With $146 million cash and $30 million quarterly term loan amortization starting in Q3, will the company accelerate debt paydown beyond the scheduled amount?

The company will amortize $30 million per quarter. While free cash flow generation is expected to exceed this, they will be cautious about prepaying more than the scheduled amount because prepaid funds cannot be re-borrowed. The focus is on maintaining sufficient cash for future variability. “However, we need to be a little careful with, you know, prepaying too much because you can't get that money back. It's not like a revolver where you can re-borrow it. So you'll see us be a little more cautious to paying down above the $30 million for the next quarter or so.”

What is the running room for workovers, and how do they manifest in production or costs on the income statement?

The company has caught up on most banked workovers in H1. Future workovers will occur as wells naturally require intervention. They show up in LOE for maintenance-related work and in capital for mini-stimulations that increase reserves. The goal is to maximize existing asset value. “So on the go-forward basis, from more or less from now to, you know, into [ Memorial ], well, will need to be worked on. When we have to be there to do the work, that's when we'll do the additional workover expense of the little mini-stimulations, the acid, surfactants, all of those things, as well as lowering pumps, doing things to optimize the reservoir capability of delivering into that wellbore.”

Why did the oil weighting decrease in Q2, what are the current gas pricing and takeaway conditions, and what is the outlook for H2?

Oil percentage dropped to 64% due to frac-impacted high oil content wells and workovers on older, higher gas cut wells. The company expects the oil cut to be closer to 67% for the rest of the year. Waha differentials, which were negative $1.50 in Q2, are now closer to minus $1 due to Gulf Coast Express expansion, leading to better gas realizations for H2 2026 and H1 2027. “So what's the read-through for the rest of the year? Again, we feel comfortable with our 67% to 68% oil cut. Now that we're halfway through the year and we're, I would probably lean a little closer to the 67% of the range is what I would expect to happen through the rest of the year.”

HPK

HighPeak Energy (HPK) Q2 FY26 earnings call: guidance and Q&A

Earnings call· Jun 2026 (Q2 FY26)· Energy· Aug 11, 2026

Source: earnings call transcript

Executive summary

HighPeak Energy Q2 FY26 — Production Exceeds Guidance, Capital Front-Loaded for H2 Free Cash Flow

HighPeak Energy delivered strong Q2 FY26 results, with H1 production exceeding guidance and unit LOE significantly below expectations. The company strategically front-loaded capital spending into the first half, accelerating completion activity to capture efficiencies and favorable pricing, which positions it for materially lower capital requirements and stronger free cash flow generation in the second half of the year. Despite absorbing hedge losses and facing negative gas differentials, management remains focused on disciplined capital allocation and operational efficiency to drive long-term shareholder value.

Highlights

Production averaged 45,500 BOE per day during H1 2026, exceeding the high end of guidance.
Lease operating expense (LOE) averaged $7.56 per BOE in H1 2026, approximately 13% below guidance.
Accelerated completion activity into Q2 2026 to lock in attractive frac pricing and efficiency gains.
Positioned to generate stronger free cash flow in H2 2026 as capital spending declines meaningfully.

Concerns

Absorbed approximately $55 million of net cash hedge losses during Q2 2026.
Oil cut decreased to 64% in Q2 2026, below the full-year expectation of 67% to 68%.
Experienced very high negative Waha differentials for gas in Q2 2026, impacting realizations.

Guidance & targets

Category	Target	Timeline	Confidence
Capital spending	decline meaningfully high materiality	H2 FY26	High
Free cash flow	stronger free cash flow high materiality	H2 FY26	High
Oil cut	closer to the 67% of the range medium materiality	Rest of FY26	Medium
DUC inventory	10-plus DUCs medium materiality	End of FY26	High
DUC inventory	2 additional DUCs medium materiality	End of FY26	High
2027 Capital requirements and production volumes	look a lot like 2026 high materiality	FY27	Medium
Waha differential	closer to the minus $1 medium materiality	Near term	High

Capital programs

2026 Development Plan underway

Period spend: $185.9M

Spent to date: mid to upper 60% of annual budget

Start: FY26

Benefit:37 turn-in-lines (target)

The company front-loaded capital spending into H1 2026 to accelerate completion activity and capture efficiencies, with 24 wells completed and 20 turned to sales in H1.

