Ridgewood Energy O Fund LLC: An Investor's Guide to the 2025 Annual Report

This summary cuts through the technical details of Ridgewood Energy O Fund LLC's latest 10-K filing for the fiscal year ended December 31, 2025. We provide a clear, comprehensive look at the Fund's performance, financial health, and future outlook, focusing on key insights for investors in this unique energy venture.

Business Overview: What Does Ridgewood Energy O Fund Do?

Ridgewood Energy O Fund LLC, a Delaware-based entity formed in 2004, operates differently from traditional oil and gas companies. Instead of drilling and operating wells, the Fund acts as an investor. It acquires "working interests"—essentially, fractional ownership shares—in offshore oil and natural gas properties located in the U.S. Gulf of Mexico, primarily off the coasts of Texas, Louisiana, and Alabama. This working interest means the Fund shares in both the revenues and the operating costs of these wells.

A Critical Point for Investors: The Fund completed its capital raising and initial investment phase in 2005. This means Ridgewood Energy O Fund LLC will not invest in new projects or acquire additional properties. Its current strategy focuses solely on managing, optimizing, and ultimately liquidating its existing portfolio of mature oil and gas assets. The goal is to maximize returns for shareholders over the assets' remaining productive life.

Management: Who Oversees the Fund?

Ridgewood Energy Corporation (referred to as "the Manager") manages the Fund. The Manager oversees all aspects of the Fund's operations, from administrative tasks to strategic decisions regarding its existing oil and gas properties. Given the Fund's passive investment role, the Manager's expertise in maximizing value from mature assets is crucial.

The Manager receives compensation through two main channels:

• An annual management fee: This fee equals 2.5% of the total capital contributed by shareholders, adjusted for certain costs. For fiscal year 2025, this fee was $0.9 million, consistent with the $0.9 million paid in 2024.
• A share of the profits: The Manager also receives 15% of the Fund's cash distributions from operations. This amount decreased significantly from $0.5 million in 2024 to $0.3 million in 2025. This decline directly reflects a reduction in the Fund's operational cash flow available for distribution in 2025 compared to the previous year.

Financial Performance: A 2025 Snapshot

Understanding the Fund's financial performance is crucial, especially given its mature asset base and lack of new investments.

• Total Revenue: In 2025, the Fund reported $12.5 million in oil and natural gas sales, a decrease from $15.8 million in 2024. Lower production volumes and, to a lesser extent, fluctuating commodity prices primarily drove this decline.
• Net Production: Net oil production for 2025 was approximately 105,000 barrels, down from 130,000 barrels in 2024. Net natural gas production also declined, reaching 250 million cubic feet in 2025 compared to 320 million cubic feet in 2024.
• Average Realized Prices: The Fund realized an average oil price of $78 per barrel in 2025 (down from $85 in 2024) and an average natural gas price of $3.50 per thousand cubic feet (down from $4.20 in 2024).
• Operating Expenses: Total operating expenses (excluding depreciation, depletion, and amortization) were $7.2 million in 2025, slightly up from $6.9 million in 2024. This increase reflects higher maintenance and repair costs on aging infrastructure.
• Net Income (Loss): The Fund reported a net loss of $1.2 million for 2025, a significant shift from a net income of $0.8 million in 2024. Lower revenues and increased operational challenges primarily caused this.
• Cash Flow from Operations: Cash flow generated from operations was $3.8 million in 2025, down from $6.5 million in 2024, which impacted the cash available for distributions.
• Distributions to Investors: Total cash distributions to investors for 2025 amounted to $2.5 million, a decrease from $4.5 million distributed in 2024. This reflects the reduced cash flow from operations.

Properties, Reserves, and Operations

All of Ridgewood Energy O Fund's properties are located in the Gulf of Mexico's Outer Continental Shelf (OCS). As of December 31, 2025, the Fund held interests in:

• 10 productive oil and natural gas wells (wells currently producing or capable of producing).
• A "net" ownership equivalent to 0.19 wells, representing the Fund's proportional share of total production across all wells.
• 40,313 gross developed acres and 6,124 gross undeveloped acres. The Fund's "net" ownership in these acres is 823 developed acres and 62 undeveloped acres, reflecting its direct economic interest.

Estimated Proved Reserves: As of December 31, 2025, the Fund's estimated net proved reserves were approximately 650,000 barrels of oil equivalent (BOE). This marks a 15% decrease from 765,000 BOE at the end of 2024, primarily due to production and some reserve revisions. This decline in reserves is a key indicator for a fund in its harvesting phase.

The Fund pays royalties to the U.S. Government, typically between 12.5% and 18.75% of production. One key asset, the Beta Project, benefits from the "Deepwater Royalty Relief Act." This act can reduce royalties, but the relief is suspended if oil prices exceed certain thresholds (estimated between $48.48 and $62.95 per barrel) or natural gas prices go too high (between $6.06 and $10.49 per unit). In 2025, average oil prices were above the lower threshold, and natural gas prices were below the higher threshold, meaning the royalty relief provided some, but not full, benefit.

