development expenditures.

Our expenditures in operating activities consist primarily of drilling expenses, production expenses and engineering services. Our expenses also consist of employee compensation, accounting, insurance and other general and administrative expenses that we have incurred in order to address normal and necessary business activities of a public company in the crude oil and natural gas production industry.

**Cash Flow Used in Investing Activities.** Cash flow from investing activities is derived from changes in oil and gas property balances. For the nine months ended December 31, 2024, we had net cash of $3,670,019 used for additions to oil and gas properties compared to $1,365,030 for the nine months ended December 31, 2023.

**Cash Flow Provided by Financing Activities.** Cash flow from financing activities is derived from our changes in long-term debt and in equity account balances. Net cash flow used in our financing activities was $834,575 for the nine months ended December 31, 2024 compared to cash flow used in our financing activities of $666,520 for the nine months ended December 31, 2023. During the nine months ended December 31, 2024, we expended $209,000 to pay the regular annual dividend and $703,216 to purchase 57,766 shares of our stock for the treasury account and received $77,641 from the exercise of stock options.

Accordingly, net cash decreased $1,563,479, leaving cash and cash equivalents on hand of $910,005 as of December 31, 2024.

### Oil and Natural Gas Property Development

**New Participations in Fiscal 2025.** The Company currently plans to participate in the drilling and completion of 28 horizontal wells at an estimated cost of approximately $1,500,000 for the fiscal year ending March 31, 2025. Twenty-five of these wells are in the Delaware Basin located in the western portion of the Permian Basin in Lea and Eddy Counties, New Mexico. The remaining 3 wells are in Grady County, Oklahoma.

During the first nine months of fiscal 2025, Mexco expended approximately $207,000 to participate in the drilling of five horizontal wells in the Bone Spring formation of the Delaware Basin in Lea County, New Mexico. In November 2024, these wells were completed with initial average production rates of 1,106 barrels of oil, 2,583 barrels of water and 1,165,000 cubic feet of gas per day, or 1,300 BOE per day.

During the first nine months of fiscal 2025, Mexco expended approximately $293,000 to drill and complete four horizontal wells in the Wolfcamp Sand formation of the Delaware Basin in Lea County, New Mexico. In November 2024, these wells were completed with initial average production rates of 1,089 barrels of oil, 4,716 barrels of water and 3,601,000 cubic feet of gas per day, or 1,689 BOE per day.

In October 2024, the Company expended approximately $74,000 for the drilling of two horizontal wells in the Bone Spring Sand formation of the Delaware Basin in Lea County, New Mexico. Mexco’s working interest in these wells is .5%. Subsequently, in January 2025, the Company expended approximately $43,000 to complete these wells.

In November 2024, the Company expended approximately $78,000 for the drilling of two horizontal wells in the Penn Shale formation of the Delaware Basin in Lea County, New Mexico. Mexco’s average working interest in these wells is .5%.

In October 2022, the Company made an approximately 2% equity investment commitment in a limited liability company amounting to $2,000,000 of which $1,600,000 has been funded as of December 31, 2024. The limited liability company is capitalized at approximately $100 million to purchase mineral interests in the Utica and Marcellus areas in the state of Ohio. To date, this LLC has returned $182,767 or 11% of the total investment.

**Completion of Wells Drilled in Fiscal 2024.** The Company expended approximately $300,000 for the completion of 19 horizontal wells in which the Company participated during fiscal 2024.

The Company expended approximately $107,000 for the completion costs of two horizontal wells in the Bone Spring Sand formation of the Delaware Basin in Lea County, New Mexico that the Company participated in drilling during fiscal 2024. Mexco’s working interest in these wells is .53%. In July 2024, these wells were completed with initial average production rates of 1,402 barrels of oil, 2,009 barrels of water and 2,168,000 cubic feet of gas per day, or 1,763 BOE per day.

Five horizontal wells in the Bone Spring Sand formation of the Delaware Basin in Lea County, New Mexico in which the Company participated during fiscal 2024 were completed in April 2024 with initial average production rates of 732 barrels of oil, 1,481 barrels of water and 657,000 cubic feet of gas per day, or 842 of oil equivalent per day. Mexco’s working interest in these wells is approximately 1.16%.

