Who Pays for the Hole in the Ground?

Measuring and Internalizing Idle-Well Liability in California Oil & Gas

Thesis paper

Research question: How can California ensure that the oil-and-gas industry—not taxpayers—pays for plugging, abandonment, and site restoration of idle wells, and what measurement and data architecture is needed to make that responsibility enforceable?

Central thesis: California has moved toward a polluter-pays framework through escalating idle-well fees under AB 1866 and transfer-related financial assurance under AB 1167. Yet the system still permits substantial “leakage”: operators can fail to pay or file valid plans, liabilities can be transferred to financially weak entities, and public disclosures do not consistently translate company-level asset-retirement obligations into well-level, operator-level, and enforceable cleanup capacity. California should therefore combine risk-adjusted, full-cost financial assurance; a dedicated industry-financed cleanup backstop; transparent, independently verifiable well-liability data; and targeted reuse incentives. The state should not mistake circular-economy opportunities for a substitute for mandatory plugging and reclamation.

Abstract

California’s idle and orphaned oil-and-gas wells illustrate a classic environmental externality: firms receive the private benefit of production while the eventual costs of plugging wells, remediating sites, monitoring leaks, and restoring land may be deferred onto the public. The liability is financially material, environmentally consequential, and politically difficult because it accumulates slowly, is sensitive to volatile commodity prices, and becomes most acute when operators are least able to pay.

California has recently strengthened its legal architecture. Assembly Bill 1866 requires operators with idle wells to pay annual fees or submit Idle Well Management Plans (IWMPs), while Assembly Bill 1167 restricts transfers of marginal wells unless the buyer demonstrates financial assurance sufficient to cover plugging, abandonment, and restoration costs. These statutes are important steps toward internalizing decommissioning liability. They do not, however, eliminate the central risk: an operator can become insolvent, transfer marginal assets, fail to comply, or leave the state with inadequate bonds and incomplete information.

This paper evaluates three financing models: an industry-financed prepayment model analogous to Superfund; a transaction-based buyer-responsibility model centered on AB 1167; and a residual public-finance model in which taxpayers fund abandoned-well cleanup. It argues that the best policy is a hybrid in which the state requires full-cost, risk-adjusted assurance at the operator and transfer level; levies fees that reflect both inactivity duration and default risk; maintains a dedicated industry-funded orphan-well backstop; and publishes auditable well-level information linking ownership, production status, bonding, estimated plugging cost, transfer history, methane risk, and compliance status.

The paper also applies the 4R framework—Reduce, Replace, Reuse, Recycle—to idle-well policy. The priority is Reduce: prevent new orphan liabilities. Reuse—for geothermal energy, carbon-dioxide storage, lithium-related projects, or other productive uses—may be economically and environmentally beneficial in selected cases, but it cannot justify indefinitely retaining uneconomic wells. Recycle, in this context, means plugging, remediating, and returning the land to safe future use. The decisive governance lesson is simple: what California does not systematically measure, compare, disclose, and enforce will remain a public liability waiting to mature.

1. The problem: an externality beneath the surface

An oil or gas well is not merely a productive asset. It is also a long-lived closure obligation. Once a well ceases economic production, it may remain idle for years before being plugged and abandoned. During that interval, the operator may preserve an option to restart production, but the public bears growing exposure to methane leakage, groundwater risks, surface hazards, blight, and the possibility that the responsible company will become insolvent.

