HALLADOR ENERGY CO

Previous wording

The Company continued to leverage the strong relationships we built with multiple counterparties, allowing us to supplement periods of weaker pricing with limited sales of firm energy. These firm energy sales help to mitigate the impacts of inconsistent weather and fluctuating natural gas prices and allowed us to focus on maximizing the value of our Merom Power Plant in a way that balances challenging periods while also giving us flexibility to capture upside opportunity in periods of elevated pricing, like we saw throughout January and February.

Current wording

The Company continued its strategy of supplementing periods of weaker pricing with limited sales of firm energy. These firm energy sales help to mitigate the impacts of inconsistent weather and fluctuating energy prices and allowed us to focus on maximizing the value of Merom in a way that balances challenging periods while also giving us flexibility to capture upside opportunity in periods of elevated pricing, like we saw in June. In late June, we expanded our relationship with one of our firm energy counterparties, entering into a $35.0 million prepaid forward power sales contract with energy to be delivered at various periods throughout 2025 and 2026. In connection with this agreement, we also entered into the Third Amendment to our Credit Amendment, which moved the required Term Loan payment from October 2025 to January 2026 and adjusted various covenants to provide additional operating flexibility throughout the summer and into the fourth quarter. The prepaid funds will be used in a variety of ways, including fully cash collateralizing the outstanding $19.0 million Term Loan principal balance under the Credit Agreement and to support company operations.

Previous wording

In the past, we highlighted our belief that the prevailing industry trend of retiring dispatchable generators, including coal, in favor of non-dispatchable resources such as wind and solar will lead to an unbalanced energy equation and extended volatility in the energy markets. We believe this volatility has the potential to make the attributes of our subsidiary, Hallador Power, much more valuable due to the enhanced reliability we provide versus non-dispatchable generators. In light of this, we continue to evaluate how to further enhance this value. Consistent with this belief, we are actively seeking opportunities to acquire additional dispatchable generation, which should help diversify our risk and provide opportunities to upsize the strategic deals that we continue to evaluate. We believe that this approach enhances our financial flexibility and strengthens our position in the evolving energy market.

Current wording

Over the last several quarters, we have highlighted our belief that the prevailing industry trend of retiring dispatchable generators, including coal, in favor of non-dispatchable resources such as wind and solar will create an unbalanced energy equation, reduce reliability and increase long-term volatility in the energy markets. It is our position that the enhanced reliability of dispatchable generation, like Merom, versus non-dispatchable generators will increase the value of the attributes of Hallador Power in the overall energy markets. In light of this, we continue to evaluate how to further enhance this value. As we have previously discussed, we are actively seeking acquisition opportunities for additional dispatchable generation, which we believe will help diversify our risk and provide opportunities to upsize strategic future

Previous wording

We continue to study the benefits of not only adding additional generation through acquisition or expansion, but the potential of enhancing the reliability, resiliency and flexibility of our current plant by adding natural gas co-firing and creating a dual fuel scenario. While we are still in the evaluation process, and we recognize the tremendous amount of work that is required to accomplish such a transition, by adding the capability to co-fire with gas or coal, we believe that it will lead to opportunities where the counterparty desires to limit the amount of coal fired electricity that they are purchasing, while also providing Hallador the ability to take advantage of the best fuel cost scenario and better control our operating expenses across multiple fuel scenarios. Additionally, we believe that the ability to co-fire with natural gas

Current wording

Additionally, we see the potential of enhancing the reliability, resiliency and flexibility of Merom by adding natural gas and creating a dual fuel scenario, if and when the opportunity makes operational and financial sense. While we are still in the evaluation process, by adding the capability to co-fire with gas or coal, we believe that it could provide Hallador Power the ability to take advantage of the best fuel cost scenario and better control our operating expenses. We believe that the ability to co-fire with natural gas and/or coal will also provide increased resiliency in times where gas availability is traditionally limited, as we have seen in various winter storms across the last several years. This co-firing also allows us to retain the advantage of operating our Sunrise Coal subsidiary and leveraging our own coal supply to prevent unreasonable price increases by third party providers while simultaneously supporting our workforce and the surrounding community. This evaluation is complex on a variety of levels, specifically customer preference and an evolving regulatory environment that could have material impacts on the timing and economic benefits of undertaking such a change.

