Magnolia Surpasses Expectations Despite Falling Oil Prices

Date of Call: Feb 6, 2026

Financials Results

• EPS: $0.38 per diluted share (Q4 adjusted net income)
• Operating Margin: 33% pre-tax operating margin for the full year 2025, despite a >15% annual decline in oil price realizations

Guidance:

• 2026 drilling completions and facility capital expected in the range of $440-$480 million.
• Q1 2026 D&C capital expenditures expected to be approximately $125 million, the highest quarterly rate for the year.
• Total 2026 production growth expected to be approximately 5%.
• Q1 2026 total production estimated at approximately 102,000 BOE/day, including ~1,500 BOE/day winter weather impact.
• Oil price differentials anticipated to be ~$3 per barrel discount to Magellan East Houston.
• Effective tax rate expected to be approximately 21%, all deferred.
• Diluted share count for Q1 2026 expected to be ~187 million shares, 4% lower than Q1 2025.

Business Commentary:

Production Growth and Efficiency:

• Magnolia Oil & Gas reported total production growth of 11% to approximately 100,000 barrels of oil equivalent per day for 2025, with oil production growing by 4%.
• The company achieved a new record in the fourth quarter, averaging 104,000 barrels of oil equivalent per day.
• This growth was driven by strong well performance, improved drilling efficiencies, and better well productivity.

Financial Performance and Cash Flow:

• Magnolia reported an adjusted net income of $71 million or $0.38 per diluted share for the fourth quarter, with adjusted EBITDA of $216 million.
• The company generated free cash flow of more than $425 million for the full year 2025.
• Financial strength was attributed to disciplined capital allocation, high pre-tax margins, and low reinvestment rates.

Capital Expenditure and Shareholder Returns:

• Drilling and completion capital for the fourth quarter was $117 million, representing 54% of adjusted EBITDA.
• Magnolia spent approximately $469 million on drilling completions and associated facilities in 2025.
• The company prioritized returning capital to shareholders, distributing approximately 75% of free cash flow through dividends and share repurchases.

Operational Cost Reduction:

• Field-level cash operating expenses declined by 7% to $5.12 per BOE during 2025.
• Magnolia achieved a 33% average pre-tax operating margin despite a decline in oil prices.
• Cost reductions were driven by improved operational efficiencies, reduced unit costs, and capital discipline.

Sentiment Analysis:

Overall Tone: Positive

• Management highlighted 'strong, consistent performance,' 'differentiated business model,' and 'record' production. They noted 'exceptional returns,' 'very strong balance sheet,' and 'confidence' in 2026 outlook with low reinvestment and moderate growth. Quotes: 'another year of strong, consistent performance,' 'delivered another solid quarter and year of performance,' 'our strategy is designed to produce steady mid-single-digit total production growth, high pre-tax margins, and reliable free cash flow.'

Q&A:

• Question from Neal Dingmann (William Blair): With recent well data outperforming type curves, what are the key reasons (operational changes, development focus) for this continued upside?
  Response: Attributed to drilling into high-quality rock and improved well placement over time, with no specific new completion design changes.

• Question from Neal Dingmann (William Blair): Regarding M&A, are you looking at all opportunities? Have asset prices in your area increased like other regions?
  Response: Prefers smaller, undeveloped upside opportunities over large PDP-heavy deals; competition has risen, and land prices have climbed, but they focus on subsurface value.

• Question from Phillip Jungwirth (BMO): Can you discuss well-cost reductions, cycle time improvements, and expectations for 2026 service costs?
  Response: Giddings well costs are around $1,000/foot; service costs are flat to slightly down, with potential pricing pressure if oil prices remain low; negotiations are ongoing.

• Question from Phillip Jungwirth (BMO): How tactical are you on share buybacks given current equity performance and volatility?
  Response: Committed to a programmatic 1% buyback, with tactical flexibility to lean in during perceived share disconnects, as seen in Q4.