California defines an idle well as one that has not been used for two years or more and has not yet been properly plugged and abandoned. The state’s CalGEM program recognizes that when an operator becomes insolvent or deserts wells, responsibility for permanently sealing and closing them can fall to the state. This is the defining feature of the externality: the private owner can postpone expenditure while the public inherits the downside if the owner disappears or lacks financial capacity. conservation.ca

The financial magnitude is substantial. A California Council on Science and Technology analysis estimated that approximately 5,540 California wells may already lack a viable operator or face a high risk of becoming orphaned, with a potential net state liability of about $500 million after accounting for available bonds. It further identified 69,425 economically marginal and idle wells that could become orphaned as production declines or ownership moves to financially weaker companies. The analysis estimated an average contract plugging cost of roughly $68,000 per well and a potential net cost approaching $9 billion if the state had to plug all active and idle wells. ccst

More recent legislative analysis likewise describes a large inventory: roughly 94,250 active, new, and idle wells statewide, including about 34,650 idle wells, alongside approximately 138,500 wells already plugged and abandoned in some form. CalGEM was estimated to face almost $1 billion in plugging-and-abandonment costs for approximately 5,300 orphaned, deserted, and potentially deserted wells. Estimates differ because they use different well populations, cost assumptions, and definitions of liability, but they point in the same direction: California has a material, growing, and unevenly secured decommissioning obligation. trackbill

Why market incentives fail

A conventional firm may rationally delay closure even when delay is socially harmful. Four incentives explain why:

• Option value: Maintaining an idle well preserves the chance of restarting production if oil prices rise or regulations change.
• Financial discounting: A plugging expense due today is more costly to the firm than an expense deferred for years, especially when future obligations are discounted in financial statements.
• Limited liability and insolvency risk: If a company fails, the cost can shift to creditors, the state, or taxpayers.
• Adverse selection in asset transfers: Firms with mature, low-producing, high-liability wells have an incentive to sell those wells to smaller or less-capitalized buyers.

These incentives mean that a cleanup system cannot rely solely on good corporate intentions or high-level sustainability statements. It needs enforceable rules, sufficient financial security, and data that reveal whether the nominally responsible party can actually perform the obligation.

2. California’s three financing models

California’s policy debate can be organized around three competing—but in practice overlapping—models of who should pay.

Model 1: Industry prepayment and the Superfund logic

The strongest normative analogy is the Superfund principle: industries associated with a pollution problem should finance its remediation rather than leave the cost to general taxpayers. The analogy is not exact—well plugging is a sector-specific end-of-life obligation rather than a hazardous-waste cleanup regime—but the fiscal logic is the same. Those who create the risk, profit from the productive activity, and control the relevant assets should bear the expected cost of remediation.

AB 1866 moves California in that direction. It requires operators with idle wells to either pay annual fees for wells that were idle during the preceding calendar year or file an Idle Well Management Plan. CalGEM states that fees or plans are due by May 1 each year. The program is designed to make prolonged idleness increasingly costly and to force a choice: pay for the continuing risk or commit to an approved elimination pathway. conservation.ca

The statutory fee schedule begins at $1,000 per well for wells idle for fewer than three years and rises with duration of inactivity. Under CalGEM’s post-2025 requirements, fees increase materially for long-idle wells, reaching $12,500 for wells idle 20 years or more under the later fee schedule. This structure is conceptually sound because the probability that an idle well becomes a public liability generally rises with time, deteriorating infrastructure, declining production prospects, and weakening operator incentives. leginfo.legislature.ca

However, the fee is not necessarily the same as full expected cleanup cost. A fee system works only if it is high enough to change behavior, collected reliably, and paired with adequate financial assurance. If a firm can treat fees as a small carrying cost while waiting for a favorable oil-price movement—or if it simply does not pay—the system becomes a weak signal rather than a true internalization mechanism.

Model 2: Buyer responsibility under AB 1167

AB 1167, commonly described as California’s Orphan Well Prevention Act, targets the transaction channel through which abandonment liability can be shifted. The governor’s signing statement described the statute as requiring State Oil and Gas Supervisor approval of transfers of marginal wells only when the full cost of plugging, abandonment, and site restoration is covered by a bond or other financial assurance mechanism. leginfo.legislature.ca

This matters because transfers can sever the connection between historical profit and end-of-life obligation. A large, well-capitalized producer may sell aging wells to a smaller company whose business model depends on extracting remaining production but whose balance sheet cannot support eventual closure. If that buyer fails, the state inherits an obligation that was foreseeable at the time of sale.

