Sable Offshore (SOC) 424B3Prospectus supplement

Filed Pursuant to Rule 424(b)(3)
Registration No. 333-282622

PROSPECTUS

7,500,000 Shares of Common Stock

This prospectus relates to the offer and sale from time to time by the selling securityholders named in this prospectus (the “Selling Holders”), or their permitted transferees, of up to 7,500,000 shares of our Common Stock, $0.0001 par value (“Common Stock”) of Sable Offshore Corp. (formerly known as Flame Acquisition Corp.) (the “Company”) issued in a committed PIPE investment of $150,000,000 (the “Second PIPE Investment”) at an equity consideration value of $20.00 per share by certain of the Selling Holders named in this prospectus. We are registering the securities for resale pursuant to the Selling Holders’ registration rights under certain agreements between us and the Selling Holders, as applicable to each Selling Holder. Our registration of the securities covered by this prospectus does not mean that the Selling Holders will offer or sell any of the securities. The Selling Holders may offer, sell or distribute all or a portion of their shares of Common Stock publicly or through private transactions at prevailing market prices or at negotiated prices. We will not receive any of the proceeds from any resale of the Common Stock being offered for resale in this prospectus (the “Resale Securities”). We provide more information about how the Selling Holders may sell their securities in the section of this prospectus entitled “Plan of Distribution.” We have agreed to bear all of the expenses incurred in connection with the registration of these securities. The Selling Holders will pay or assume underwriting fees, discounts and commissions or similar charges, if any, incurred in the sale of securities by them.

We may amend or supplement this prospectus from time to time by filing amendments or supplements as required.

Our Common Stock and Public Warrants are listed on the New York Stock Exchange (the “NYSE”) under the symbols “SOC” and “SOC.WS,” respectively. On October 31, 2024, the closing price of our Common Stock was $22.36 per share and the closing price of our Public Warrants was $11.38 per warrant.

The Resale Securities represent a substantial percentage of the total outstanding shares of our Common Stock as of the date of this prospectus. The shares of Common Stock that the Selling Holders can sell into the public markets pursuant to this prospectus is up to 7,500,000 shares of Common Stock, constituting approximately 9.2% of our issued and outstanding shares of Common Stock and approximately 13.1% of our issued and outstanding shares of Common Stock held by non-affiliates. The sale of all the Resale Securities or the perception that these sales could occur, could result in a significant decline in the public trading price of our securities. See the section of this prospectus entitled “Risk Factors—Risks Related to Being a Public Company— Sales of a substantial number of our securities in the public market by the Selling Holders or by our existing securityholders could cause the price of our shares of Common Stock to fall.”

We are an “emerging growth company” under applicable Securities and Exchange Commission rules and will be eligible for reduced public company reporting requirements. See “Prospectus Summary—Emerging Growth Company; Smaller Reporting Company.”

Investing in our Common Stock involves risks. For a discussion of the material risks that you should consider, see “Risk Factors” beginning on page 17 of this prospectus.

None of the Securities and Exchange Commission or any state securities commission has approved or disapproved of these securities or determined if this prospectus is accurate or complete. Any representation to the contrary is a criminal offense.

The date of this Prospectus is November 1, 2024

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RISK FACTORS

You should carefully consider the risks and uncertainties described below and the other information in this prospectus before making an investment in our Common Stock. Our business, financial condition, results of operations, or prospects could be materially and adversely affected if any of these risks occurs, and as a result, the market price of our Common Stock could decline and you could lose all or part of your investment. This prospectus also contains forward-looking statements that involve risks and uncertainties. See “Cautionary Note Regarding Forward-Looking Statements.” Our actual results could differ materially and adversely from those anticipated in these forward-looking statements as a result of certain factors, including those set forth below.

Risks Related to Restart of Production

We need to satisfy a number of permitting obligations and other requirements before we can restart production of the SYU Assets. The requirements to restart Lines 324 and 325 include those set forth in a Consent Decree with federal and state agencies. While the operator of the lines has satisfied most of the conditions to restart including under the Consent Decree, there is no assurance that we will be successful in satisfying the remainder of the requirements and restarting production of the SYU Assets in a timely manner.

SYU suspended production as a result of the Line 324 incident and consequent suspension of service, and our business depends on its production restarting. We need to satisfy a number of requirements related to SYU and Lines 324 and 325 before we can restart production. Such requirements include conditions set forth in a U.S. federal district court Consent Decree executed by Plains and relevant U.S. and State of California government agencies. For further information, see “Business—Pipeline 324 Incident.” While the previous operator of Lines 324 and 325 satisfied most of the conditions to restart including under the Consent Decree, there is no assurance that we will be successful in satisfying the remaining requirements and restarting production in a timely manner. If we fail to restart production by January 1, 2026, the prior owner of SYU may exercise its right to cause us to reassign the SYU Assets. See “Risk Factors—Risks Related to the Business of the Company—We may be unable to restart production of SYU by January 1, 2026, which would permit EM to exercise a reassignment option and take ownership of SYU without any compensation or reimbursement other than the deemed repayment in full of the principal and accrued interest outstanding under the Term Loan.”