A horizontal well in the Penn Shale formation of the Delaware Basin in Lea County, New Mexico was completed in May 2024 with the initial production rate of 964 barrels of oil, 2,441 barrels of water and 626,000 cubic feet of gas per day, or 1,068 of oil equivalent per day. Mexco’s working interest in this well is .165%.

The Company expended approximately $207,000 for the completion costs of four horizontial wells in the Bone Spring Sand formation of the Delaware Basin in Lea County, New Mexico that the Company participated in drilling during fiscal 2024. Mexco’s working interest in these wells is .45%. In October 2024, these wells were completed with initial average production rates of 893 barrels of oil, 2,990 barrels of water and 1,161,000 cubic feet of gas per day, or 1,087 BOE per day.

**Acquisitions.** In April 2024, the Company acquired royalty interests in 21 producing wells operated by Anadarko Petroleum Corporation and Cimarex Energy Company and located in Reeves County, Texas for a purchase price of $158,000.

In August 2024, the Company acquired royalty interests in 6 producing wells operated by Marathon Oil and located in Karnes County, Texas for a purchase price of $50,000. This acquisition was effective August 1, 2024.

In August 2024, the Company acquired royalty interests in 15 producing wells operated by Anadarko Petroleum Corporation and located in Weld County, Colorado for a purchase price of $118,000; and, royalty interests in approximately 250 producing wells operated by Samson Exploration, EOG Resources and others in Laramie County, Wyoming and Adams and Weld Counties, Colorado for a purchase price of $483,000. All of these acquisitions were effective September 1, 2024.

In September 2024, the Company acquired royalty interests in 20 producing wells operated by Marathon Oil and Murphy Exploration and located in Karnes County, Texas for a purchase price of $90,000 and effective August 1, 2024.

In October 2024, the Company acquired a .3% royalty interest in 15 producing wells operated by Civitas Resources, Inc. and located in Broomfield and Adams Counties, Colorado for a purchase price of $450,000. This acquisition was effective November 1, 2024.

In October 2024, the Company acquired a .5% royalty interest in 3 producing wells operated by Mewbourne Oil Company and located in Eddy County, New Mexico for a purchase price of $260,000. This acquisition was effective November 1, 2024 and includes acreage for further development.

In October 2024, the Company acquired royalty interests in 8 producing wells operated by Marathon Oil and located in Live Oak County, Texas for a purchase price of $20,000; royalty interests in 6 producing wells operated by SWN Production Company, LLC and located in DeSoto Parish, Louisiana for a purchase price of $25,000; royalty interests in 10 producing wells operated by Ovintiv, Inc. and located in Upton County, Texas for a purchase price of $65,000; and, royalty interests in 12 producing wells operated by Pioneer Natural Resources and located in Reagan and Upton Counties, Texas for a purchase price of $65,000. All of these acquisitions were effective November 1, 2024.

Also in October 2024 and effective November 1, 2024, the Company acquired various small royalty interests in over 300 producing wells operated by Petro-Hunt Corporation, Hess Bakken Investments II, LLC, Marathon Oil, WPX Energy and others in multiple counties throughout the states of Nebraska, North Dakota, South Dakota and Montana for a purchase price of $185,000.

**Other Projects.** We are participating in other projects and are reviewing projects in which we may participate. The cost of such projects would be funded, to the extent possible, from existing cash balances and cash flow from operations. The remainder may be funded through borrowings on the credit facility and, if appropriate, sales of non-core properties.

**Sale of Properties.** In November 2024, the Company conveyed its working and royalty interests in 13.5 net acres in Ward County, Texas. The Company received $15,000 per acre in the total amount of $202,500. The Company retained an overriding royalty interest equal to the positive difference between 25% and any existing burdens of record as of the effective date. The divestitures of this non-core oil and gas asset did not result in a significant alteration of the relationship between the Company’s capitalized costs and proved reserves and, accordingly, the Company recorded the proceeds as sales proceeds, a reduction of its full cost pool, with no gain or loss recognized on the sale.