Early evidence indicates that AB 1167 has changed behavior. Carbon Tracker reported that the law took effect on January 1, 2024 and required full-cost financial assurance for transfers of low-producing wells; it found that transfers slowed substantially after the law’s implementation. The direction of change is important: a transfer review process can prevent marginal wells from being moved into thinly capitalized corporate shells. carbontracker

Yet AB 1167 is not self-executing. Its effectiveness depends on four questions:

1. What counts as a marginal well or covered transaction?
2. How accurately does CalGEM estimate plugging, abandonment, restoration, and monitoring costs?
3. Can assurance be evaded through corporate restructuring, stock transactions, affiliate transfers, or changes in control that do not look like a conventional asset sale?
4. Can the state reassess assurance when conditions change—such as falling prices, reserve downgrades, litigation, or a buyer’s deteriorating credit?

The issue of stock-for-stock transactions deserves special attention. A rule that focuses only on a direct asset conveyance may miss economically identical transfers of control. A buyer may acquire a company rather than individual wells, thereby acquiring the liability indirectly. The policy objective should be functional rather than formal: whenever control over the entity responsible for high-liability wells changes, the state should have authority to reassess financial assurance and responsibility.

Model 3: Taxpayer funding as the residual backstop

Taxpayer funding cannot be eliminated entirely. Some wells have already become orphaned, some responsible entities no longer exist, and urgent public-health or methane risks may require rapid state intervention. Public cleanup capacity is therefore essential.

But public money should be a residual backstop, not the principal business model for an industry whose operations generate predictable end-of-life liabilities. When the state pays by default, it creates moral hazard: operators receive the upside from extracting the last economic value from a well while transferring the downside to the public after insolvency.

The policy objective is not to deny the state’s duty to protect communities. It is to reduce the number of cases in which the state must step in by ensuring that operators pay before financial distress makes collection impossible.

3. Leakage: why 100% compliance is unrealistic

No regulatory system achieves perfect compliance. The relevant policy question is not whether leakage exists, but whether the state can identify it quickly, quantify it, price it into the system, and prevent it from becoming taxpayer exposure.

California’s own experience demonstrates the scale of this problem. Legislative analysis based on CalGEM reporting found that, in 2021, California had 1,200 unique operators associated with 17,888 long-term idle wells. Of those operators, 1,149—96%—did not file Idle Well Management Plans, and 1,066—93%—did not pay fees. The analysis concluded that 1,031 operators failed to either file a plan or pay fees, leaving approximately $3.7 million unpaid. A later report described roughly 1,085 operators statewide as failing to pay fees or submit valid management plans by the deadline. trackbill

These figures should not be treated as a minor administrative defect. They are evidence of systemic leakage. They suggest that the legal obligation exists, but collection, follow-up, and escalation may not be occurring at the speed required to prevent liabilities from aging into orphan status.

The compliance problem has several layers

• Payment leakage: An operator owes an idle-well fee but does not pay.
• Planning leakage: An operator files no management plan, files an inadequate plan, or fails to meet plan commitments.
• Data leakage: The regulator lacks timely or verified information on production status, ownership, financial condition, well integrity, or abandonment cost.
• Transaction leakage: Ownership changes in form rather than substance, allowing risk to move without adequate reassessment.
• Enforcement leakage: A violation is recorded but penalties, liens, permit restrictions, or abandonment orders are delayed or underused.
• Insolvency leakage: By the time the state acts, the operator has insufficient assets to pay.