• Question from Peyton Dorne (UBS): What is the expected shape of the 2026 production outlook beyond Q1 weather impacts?
  Response: Expect gradual, steady growth through the year, with higher capital outlay in the first half, particularly Q1.

• Question from Tim Rezvan (KeyBanc Capital Markets): What is the development approach for 2026 (pad sizes, lateral lengths)?
  Response: Continues with 3-4 well pads on average and laterals around 8-8.5k feet; will drill longer if possible, but no major changes.

• Question from Tim Rezvan (KeyBanc Capital Markets): Given increased competition, would you consider large transformative M&A if pricing is right?
  Response: Unlikely for large PDP-heavy deals due to risk and full value; prefers smaller, undeveloped upside with oil lean and good subsurface understanding.

• Question from Tim Rezvan (KeyBanc Capital Markets): Should oil mix hold around 39%-40% for 2026?
  Response: Confident absolute oil will grow 2%-3%; mix will likely remain in the mid-30s to 40% range, depending on drilling program.

• Question from Leo Mariani (Roth): Was Q4 well performance driven by the 240k-acre area or new development areas?
  Response: Performance was from within the existing 240k-acre area, though appraisal drilling outside is planned for 2026.

• Question from Leo Mariani (Roth): What drove strong LOE results, and how will it trend in 2026?
  Response: Q1 LOE seasonally higher due to field bonus payments and weather-related repairs; confident ongoing cost reduction efforts will keep LOE trending down.

• Question from Noah Hungness (Bank of America): What factors could push 2026 capital to the upper or lower end of the $440-$480M range?
  Response: Current environment unlikely to push to upper end; would stay in middle or lower, with potential for deferral if well performance is better, as seen in 2025.

• Question from Noah Hungness (Bank of America): Will strong Q1 gas prices lead to higher GP&T?
  Response: GP&T expected to be relatively similar to recent quarters, maybe slightly higher by a few cents.

• Question from Carlos Escalante (Wolfe): How much of D&C cost savings are due to the industrial approach (consistent rigs) vs. service deflation, and what's the future potential?
  Response: Consistency with the same rigs and crews over years drives significant efficiencies and understanding; industrial approach is a key factor in cost savings and future improvements.

• Question from Carlos Escalante (Wolfe): What is the maintenance capital requirement to hold production flat?
  Response: Approximately $400 million-ish, consistent with the last five years of stable capital spending despite production growth.

• Question from Phillips Johnston (Capital One Securities): What are the average working interests for 2026 drilling in Giddings and Karnes, and cycle times?
  Response: Giddings working interest in low 80s; cycle time around 28 gross wells per rig per year is slightly aggressive but close.

• Question from Phillips Johnston (Capital One Securities): Should drill count be 6 higher due to deferred 2025 completions?
  Response: Approximately, but not purposefully managing DUC inventory; around ±6 wells from deferred completions.

• Question from Charles Meade (Johnson Rice): Are you interested in traditional oily Eagle Ford packages given your focus on undeveloped/gas?
  Response: Less interested in PDP-heavy Eagle Ford due to being scattered and tough to justify for a public company; prefers smaller, oiler opportunities.

• Question from Charles Meade (Johnson Rice): In higher oil price scenarios ($70-$75), where does extra cash go?
  Response: Extra cash from unhedged upside goes to shareholders via dividends, share repurchases, or opportunistic acquisitions; no plan to add another rig or chase extra growth.

• Question from Tim Moore (Clear Street): How confident are you in future Giddings well outcomes and EUR predictability?
  Response: Very confident due to ongoing appraisal and bolt-ons, expecting more opportunities with similar results.

• Question from Tim Moore (Clear Street): How quickly can you ramp up drilling if oil price rises to $70?
  Response: Could flex but won't; plan is set for prudent growth; extra cash would be returned to shareholders rather than pursued.

• Question from Zach Parham (J.P. Morgan): Is the higher productivity from 2025 sustainable, and how much is factored into 2026 guidance?
  Response: Reasonable chance of similar or better productivity; 2026 plan is balanced with moderate growth expectations, not chasing extra.