Previous wording

We believe that our approach should allow Hallador Power to capture higher prices and energy volumes in the future versus what we have historically achieved since buying the plant in late 2022, specifically as we look to 2027 and beyond. Following the end of the quarter, we completed maintenance on one of the units at the plant and now have that unit back in service. We currently have a second unit out of service for scheduled maintenance and expect that unit to be back online early in the third quarter. We typically choose the shoulder season periods for these scheduled maintenance outages as power demand and pricing in spring are traditionally lower than in other parts of the year. We also try to limit our firm electricity sales during these periods to guard against any unforeseen or forced outages, which have the potential to expose us to spot market pricing. Despite these outages, we have contracted approximately 3.0 million MWh for the remainder of 2025 at an average price of $37.20/MWh, which should help to smooth our exposure to the spot market throughout the remainder of the year. For 2026, we currently have contracted 3.4 million MWh at an average sales price of $44.43/MWh and continue to see high demand. Following 2026, we are optimistic that we can sell energy at higher prices in support of data center development and/or to traditional wholesale customers in line with the indicators of a higher forward curve.

Current wording

We continue to invest in the future of the plant through extensive maintenance and capital expenditures. We had one unit out of service for planned maintenance for most of the quarter and extending into early third quarter. We typically choose the shoulder season periods for these planned maintenance outages as power demand and pricing in spring are traditionally lower than in other parts of the year. We also try to limit our firm energy sales during these periods to guard against any unforeseen or forced outages, which have the potential to expose us to spot market pricing. Despite the outage, we saw stronger than expected prices in June, which we were able to take advantage of with the unit that remained online. As illustrated in the solid forward sales position table below, in 2026, we currently have 4.0 million delivered energy MWh contracted at an average sales price of $43.05 per MWh. We continue to see higher demand and increase in our average contracted sales price. Our largest PPA contract will see an increase of more than $20.00 per MWh in 2026 as compared to 2025 on expected volumes of approximately 1.6 million MWh. Following 2026, we are optimistic that we will be able to sell energy at higher prices in support of data center development and/or to traditional wholesale customers in line with the indicators of a strong forward curve.

Previous wording

As we said on March investor call, we continue to evaluate other strategic transactions that could add durability, scale, and geographic expansion opportunities to our electric operations. We believe that Hallador is uniquely positioned to transform retiring and/or underperforming assets into future opportunities. This will enable us to supply high demand end users, such as data centers and on-shored industrial customers, with minimal impact to retail consumers. By continuing the operations of the dispatchable plants to support large load industrial users as the utilities transition to non-dispatchable generation, the new generation becomes additive to the struggling grid rather than cannibalizing the overall reliability of what exists today. We are optimistic about the potential to add to our strategic portfolio and the long-term benefits that such a transaction could produce for the company, its shareholders and its customers. This model for growth enables us to continue our shift away from the less favorable pricing related to plant acquisition, to traditional wholesale market pricing, and ultimately to the enhanced pricing associated with supporting data centers and other large load end users. Importantly, the positive momentum that we are seeing from the current administrations on both the federal and state levels should make transactions of this sort more feasible than they would have been under the prior administrations.

Current wording

We believe that Hallador is uniquely positioned to transform retiring and/or underperforming assets into future opportunities. This will enable us to supply high demand end users, such as data centers and on-shored industrial customers, with minimal impact to retail consumers, unlike a traditional utility siphoning off consumer power to serve these types of large load end-users. By continuing the operations of the dispatchable plants to support large load industrial users as the utilities transition to non-dispatchable generation, the new generation becomes additive to the already struggling grid rather than cannibalizing the overall reliability of what exists today. We remain optimistic about the potential to add to our strategic portfolio and the long-term benefits that such a transaction could produce for the company, its shareholders and its customers. This model for growth enables us to capture value from the critical factors limiting artificial intelligence and data center growth, accredited capacity and reliable and affordable energy. Importantly, the positive momentum that we continue to see from the current administration on both the federal and state levels should make transactions of this sort more feasible than they would have been under the prior administration.

Previous wording

Shifting to our coal operations, we continue to see improvements from the restructuring of our Sunrise Coal division that we initially announced in the first quarter of 2024. We spent much of last year optimizing production, headcount, and strategy to best support our electric operations and our existing third-party coal contracts. As we look to the future, this restructuring should provide us with greater flexibility to quickly scale if we see coal prices increase to a point that justifies restarting production at our more expensive units.