AB 1866 provides some leverage: an operator that fails to comply with an approved IWMP can have the plan canceled and become liable for the relevant year’s fees and the following two years. But enforcement after noncompliance is not a substitute for prevention. The state’s most valuable moment is before a financially weak operator becomes insolvent, not after. conservation.ca

A practical principle: price default risk

California should treat an operator’s likelihood of nonpayment as part of the liability—not as a separate administrative issue. That implies a risk-adjusted framework:

[ \text{Required financial assurance} = \text{Estimated closure cost}

• \text{contingency}
• \text{risk premium}

• \text{credible dedicated reserves}. ]

The risk premium should rise when an operator has:

• A high proportion of low-producing or idle wells.
• Repeated failure to pay fees or comply with plans.
• Weak liquidity, excessive leverage, or a deteriorating credit profile.
• A record of acquisitions involving mature wells.
• High methane risk or wells located near sensitive receptors.
• A large gap between estimated abandonment obligations and available bonding.
• Material dependence on volatile commodity prices.

This is not punitive. It is actuarially rational. A financially weak operator with thousands of aging wells presents a larger expected public liability than a well-capitalized operator with the same number of wells and an independently secured closure reserve.

4. Measurement: what is disclosed, what is missing

The maxim “what gets measured gets improved” is particularly relevant to idle-well liability. California needs two related forms of measurement:

1. Financial measurement of future plugging, abandonment, restoration, and monitoring costs.
2. Operational measurement of the wells, owners, risks, and compliance status that determine whether the liability will actually be paid.

What 10-K filings reveal

Public-company 10-K filings provide evidence that oil-and-gas firms recognize some retirement obligations. Under U.S. accounting rules, companies recognize asset retirement obligations when a legal retirement obligation exists and can be reasonably estimated. The liability is typically calculated as the present value of estimated future cash outflows, using assumptions about inflation, timing, discount rates, regulatory requirements, and engineering costs.

California Resources Corporation provides a useful example. Its 2025 Form 10-K states that its asset retirement obligations relate to plugging and abandoning oil-and-gas wells and related facilities. It reported asset retirement obligations of $1.033 billion as of December 31, 2025, compared with $1.129 billion in 2024. The filing also states that a one-percentage-point increase in the assumed inflation rate would increase the liability by $94 million. This is a meaningful disclosure: it shows that closure costs are financially material and sensitive to assumption changes. crc

Chevron similarly reports asset-retirement obligations where a legal obligation exists and the amount can be reasonably estimated; its 2025 filing reported an approximate total liability balance of $15.0 billion, including environmental-related costs. Such disclosures demonstrate that large firms recognize decommissioning liabilities at a corporate level. sec

But corporate ARO disclosure is not enough for public accountability in California. It is usually aggregated across geographies, asset classes, and business segments. It may not identify:

• The number of idle wells in California.
• The age of those idle wells.
• Their estimated plugging and site-restoration cost.
• Their methane-leak or integrity risk.
• Their distance from homes, schools, hospitals, or other sensitive receptors.
• The amount and type of financial assurance held by CalGEM.
• The difference between booked ARO and regulator-estimated full closure cost.
• The degree to which the liability is funded, insured, bonded, or merely booked.

CRC, Berry, and Chevron: a disclosure comparison

The 2025 CRC–Berry transaction also shows why consolidation and transfer oversight matter. CRC’s 2025 annual report states that the company entered into an all-stock combination with Berry and that the transaction added well-servicing and abandonment capacity in California. A corporate transaction may have real operational benefits, including access to decommissioning expertise. But it must not allow a change in corporate form to obscure who is ultimately responsible for inherited wells and whether the combined entity has sufficient assurance. sec

GRI, SASB, and the materiality gap

GRI and SASB serve different purposes. GRI is broader and impact-oriented, whereas SASB—now maintained within the IFRS Foundation’s sustainability standards architecture—focuses on industry-based disclosures about sustainability-related risks and opportunities likely to affect cash flows, access to finance, or cost of capital. ifrs

For oil-and-gas exploration and production, SASB identifies material sustainability topics and metrics related to issues such as greenhouse-gas emissions, air quality, water management, biodiversity, community relations, and reserves-related risk. The standard covers upstream exploration and production activities. Yet the central disclosure gap for this paper is that public sustainability reporting does not consistently provide a standardized, decision-useful metric for the number, age, risk status, estimated closure cost, and financial security of idle and abandoned wells. sasb.ifrs

That absence matters. If an investor can see total ARO but cannot see how much of it is tied to aging California idle wells, how much is backed by financial assurance, and how much depends on optimistic assumptions about timing and cost, then the investor cannot reliably assess abandonment risk. Likewise, if communities cannot identify which nearby wells are idle, who owns them, and whether they are secured, they cannot evaluate local exposure.