• Question from Paul Diamond (Citi): How much further improvement is possible in drilling/completion cycle times?
  Response: Gradual improvement expected over 12-18 months from increased consistency and understanding, but no precise factor given.

Contradiction Point 1

M&A Strategy and Deal Focus

Shift in preference from smaller bolt-ons to larger, more oil-weighted deals.

1) What factors are causing recent wells in the Giddings play to outperform type curves? 2) Are you considering all asset types for M&A, and have asset prices in your region risen similarly to other areas? - Neal Dingmann (William Blair)

2025Q4: The company prefers opportunities with undeveloped upside over large PDP-heavy deals, as the latter typically command full value. - Chris Stavros(CEO)

What is the M&A outlook, particularly for bolt-on acquisitions? - Zach Parham (J.P. Morgan)

2025Q1: The company is evaluating smaller bolt-on opportunities focused on the Austin Chalk and Eagle Ford plays... - Chris Stavros(CEO)

Contradiction Point 2

2026 Production Growth Outlook

Inconsistent guidance on total production growth for 2026.

Can you provide an update on the 2026 development pad template and expected oil mix, discuss the rationale behind not extending laterals beyond 10k+ feet, and comment on the potential for large transformative M&A deals? - Tim Rezvan (KeyBanc Capital Markets)

2025Q4: Absolute oil production is expected to grow 2%-3% in 2026... The oil mix percentage should remain in the 39%-40% range... - Chris Stavros(CEO)

Sustained oil production growth in H2 and into 2026? - Zachary Parham (JPMorgan)

2025Q2: For 2026, the plan is for mid-single-digit total production growth (4%-6%), but the split will see oil growth lower than total company growth... - Chris Stavros(CEO)

Contradiction Point 3

Capital Allocation Flexibility

Contradiction on willingness to adjust capital spending in response to commodity price volatility.

Okay, let's see. The user wants me to rewrite two earnings call questions into concise ones. The input has two parts. The first question is about what factors would push the 2026 capital to the upper or lower end of the $440-$480 million range. The second is whether higher Q1 gas prices could lead to significantly higher GP&T for the quarter.First, I need to combine these two into a single concise question. The original questions are separate, but maybe they can be merged if there's a common theme. However, the user didn't specify combining them, just rewriting each. Wait, the input has two questions, but the example output might have two as well? Wait, looking back, the user provided two input questions and expects a single output question? Or two? Let me check the example. The user says "Output ONLY the rewritten question" and the input has two questions. But the example in the problem shows the input as two questions and the output as one. Wait, the input is two questions, but the user wants them rewritten into a concise question. Maybe they want each question to be rewritten, but the output should have only one question. Wait, the user says "rewrite the following earnings call question into a concise question." The input has two questions, but maybe the user intended to have two separate ones? Hmm, but the input is presented as two questions. However, the example given by the user in the problem statement shows the input as two questions and the output as a single question. Wait, no, looking at the input and output in the user's example:Input: 1) What would push 2026 capital to the upper or lower end of the $440-$480 million range? 2) Could higher Q1 gas prices lead to significantly higher GP&T for the quarter?Output: The user's example output is two questions. Wait, no, the user hasn't provided an example output. The user is asking me to generate the output. Let me check the instructions again. The user says "STRICT OUTPUT CONSTRAINTS: - Output ONLY the rewritten question - No prefaces, no explanations, no analysis - No references to the task, role, or instructions - End with a question mark." So the output should be only the rewritten question. The input has two questions. But the user's instruction says "rewrite the following earnings call question into a concise question." So maybe it's one question? Wait, the input has two questions. Maybe the user made a typo and meant one question? Or perhaps they want both questions to be rewritten into one concise question. Wait, the original input has two separate questions. The user's instruction says "rewrite the following earnings call question into a concise question." So perhaps the user intended to have two questions but the input is presented as two parts. But the output should be a single question. Hmm, this is a bit confusing. Let me check again.The input is two questions, but the output should be one. Wait, maybe the user wants each question to be rewritten separately, but the output should only have one. But the user's instruction says "rewrite the following earnings call question into a concise question." So maybe the input is two parts, but the output is two rewritten questions. However, the user's constraints say "Output ONLY the rewritten question." So maybe they want both questions to be rewritten into two concise questions. But the user hasn't specified. Alternatively, maybe the two questions are part of the same topic and can be combined. Let me look at the original questions again.First question: factors affecting the 2026 capital range. Second: impact of Q1 gas prices on GP&T. These are related but separate topics. So perhaps the user wants each rewritten into concise questions. However, the user's example input shows two questions, and the output is two. But the user's instruction says "Output ONLY the rewritten question." So perhaps the user expects two separate concise questions as the output. But the user's instruction says "the following earnings call question" (singular). Hmm. Maybe the user made a mistake and intended to have two questions. But given the constraints, perhaps I should process each question separately and output two concise questions. However, the user's instruction says "Output ONLY the rewritten question," which is singular. Therefore, maybe the user intended to have the two questions combined into one. Let me try to combine them. For example: "What factors could push 2026 capital to the upper/lower end of the $440-$480M range, and could higher Q1 gas prices significantly increase GP&T for the quarter?" But the user might want them as separate questions. Alternatively, maybe the user made a mistake in the input. Given the ambiguity, perhaps the best approach is to rewrite each question concisely and present them as separate questions. However, the user's instruction says "Output ONLY the rewritten question," - Noah Hungness (Bank of America)