**Pricing.** Crude oil and natural gas prices generally remained volatile during the last year. The volatility of the energy markets makes it extremely difficult to predict future oil and natural gas price movements with any certainty. For example, in the last twelve months, the NYMEX West Texas Intermediate (“WTI”) posted price for crude oil has ranged from a low of $61.73 per bbl in September 2024 to a high of $82.89 per bbl in April 2024. The Henry Hub Spot Market Price (“Henry Hub”) for natural gas has ranged from a low of $1.21 per MMBtu in November 2024 to a high of $3.40 per MMBtu in December 2024.

On December 31, 2024, the WTI posted price for crude oil was $67.70 and the Henry Hub spot price for natural gas was $3.40 per MMBtu. See Results of Operations below for realized prices. Pipeline capacity constraints and maintenance in the Permian Basin area has contributed to a wider difference between the WaHa Hub and the Henry Hub and at times prices were negative.

**Contractual Obligations.** We have no off-balance sheet debt or unrecorded obligations and have not guaranteed the debt of any other party. The following table summarizes our future payments we are obligated to make based on agreements in place as of December 31, 2024:

| Contractual obligations: | Total | Payments due in: less than 1 year | 1 - 3 years | over 3 years |
| --- | ---: | ---: | ---: | ---: |
| Leases (1) | $155,827 | $60,320 | $95,507 | $- |

(1) The lease amount represents the monthly rent amount for our principal office space in Midland, Texas under a 36-month lease agreement expiring July 31, 2027. Of this total obligation for the remainder of the lease, our majority shareholder will pay $10,175 less than 1 year and $16,110 1-3 years for his portion of the shared office space.

**Results of Operations – Three Months Ended December 31, 2024 and 2023.** For the quarter ended December 31, 2024, there was net income of $469,133 compared to $345,610 for the quarter ended December 31, 2023 as a result of an increase in operating revenues due to a increase in oil and gas production volumes partially offset by a decrease in oil and gas prices and an increase in operating expenses that is further explained below.

*Oil and gas sales*. Revenue from oil and gas sales was $1,828,404 for the third quarter of fiscal 2025, a 14% increase from $1,610,595 for the same period of fiscal 2024. This resulted from an increase in oil and natural gas production volumes partially offset by a decrease in oil and natural gas prices. Natural gas prices have been negatively impacted by limited pipeline capacity in the Permian Basin.

| Oil: | 2024 | 2023 | % Difference |
| --- | ---: | ---: | ---: |
| Revenue | $1,563,663 | $1,387,008 | 12.7% |
| Volume (bbls) | 22,451 | 17,636 | 27.3% |
| Average Price (per bbl) | $69.65 | $78.65 | (11.4)% |
| Gas: |  |  |  |
| Revenue | $264,741 | $223,587 | 18.4% |
| Volume (mcf) | 149,945 | 122,794 | 22.1% |
| Average Price (per mcf) | $1.77 | $1.82 | (2.7)% |

*Other operating revenues.* Other revenues increased to $62,861 for the three months ended December 31, 2024, from $45,848 for the three months ended December 31, 2023. This increase resulted from a settlement in a class action lawsuit from Contango Resources and an increase in income from one of our limited liability company investments.

*Interest income.* Interest income on corporate funds decreased to $7,315 for the three months ended December 31, 2024, from $36,936 for the three months ended December 31, 2023. This decrease resulted from using the corporate funds for property acquisitions.

*Production and exploration.* Production costs were $460,241 for the third quarter of fiscal 2025, a 15% increase from $401,035 for the same period of fiscal 2024. This is the result of an increase in production taxes due to an increase in oil revenues and an increase in marketing and other charges due to the current natural gas pricing environment from limited pipeline takeaway capacity in the Permian and an increase in lease operating expenses on new wells in which we own an interest.

*Depreciation, depletion and amortization.* Depreciation, depletion and amortization expense was $636,424 for the third quarter of fiscal 2025, a 59% increase from $400,337 for the same period of fiscal 2024, primarily due to an increase in the full cost amortization base, an increase in oil and gas production and a decrease in gas reserves partially offset by a increase in oil reserves.