The policy conclusion is not that SASB or GRI are useless. Rather, they are insufficient by themselves. California needs a state-specific, mandatory, auditable idle-well-liability disclosure regime.

5. Is an independent data layer necessary?

The key governance question is whether California can rely on CalGEM’s existing information systems and operator-reported data, or whether it needs an independent intermediary layer that validates and synthesizes information.

CalGEM already has meaningful infrastructure. WellSTAR is the agency’s statewide tracking and reporting system; it is a comprehensive electronic database designed to support data collection, analysis, reporting, and regulatory processes. The public-facing Well Finder allows users to search wells and facilities by address, geographic coordinates, API number, field, and related location information, and it is updated nightly through the WellSTAR database. The CalGEM Data Dashboard also provides production, permitting, incident, and related data that users can filter by location, operator, field, and well identifier. conservation.ca

This is a strong foundation, but not a complete answer. Regulatory databases usually report operational and legal status; they do not necessarily integrate financial assurance adequacy, projected closure cost, bankruptcy probability, ownership-chain changes, inspection findings, methane risk, and public-health proximity in one standardized record.

The missing function

The state does not necessarily need a new private intermediary that replaces CalGEM. It does need an independent verification and reconciliation function between operator self-reporting, state enforcement data, financial disclosures, and public-facing risk information.

That function should perform five tasks:

• Reconcile ownership: Match every well and facility to the legally responsible operator, parent entity, beneficial control relationship, and transfer history.
• Estimate liability: Produce updated, risk-adjusted estimates of plugging, abandonment, restoration, and post-closure monitoring costs.
• Verify security: Compare those estimates with bonds, letters of credit, escrow funds, insurance, or other enforceable assurance.
• Flag risks: Identify wells and operators with nonpayment, noncompliance, methane, integrity, financial-distress, or sensitive-receptor risk.
• Publish usable data: Make the results searchable by well, operator, community, county, and field.

The model should be comparable to independent financial audit rather than a substitute regulator. Operators would still submit data; CalGEM would retain legal authority; but a transparent methodology and periodic third-party verification would reduce the informational asymmetry that enables liability dumping.

Minimum public data fields

A robust public registry should disclose, at minimum:

6. Applying the 4R framework

The 4R framework—Reduce, Replace, Reuse, Recycle—helps distinguish policy priorities that are often blurred together.

Reduce: prevent new abandonment liabilities

Reduce is the first and most important strategy. California should reduce the creation of future orphan wells rather than focus only on cleaning up the existing stock.

Policies include:

• Require full-cost, risk-adjusted financial assurance before drilling, acquisition, or transfer.
• Raise assurance as wells become older, less productive, or more likely to become idle.
• Require annual recalibration of closure-cost estimates using current labor, material, inflation, methane-control, and site-restoration assumptions.
• Restrict new permits for operators with unpaid AB 1866 fees, failed IWMP commitments, or insufficient security.
• Create automatic escalation: missed payments or plan milestones should trigger permit restrictions, enhanced bonds, liens, and transfer prohibitions.
• Apply change-of-control review to stock deals, mergers, affiliate restructurings, and other transactions that can shift practical responsibility without a simple asset transfer.

The objective is to make it uneconomic to treat plugging as an optional future cost.

Replace: substitute cleaner energy and lower-risk assets

Replace concerns the broader energy transition. As California reduces dependence on mature oil fields, it can reduce the pressure to maintain marginal wells solely in hopes of a temporary price rebound. Replacement does not itself resolve legacy liabilities, but it changes the long-run economic context in which those liabilities arise.