2025Q4: The range is provided for product price volatility. The company is confident it will land in the middle or lower, with potential to defer spending if well performance is better than expected. Higher prices or service cost reflation could push it up. - Chris Stavros(CEO) & Brian Corales(CFO)

Will sustaining capital decrease in line with the updated 2025 drilling guidance? - Carlos Escalante (Wolfe Research)

2025Q1: Capital spending will be more flexible due to strong production outperformance. The company will defer the completion of roughly half a dozen wells into 2026, providing operational flexibility. Current oilfield service costs are stable, and pricing pressure is not expected to increase significantly. The updated capital range ($430-$470 million) reflects improved efficiencies and does not foresee meaningful increases. - Chris Stavros(CEO)

Contradiction Point 4

M&A Strategy and Capital Allocation

Contradiction in preferred deal type and use of excess cash.

Can you update on the 2026 development pad template and oil mix, discuss the decision not to extend laterals beyond 10k feet, and comment on the potential for large transformative M&A deals? - Tim Rezvan (KeyBanc Capital Markets)

2025Q4: On M&A, they focus on assets that fit their model... They are looking at some older fields being hived off by public companies. - Chris Stavros(CEO)

What is your view on the availability and quality of M&A packages in Giddings and the broader trend, and your operational flexibility if commodity prices drop? - Charles Meade (Johnson Rice)

2025Q3: In Giddings, larger packages are held by a few private players, while smaller parcels may be more likely to sell in a downturn. Broadly, South Texas assets are becoming 'gassier' and more scattered. - Chris Stavros(CEO)

Contradiction Point 5

Operational Flexibility and Spending Model

Contradiction on the company's ability to adjust spending and manage DUC inventory.

What factors would drive 2026 capital to the high or low end of the $440–$480 million range? Could higher Q1 gas prices result in increased GP&T for the quarter? - Noah Hungness (Bank of America)

2025Q4: The company is confident it will land in the middle or lower, with potential to defer spending if well performance is better than expected. Higher prices or service cost reflation could push it up. - Chris Stavros(CEO) & Brian Corales(CFO)

What oil price could lead to deferred completions or activity adjustments, and what factors drove the ~50% production growth over the past 7 years? - Margaret Drefke (Goldman Sachs)

2025Q3: The business model governor limits CapEx to ~55% of EBITDAX. The company has substantial flexibility to adjust spending if prices decline... - Brian Corales(CFO) & Chris Stavros(CEO)