*General and administrative expenses.* General and administrative expenses were $340,514 for the third quarter of fiscal 2025, a 2% increase from $335,152 for the same period of fiscal 2024. This was primarily due to an increase in contract services.

*Income taxes.* There was an income tax benefit of $18,305 for the three months ended December 31, 2024 compared to an expense of $202,945 for the three months ended December 31, 2023, primarily due to a decrease in state income taxes and a decrease in the deferred tax provision. The effective tax rate for state and federal taxes combined for the three months ended December 31, 2024 and 2023 was (4%) and 37%, respectively. The decrease in the effective tax rate is primarily the result of state income taxes net of federal benefit, primarily in New Mexico, and the impact of permanent differences between book and taxable income.

**Results of Operations – Nine Months Ended December 31, 2024 and 2023.** For the nine months ended December 31, 2024, there was a net income of $1,077,370 compared to net income of $1,080,657 for the nine months ended December 31, 2023. This was a result of an increase in operating revenues due to an increase in oil and gas production volumes partially offset by a decrease in oil and gas prices and an increase in operating expenses that is further explained below.

*Oil and gas sales*. Revenue from oil and gas sales was $5,212,313 for the nine months ended December 31, 2024, an 11% increase from $4,706,395 for the same period of fiscal 2024. This resulted from a increase in oil and natural gas production partially offset by a decrease in oil and natural gas prices. Natural gas prices have been negatively impacted by pipeline capacity in the Permian Basin.

| Oil: | 2024 | 2023 | % Difference |
| --- | ---: | ---: | ---: |
| Revenue | $4,595,585 | $3,916,792 | 17.3% |
| Volume (bbls) | 61,685 | 50,826 | 21.4% |
| Average Price (per bbl) | $74.50 | $77.06 | (3.3)% |
| Gas: |  |  |  |
| Revenue | $616,728 | $789,903 | (21.9)% |
| Volume (mcf) | 420,236 | 372,459 | 12.8% |
| Average Price (per mcf) | $1.47 | $2.12 | (30.7)% |

*Other operating revenues.* Other revenues increased to $156,014 for the nine months ended December 31, 2024, from $105,077 for the nine months ended December 31, 2023. This increase resulted from a settlement in a class action lawsuit from Contango Resources and an increase in income from one of our limited liability company investments.

*Interest income.* Interest income on corporate funds decreased to $50,891 for the nine months ended December 31, 2024, from $86,995 for the nine months ended December 31, 2023. This decrease resulted from using the corporate funds for property acquisitions and purchase of treasury stock.

*Production and exploration.* Production costs were $1,311,066 for the nine months ended December 31, 2024, a 15% increase from $1,143,116 for the nine months ended December 31, 2023. This is the result of an increase in production taxes due to an increase in oil revenues and an increase in marketing and other charges due to the current natural gas pricing environment from limited pipeline takeaway capacity in the Permian and an increase in lease operating expenses on new wells in which we own an interest.

*Depreciation, depletion and amortization.* Depreciation, depletion and amortization expense was $1,760,409 for the nine months ended December 31, 2024, a 39% increase from $1,268,703 for the nine months ended December 31, 2023, primarily due to an increase in the full cost amortization base, an increase in oil and gas production and a decrease in gas reserves partially offset by an increase in oil reserves.

*General and administrative expenses.* General and administrative expenses were $1,042,084 for the nine months ended December 31, 2024, a 6% increase from $981,664 for the nine months ended December 31, 2023. This was primarily due to an increase in contract and engineering services partially offset by a decrease in salaries and stock option compensation.

*Income taxes.* Income taxes for the nine months ended December 31, 2024 was $200,034 compared to $398,971 for the nine months ended December 31, 2023, primarily due a decrease in state income taxes and a decrease in the deferred tax provision. The effective tax rate for state and federal taxes combined for the nine months ended December 31, 2024 and 2023 was 16% and 27%, respectively. The decrease in the effective tax rate is primarily the result of state income taxes net of federal benefit, primarily in New Mexico, and the impact of permanent differences between book and taxable income.

## Market risk

As filed, 4,003 characters.