The policy caution is important: replacing fossil-fuel output with lower-carbon energy should not leave a shrinking production base responsible for a growing cleanup burden. A managed transition needs an explicit decommissioning-finance strategy so that closure obligations are funded while operating cash flow still exists.

Reuse: convert appropriate wells or sites

Reuse can be valuable where a well or site has a credible new use, such as:

• Geothermal energy development.
• Carbon-dioxide storage, where geology, engineering, permitting, monitoring, and long-term liability requirements are satisfied.
• Lithium or produced-water-related projects where technically and environmentally appropriate.
• Industrial redevelopment, solar generation, habitat restoration, or other site-level reuse after safe closure.

Reuse is not the same as recycling. A reused well remains an engineered subsurface asset with continuing operational and monitoring obligations. A recycled site is one that has been plugged, remediated, and returned to a safe alternative land use.

The principal danger is “reuse-washing”: labeling a well as a future geothermal or carbon-storage candidate in order to postpone plugging without a financed project, credible permit pathway, engineering basis, or deadline. California should require a reuse proponent to post security and meet development milestones. If milestones are missed, the well should be plugged and the site reclaimed.

Recycle: reclaim the land

In this context, Recycle means returning the land and associated infrastructure to a safe, productive condition after the well is permanently closed. This may include plugging, equipment removal, soil remediation, habitat restoration, site redevelopment, and long-term monitoring where needed.

The policy hierarchy should be:

[ \text{Reduce new liabilities} \rightarrow \text{Reuse only when technically and financially credible} \rightarrow \text{Recycle through closure and reclamation}. ]

That ordering prevents circular-economy language from becoming a rationale for indefinite inactivity.

7. Legal and regulatory uncertainty

Businesses dislike uncertainty because it complicates investment, reserve valuation, acquisition decisions, and long-term planning. California’s oil-and-gas sector faces several forms of uncertainty simultaneously: oil-price volatility, changing federal policy, litigation, climate regulation, local restrictions, and potentially rising closure costs.

Senate Bill 1137 is a prominent example. The law establishes 3,200-foot health-protection zones around sensitive receptors for new oil-and-gas development. In January 2026, the U.S. Department of Justice sued California, alleging that the law was preempted by federal statutes. In March 2026, a federal court denied the federal government’s request for a preliminary injunction, meaning the law remained in effect while the litigation continued; the case was scheduled for trial in November 2026. justice

This uncertainty has two implications for idle-well policy.

First, regulatory uncertainty can accelerate the risk of abandonment. If firms expect restrictions on drilling, higher compliance costs, or lower future production, marginal assets may become less valuable and closure liabilities more salient.

Second, uncertainty is not a reason to weaken financial assurance. It is a reason to strengthen it. When the future of production is uncertain, the state should ensure that obligations are funded earlier, while operators remain solvent and assets retain value.

8. Policy recommendations

California should adopt a layered system that combines prevention, funding, data transparency, and enforcement.

Recommendation 1: Require full-cost, risk-adjusted assurance

CalGEM should require assurance equal to independently estimated plugging, abandonment, site-restoration, and necessary post-closure monitoring costs—not merely a historical blanket bond. Requirements should adjust annually for:

• Well age and duration of idleness.
• Technical difficulty and depth.
• Urban or environmentally sensitive location.
• Methane and integrity risk.
• Operator financial condition.
• Inflation, labor, and material costs.
• Transfer and ownership-change risk.

Recommendation 2: Create an industry-financed cleanup backstop

California should establish or strengthen a dedicated orphan-well fund financed by the industry through a combination of:

• Idle-well fees.
• Risk-weighted annual assessments.
• Transfer fees for high-liability transactions.
• Penalties for late payment and noncompliance.
• A production-linked levy that captures revenue while wells are productive.
• Recovery actions against parent entities, affiliates, successors, and responsible predecessors where legally appropriate.

The fund should be used for wells with no financially viable responsible party, not as a subsidy for operators that could have paid.