Risks & headwinds

Net cash hedge losses Q2 FY26

$55M

Mitigation:Maintaining a solid hedge position for downside protection while allowing exposure to spot prices; adding NYMEX WTI roll swaps and Waha basis swaps.

Commodity price volatility Near term

Unquantified

Mitigation:Maintaining a solid hedge position with majority of oil hedges in mid-$60/barrel range; larger percentage of expected production exposed to spot pricing for upside.

Negative Waha differentials for natural gas Q2 FY26

Negative $1.50 per MCF in Q2 FY26

Mitigation:Waha differential now closer to minus $1 per MCF due to Gulf Coast Express expansion; taken steps to hedge some volatility.

What to watch in Q3 FY26

Capital spending

H2 FY26

Current $185.9M in H1 FY26 (mid to upper 60% of annual budget)

Target Meaningful decline in H2 FY26

Why it matters

A significant reduction in capital spending is key to generating stronger free cash flow and validating the front-loaded capital strategy.

As a result, we expect capital spending to decline meaningfully during the second half of 2026, which is consistent with our original plan and reflects the amount of development work completed during the first 6 months of the year.

Find out whether HPK delivers this. Inve re-checks your case every morning.

Q&A highlights

How did accelerating completions impact Q2 production, and what is the anticipated cadence for H2 2026 and the setup for 2027 production and capital?

Accelerated completions led to more frac-impacted oil volumes in Q2, but H2 will see less water out. The drilling rig is more efficient, potentially adding 2 DUCs for 2027. 2027 capital requirements and production volumes are expected to be similar to 2026, with a planned 10+ DUCs carried over.

“So to your point, we watered out or frac-impacted even more oil than we had initially anticipated. When you look at our kind of maintenance mode program, you will have some lumpiness as we move that frac crew around and have breaks in the schedule.”

asked by Jeffrey Robertson · answered by Michael Hollis

2 min read 5 chapters

Detailed narrative

Operational Execution and Capital Discipline

HighPeak Energy demonstrated strong operational execution in the first half of 2026, with production averaging 45,500 BOE/d, exceeding the high end of guidance. The company strategically pulled forward completion activity into Q2, spending $185.9 million (mid to upper 60% of the annual budget) to capitalize on attractive frac pricing and efficient simul-frac crews.

This front-loaded capital deployment is expected to lead to a meaningful decline in capital spending during H2 2026, positioning the company for stronger free cash flow.

Successful Workover Program

A successful workover program complemented the development plan, investing modest capital into low-cost, high-return opportunities. These workovers brought meaningful production back online and enhanced well productivity, generating attractive economics and quick paybacks. While not a replacement for new drilling, this program maximizes the value of existing assets and contributed to maintaining strong production levels despite frac-impacted oil volumes.

Cost Management and Efficiency Gains

The company achieved strong cost performance, with unit lease operating expense (LOE) averaging $7.56 per BOE in H1 2026, approximately 13% below guidance. These savings are attributed to years of focus on efficient operations, including infrastructure improvements, electrification, fluid level optimization, and a culture of continuous improvement. Management emphasized that these cost savings are proving to be durable and sustainable.

Hedge Strategy and Commodity Exposure

HighPeak maintains a disciplined approach to risk management, utilizing hedges to provide downside protection while allowing exposure to stronger commodity prices. Despite absorbing $55 million in net cash hedge losses in Q2 2026, a larger percentage of expected production remains exposed to spot pricing.

The company also added NYMEX WTI roll swaps and Waha basis swaps to manage calendar spread and West Texas natural gas pricing volatility, respectively.

Balance Sheet and Liquidity Management

The company ended Q2 2026 with $146 million in cash. Scheduled amortization of the term loan at $30 million per quarter begins in Q3 2026. Management indicated a cautious approach to prepaying beyond the scheduled amortization, prioritizing maintaining sufficient cash on hand to weather potential variability in commodity prices, while acknowledging that current strip prices suggest significant free cash flow generation.

Summary of the company's earnings call; see how call summaries are prepared. Not investment advice.