Current wording

Shifting to our Coal Operations, we continue to see the benefits of our 2024 organizational restructuring. While much of the last year was focused on optimizing production, headcount, and strategy to best support our Electric Operations and our existing third-party coal contracts, we have seen improved operational expenses, more efficient recoveries and accelerating shipments. As we have said before, this organizational restructuring should provide us with greater flexibility to quickly scale if we see coal prices increase to a point that justifies restarting production at higher cost units. Additionally, while our coal inventories are elevated, we believe that we are well-positioned to meet industry needs in the event that coal plants, including Merom, continue to dispatch at higher levels.

Previous wording

With renewed support of coal mining and coal fired power generation on both the federal and state level, we believe that we are positioned well to take advantage of opportunities for growth and/or expansion. Current market dynamics have improved over where they were last year, and if this trend continues, it has the potential to encourage us to bring on additional coal production in the back half of 2025 and/or 2026. Notwithstanding this potential to increase production, we currently expect to produce approximately 3.8 million tons of coal in 2025. In the first quarter of 2025, we produced approximately 1.0 million tons of coal at our Oaktown Mining Complex and shipped approximately 1.1 million** **tons to Merom and other customers. We use supplemental coal from third party suppliers typically purchased at favorable prices to diversify self-production supply risk and to provide us additional flexibility in our sales portfolio. The optionality to

Current wording

Notwithstanding this potential to increase production, we currently expect to produce approximately 3.7 million tons of coal in 2025. In the first half of 2025, we produced approximately 2.1 million tons of coal at our Oaktown Mining Complex. We use supplemental coal from third party suppliers at Merom, typically purchased at favorable prices to help diversify self-production supply risk and to provide us additional flexibility in our sales portfolio if prices increase on the spot market. This optionality to obtain low-cost tons either internally or from third-parties while capturing upward swings in the commodity markets for coal should allow us to further maximize margins while optimizing fuels costs at Merom.

Previous wording

Our goal is for Hallador Power to generate on average 1.5 million MWh on a quarterly basis, which equates to 6.0 million MWh annually (see Hallador Power’s capacity and utilization information below). During the first three months of the year, Hallador Power generated 1.4 million MWh, or 93.3% or our quarterly target and purchased 0.2 million MWh.

Current wording

Our goal is for Hallador Power to generate on average 1.5 million MWh on a quarterly basis, which equates to 6.0 million MWh annually (see Hallador Power’s capacity and utilization information below). During the first six months of the year, Hallador Power generated 2.2 million MWh, or 73.3% of our quarterly target and purchased 0.2 million MWh.

Previous wording

When forward selling Capacity, we target annual sales of around $65.0 million to offset our fixed annual costs at the plant of approximately $60.0 million. For 2025, we have contracted approximately $56.0 million or 86.2% of our target with $45.5 million remaining to be delivered in 2025. We believe our forward Capacity sales goals are attainable as illustrated in our “Solid Forward Sales Position” table below.

Current wording

When forward selling Capacity, we target annual sales of around $65.0 million to offset our fixed annual costs at the plant of approximately $60.0 million. For 2025, we have contracted approximately $56.0 million or 86.2% of our target. We believe our forward Capacity sales goals are attainable as illustrated in our “Solid Forward Sales Position” table below.

Previous wording

For the three months ended March 31, 2025, capex was $11.7 million allocated as follows (in millions):

Current wording

For the six months ended June 30, 2025, capex was $24.8 million allocated as follows (in millions):

Previous wording

Income before income taxes increased $4.1 million, or 27.3%, compared to the first quarter of 2024. The main drivers of this change in income before income taxes are described in the discussion above.

Current wording

Income before income taxes increased $5.0 million, or 75.3%, compared to the second quarter of 2024. The main drivers of this change in income before income taxes are described in the discussion above.

Previous wording

Cost of purchased power was $4.9 million during the first quarter of 2025. When energy hours at the Merom Hub are priced below our production cost or during outages at our Merom Facility, we have the option to make net hourly purchases of power in the MISO market, which we record as cost of purchased power. During the first quarter of 2025, we purchased 0.2 million MWh, an increase of 90.7% from Q1 2024, at an average price of $47.83 per MWh.

Current wording

The cost of purchased power increased $4.5 million, or 98.3%, compared to year-to-date 2024. On a per MWh basis, cost of purchased power increased $1.14, or 43.3%. When energy hours at the Merom Hub are priced below our production cost or during outages at Merom, we have the option to make net hourly purchases of power in the MISO market, which we record as cost of purchased power.