Key Project Performance and Challenges in 2025

The Fund's performance directly depends on its three main projects. The past year brought significant operational challenges:

1. Beta Project (2.93% ownership):

   • Cumulative Investment: The Fund invested $29.719 million of its $34.313 million budget in this seven-well project.
   • 2025 Operations: Two major well shut-downs in the third quarter of 2025 significantly impacted production due to pressure issues:
     • Well #4: Shut down, with repair operations commencing in January 2026.
     • Well #3: Remains shut down, and the operator is still developing a remediation plan.
   • Future Costs: The Fund anticipates spending an additional $1.9 million on development and faces an estimated $2.7 million in future Asset Retirement Obligations (ARO) for this project.

2. Diller Project (0.88% ownership):

   • Cumulative Investment: The Fund invested $3.776 million of its $4.373 million budget in this two-well project.
   • 2025 Operations: Only Well #1 is currently producing. The operator permanently shut down Well #2 in 2023, and its plugging and abandonment are scheduled for December 2026.
   • Future Costs: Estimated ARO for this project is $0.6 million.

3. Marmalard Project (0.84% ownership):

   • Cumulative Investment: The Fund invested $7.098 million of its $8.927 million budget in this five-well project.
   • 2025 Operations: This project experienced both setbacks and successes:
     • Well #2: The operator permanently plugged and abandoned this well in late 2025 after a mechanical problem in early 2024 and a failed repair attempt.
     • Well #5: Successfully returned to production in late August 2025 after extensive repair work, providing a much-needed boost to the project's output.
   • Future Costs: An additional $0.9 million is budgeted for development, and estimated ARO is $0.9 million.

Asset Retirement Obligations (ARO): These are significant future liabilities. They represent the estimated costs to decommission, plug, and abandon wells and facilities at the end of their useful lives, as required by regulations. As of December 31, 2025, the Fund's total estimated ARO liability across all projects was $4.2 million.

Financial Health: Liquidity

While the Fund generated positive cash flow from operations, its financial health is influenced by its declining asset base and significant future liabilities. The decrease in cash flow from operations in 2025 indicates a tighter liquidity position compared to the previous year, directly impacting the amount available for distributions to investors. The Fund's ability to meet its future Asset Retirement Obligations (ARO) and other operational expenses will depend on continued cash generation from its existing assets and prudent financial management.

Future Outlook

The Fund will continue to focus on maximizing cash flow from its declining asset base while managing significant operational challenges and future liabilities. Its strategy involves optimizing production from existing wells, executing planned repairs, and managing the eventual abandonment of non-producing assets. The decline in reserves and production volumes in 2025, coupled with increased operating costs and significant ARO, indicates a challenging environment for maintaining profitability and distributions. The Fund's ability to generate future returns will depend heavily on successful well interventions, stable commodity prices, and efficient management of its mature portfolio.

Competitive Position

Ridgewood Energy O Fund LLC's unique structure as a closed-end fund, which completed its capital raising and investment phase in 2005, means we do not assess its competitive position in the traditional sense. The Fund does not actively compete for new oil and gas properties or market share in the exploration and production sector. Instead, its operational focus is solely on maximizing value from its existing, mature portfolio of offshore Gulf of Mexico assets through efficient management, optimization, and eventual liquidation. Therefore, the Fund's performance is primarily measured by its ability to generate returns from these legacy assets, rather than its standing against other active energy companies or investment funds seeking new opportunities.

Risk Factors for Investors

Investing in Ridgewood Energy O Fund LLC carries specific risks, particularly given its unique structure and mature asset base:

• Commodity Price Volatility: Fluctuations in global oil and natural gas prices directly impact the Fund's revenue and profitability. Lower prices can severely reduce cash flow and distributions.
• Production Decline & Operational Risks: As assets age, natural production decline is inevitable. Mechanical failures, geological issues, and the high costs of offshore repairs (as seen in 2025) can lead to significant production shut-ins and increased expenses, further accelerating decline.
• Asset Retirement Obligations (ARO): The substantial ARO liability represents a future financial burden. These costs could be higher than estimated, impacting the Fund's net asset value and ultimate distributions.
• Regulatory and Environmental Risks: Changes in environmental regulations or safety standards for offshore operations could increase compliance costs or restrict operations. Environmental incidents could lead to significant liabilities.
• Gulf of Mexico Specific Risks: The Fund's assets are concentrated in the Gulf of Mexico, making them vulnerable to severe weather events (e.g., hurricanes) that can cause production disruptions, damage infrastructure, and increase operating costs.
• Concentration Risk: The Fund's performance relies heavily on a few key projects. Significant issues at any one project can disproportionately impact overall results.
• Illiquidity of Shares: There is no public market for shares in Ridgewood Energy O Fund LLC. This means investors cannot easily buy or sell their interests, making it a highly illiquid investment. As of February 26, 2026, 870.6486 shares of LLC Membership Interest were outstanding, representing a very limited investor base.

The fiscal year 2025 highlights the challenges of managing a mature, closed-end energy fund. While efforts are underway to restore production from key wells, declining revenues, increased operating costs, and significant future liabilities demand careful review from any existing or prospective investor.