The primary sources of market risk for us include fluctuations in commodity prices and interest rates. All of our financial instruments are for purposes other than trading.

**Credit Risk.** Credit risk is the risk of loss as a result of nonperformance by other parties of their contractual obligations. Our primary credit risk is related to oil and gas production sold to various purchasers and the receivables are generally not collateralized. At December 31, 2024, our largest credit risk associated with any single purchaser was $520,794 or 50% of our total oil and gas receivables. We have not experienced any significant credit losses.

**Energy Price Risk.** Our most significant market risk is the pricing applicable to our crude oil and natural gas production. Our financial condition, results of operations, and capital resources are highly dependent upon the prevailing market prices of, and demand for, oil and natural gas. Prices for oil and natural gas production has been volatile and unpredictable for several years, and we expect this volatility to continue in the future.

Pipeline capacity constraints and maintenance in the Permian Basin area has contributed to a wider difference between the WaHa Hub and the Henry Hub and at times prices were negative.

Factors that can cause price fluctuations include the level of global demand for petroleum products, foreign and domestic supply of oil and gas, the establishment of and compliance with production quotas by oil-exporting countries, weather conditions, the price and availability of alternative fuels and overall political and economic conditions in oil producing and consuming countries.

For example, in the last twelve months, the NYMEX West Texas Intermediate (“WTI”) posted price for crude oil has ranged from a low of $61.73 per bbl in September 2024 to a high of $82.89 per bbl in April 2024. The Henry Hub Spot Market Price (“Henry Hub”) posted price for natural gas has ranged from a low of $1.21 per MMBtu in November 2024 to a high of $3.40 per MMBtu in December 2024. On December 31, 2024, the WTI posted price for crude oil was $67.70 and the Henry Hub posted price for natural gas was $3.40. See Results of Operations above for the Company’s realized prices during the three and nine months. Subsequently, on January 27, 2025, the WTI posted price for crude oil was $69.15 and the Henry Hub posted price for natural gas was $3.71.

Declines in oil and natural gas prices will materially adversely affect our financial condition, liquidity, ability to obtain financing and operating results. Changes in oil and gas prices impact both estimated future net revenue and the estimated quantity of proved reserves. Any reduction in reserves, including reductions due to price fluctuations, can reduce the borrowing base under our credit facility and adversely affect the amount of cash flow available for capital expenditures and our ability to obtain additional capital for our acquisition, exploration and development activities. In addition, a noncash write-down of our oil and gas properties could be required under full cost accounting rules if prices declined significantly, even if it is only for a short period of time. Lower prices may also reduce the amount of crude oil and natural gas that can be produced economically. Thus, we may experience material increases or decreases in reserve quantities solely as a result of price changes and not as a result of drilling or well performance.

Similarly, any improvements in oil and gas prices can have a favorable impact on our financial condition, results of operations and capital resources. If the average oil price had increased or decreased by ten dollars per barrel for the first nine months of fiscal 2025, our operating revenues would have increased or decreased $616,850. If the average gas price had increased or decreased by one dollar per mcf for the first nine months of fiscal 2025, our operating revenues would have increased or decreased $420,236.

## Controls and procedures

As filed, 920 characters.

**Evaluation of Disclosure Controls and Procedures.** We maintain disclosure controls and procedures to ensure that the information we must disclose in our filings with the SEC is recorded, processed, summarized and reported on a timely basis. At the end of the period covered by this report, our principal executive officer and principal financial officer reviewed and evaluated the effectiveness of our disclosure controls and procedures, as defined in Exchange Act Rules 13a-15(e). Based on such evaluation, such officers concluded that, as of December 31, 2024, our disclosure controls and procedures were effective.

**Changes in Internal Control over Financial Reporting.** No changes in our internal control over financial reporting occurred during the nine months ended December 31, 2024 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

## Risk factors

As filed, 142 characters.

There have been no material changes to the information previously disclosed in Item 1A. “Risk Factors” in our 2024 Annual Report on Form 10-K.

Filed Feb 7, 2025.
Source: SEC EDGAR, the filing index for accession 0001493152-25-005426. Last ingested by Listed: Nov 13, 2026, 16:49 ET. No prices; not investment advice.