Previous wording

Interest expense decreased $1.2 million, or 38.0%, compared to the first quarter of 2024. Our decreased interest expense relates to reductions of convertible debt of $11.0 million, related party debt of $5.0 million and bank debt of $54.0 million, from Q1 2024.

Current wording

Interest expense decreased $1.3 million, or 39.5%, compared to the second quarter of 2024. On a per ton basis, interest expense decreased $1.59, or 42.3%. Our decreased interest expense relates to reductions of convertible debt of $11.0 million and related party debt of $5.0 million.

Previous wording

Coal sales decreased $11.3 million, or 17.1%, compared to the first quarter of 2024. Consolidated coal sales decreased $19.4 million, or 39.2%, from 2024. These declines were due to reductions in volume and average sales price for our coal. Our average sales price, on a segment basis, decreased $3.25 per ton and we sold 0.1 million tons less compared to 2024. Our average sales price, on a consolidated basis, for 2025 decreased $4.22 per ton and we sold 0.3 million tons less compared to 2024. Operating revenues for the first quarter of 2025 include $24.6 million in sales to the Merom plant which were eliminated in the consolidation.

Current wording

Coal sales decreased $11.4 million, or 10.2%, compared to the first six months of 2024. On a per ton basis, coal sales decrease $3.02, or 5.6%. Consolidated coal sales decreased $14.1 million, or 17.1% from 2024. These declines were due to reductions in volume and average sales price for our coal. Our average sales price, on a segment basis, decreased $2.99 per ton and we sold 0.1 million tons less compared to 2024. Our average sales price, on a consolidated basis for 2025 decreased $4.27 per ton and we sold 0.2 million tons less compared to 2024.

Previous wording

Loss before income taxes decreased $9.6 million, or 65.4%, compared to the first quarter of 2024. The main drivers of this change in loss before income taxes are described in the discussion above.

Current wording

Loss before income taxes decreased $25.5 million, or 87.4%, compared to the first six months of 2024. The main drivers of this change in loss before income taxes are described in the discussion above.

Previous wording

Our effective tax rate (ETR) is estimated at ~0% and ~26% for the three months ended March 31, 2025 and 2024, respectively. For the three months ended March 31, 2025, we estimated our annual ETR based upon projected annual income (loss), forecasted permanent tax differences, discrete items, and statutory rates in states in which we operate. Our ETR differs from the statutory rate due primarily to statutory depletion in excess of tax basis and changes in the valuation allowance. The deduction for statutory percentage depletion does not necessarily change proportionately to changes in income (loss) before income taxes.

Current wording

Our effective tax rate (ETR) is estimated at ~0% and ~23% for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025, we estimated our annual ETR based upon projected annual income (loss), forecasted permanent tax differences, discrete items, and statutory rates in states in which we operate. Our ETR differs from the statutory rate due primarily to statutory depletion in excess of tax basis and changes in the valuation allowance. The deduction for statutory percentage depletion does not necessarily change proportionately to changes in income (loss) before income taxes.

Previous wording

Long-lived assets used in operations are depreciated and assessed for impairment annually or whenever changes in facts and circumstances indicate a possible significant deterioration in future cash flows is expected to be generated by an asset group. For impairment assessments, management groups individual assets based on a judgmental assessment of the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. The determination of the lowest level of cash flows is largely based on nature of production, common infrastructure, common sales points, common regulation and management oversight to make such determinations. These determinations could impact the determination and measurement of a potential asset impairment. Management evaluates assets for impairment through an established process in which changes to significant assumptions such as prices, volumes and future development plans are reviewed. If, upon review, the sum of the undiscounted pre-tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future volumes, commodity prices, operating costs and capital investment plans, considering all available information at the date of review. Changes to any of the market-based assumptions can significantly affect estimates of undiscounted and discounted pre-tax cash flows and impact the recognition and amount of impairments.

Current wording

assets for impairment through an established process in which changes to significant assumptions such as prices, volumes and future development plans are reviewed. If, upon review, the sum of the undiscounted pre-tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future volumes, commodity prices, operating costs and capital investment plans, considering all available information at the date of review. Changes to any of the market-based assumptions can significantly affect estimates of undiscounted and discounted pre-tax cash flows and impact the recognition and amount of impairments.