Recommendation 3: Close transaction loopholes

AB 1167 should be implemented and, if necessary, amended to cover economic transfers of control rather than only conventional asset transactions. This should include:

• Stock-for-stock mergers.
• Changes in corporate control.
• Affiliate transactions.
• Spin-offs and reorganizations.
• Transfers through bankruptcy or receivership.
• Multi-step deals designed to separate productive assets from closure liabilities.

The state should review the buyer’s financial capacity and require replenishment of assurance after material changes in market conditions or closure-cost assumptions.

Recommendation 4: Enforce AB 1866 through automatic escalation

A missed fee or management-plan deadline should automatically trigger a sequence of escalating consequences:

1. Public noncompliance flag in the well registry.
2. Prohibition on new drilling permits and certain transfers.
3. Increased financial assurance.
4. Administrative penalties and collection action.
5. Liens or other legal claims where authorized.
6. A finding of desertion or abandonment where statutory conditions are met.
7. State-led plugging financed first from the operator’s security and recoverable assets.

The goal is not merely to punish. It is to act before noncompliance becomes insolvency.

Recommendation 5: Build a public liability dashboard

California should expand WellSTAR and related public tools into a unified idle-well-liability dashboard. The dashboard should connect operational status with financial and compliance information and allow communities, investors, researchers, and policymakers to see where the risks are accumulating.

CalGEM already maintains searchable, standardized well information through WellSTAR, Well Finder, and its data dashboard. The next step is integration: status data must be joined to liability estimates, assurance coverage, enforcement status, and transfer history. conservation.ca

Recommendation 6: Require issuer-level and operator-level disclosure

Publicly traded operators with material California operations should disclose, in annual reports or standardized supplements:

• California-specific ARO.
• Number of active, idle, and long-term idle wells.
• Total estimated plugging and restoration liability by well status.
• Amount and form of financial assurance.
• Coverage ratio: assurance divided by estimated closure cost.
• Cleanup expenditures and wells plugged during the reporting year.
• Transfers completed, rejected, or pending.
• Assumptions used to estimate closure cost.
• Sensitivity of ARO to inflation, discount rates, regulation, and timing.
• Material noncompliance with state idle-well obligations.

These metrics would supplement—not replace—existing GRI, SASB, and financial-statement reporting.

Recommendation 7: Encourage reuse without allowing delay

California should support pilot projects for geothermal, carbon storage, lithium-related development, and productive site reuse. But each reuse proposal should include:

• Engineering feasibility documentation.
• A binding development schedule.
• Separate financial assurance for the new use.
• Clearly assigned long-term liability.
• A contingency plan and funded obligation to plug and reclaim if the project does not proceed.

Reuse should be a genuine conversion, not a holding pattern.

Conclusion

The question “Who pays for the hole in the ground?” has a clear normative answer: the industry that created, operated, and benefited from the well should pay for its safe closure. California’s AB 1866 and AB 1167 represent important movement toward that outcome. AB 1866 begins to price continued idleness and requires management planning; AB 1167 addresses the transfer of marginal-well liabilities to weaker buyers. Yet neither statute can succeed fully if unpaid fees, incomplete plans, weak bonds, opaque corporate transactions, and fragmented data allow liability to escape.

California’s challenge is not simply to plug more wells. It is to redesign the financial and informational system so that plugging is treated as an unavoidable cost of production from the beginning of a well’s life. The state should require full-cost, risk-adjusted assurance; preserve a polluter-financed orphan-well backstop; review all meaningful changes of control; impose automatic consequences for noncompliance; and publish an independently validated well-liability registry.

The larger lesson extends beyond California oil and gas. Environmental liabilities become public liabilities when they are deferred, under-measured, and transferred to entities unable to pay. A credible polluter-pays system must therefore do three things at once: measure the obligation accurately, secure the money before distress occurs, and enforce responsibility when firms attempt to escape it. Without those elements, the taxpayer remains the insurer of last resort for private extraction.