Our assumptions and estimates regarding the total costs associated with restarting production may be inaccurate.

We currently estimate the total costs we will incur in order to restart production to be approximately $197,000,000. The expenditures will primarily be directed toward obtaining the necessary regulatory approvals and completing the pipeline repairs and bringing the shut-in assets back online in fourth quarter 2024. This estimate of costs to restart production considers currently available facts and presently enacted laws and regulations, but it is subject to uncertainties associated with the assumptions that we have made. For example, the costs of equipment, repairs and maintenance, the costs of operating personnel, the costs to obtain governmental approvals, and legal, consulting and other professional expenses could turn out to be higher than we have estimated. Accordingly, our assumptions and estimates may change in future periods based on future events and total costs may materially increase; therefore, we can provide no assurance that we will not have to incur additional costs in future periods significantly higher than our estimated costs for the restart of production.

There is no guarantee that we will have sufficient cash to restart production of the SYU Assets.

Until we restart production of the SYU Assets, we will not generate any revenue or cash flows from operations. We will rely on cash on hand to fund the operations necessary to restart production of the SYU Assets. If we do not have sufficient cash on hand to restart production of SYU, we may need to raise additional capital to continue our operations, and this capital may not be available on acceptable terms or at all. If we do not have sufficient cash on hand or are unable to obtain additional funding on a timely basis, we may be unable to restart production

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of SYU, which could materially affect our business, financial condition and results of operations. See “Risk Factors— Risks Related to the Business of the Company—We may be unable to restart production of SYU by January 1, 2026, which would permit EM to exercise a reassignment option and take ownership of SYU without any compensation or reimbursement other than the deemed repayment in full of the principal and accrued interest outstanding under the Term Loan.”

Risks Related to the Business of the Company

Oil, natural gas and natural gas liquids, or “NGL(s)”, prices are volatile, due to factors beyond our control, and greatly affect our business, results of operations and financial condition. Any decline in, or sustained low levels of, oil, natural gas and NGL prices will cause a decline in our cash flow from operations, which could materially and adversely affect our business, results of operations and financial condition.

Our revenues, operating results, profitability, liquidity, future growth and the value of our assets depend primarily on prevailing commodity prices. Historically, oil and natural gas prices have been volatile and fluctuate in response to changes in supply and demand, market uncertainty, and other factors that are beyond our control, including:

These factors and the volatility of the energy markets make it extremely difficult to predict future oil, natural gas and NGL price movements with any certainty. For example, for the five years ended December 31, 2023, the

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NYMEX-WTI oil futures price ranged from a high of $123.70 per Bbl to a low of $(37.63) per Bbl, while the NYMEX-Henry Hub natural gas futures price ranged from a high of $9.68 per MMBtu to a low of $1.48 per MMBtu. For the year ended December 31, 2023, the NYMEX-WTI oil futures price ranged from a high of $93.68 per Bbl on September 27, 2023 to a low of $66.74 per Bbl on March 17, 2023 and the NYMEX-Henry Hub natural gas futures price ranged from a high of $4.17 per MMBtu on January 4, 2023 to a low of $1.99 per MMBtu on March 29, 2023. Likewise, NGLs, which are made up of ethane, propane, isobutane, normal butane and natural gasoline, each of which has different uses and different pricing characteristics, have sustained depressed realized prices during this period and are generally correlated with the price of oil. While recent events have led to elevated oil, natural gas and NGL prices, an extended decline in commodity prices could materially and adversely affect our business, results of operations and financial condition.

If commodity prices decline and remain depressed for a prolonged period, our business may become uneconomical and result in additional write downs of the value of our properties, which may adversely affect our financial condition and our ability to fund operations.

Oil, natural gas and NGL prices have experienced significant volatility over the past few years. An extended decline in commodity prices could render our business uneconomical and result in a downward adjustment of our assets, which would reduce our ability to fund our operations. An extended decline, or sustained marked uncertainty, in commodity prices may cause us to write down, as a non-cash charge to earnings, the carrying value of our oil and natural gas properties for impairments. We may in the future incur impairment charges that could have a material adverse effect on our results of operations in the period taken. Sustained declines or uncertainty in commodities prices may adversely affect our financial condition, results of operations, ability to reduce debt, ability to pay dividends and the timing of our capital projects.

An increase in the differential between the NYMEX or other benchmark prices of oil and natural gas and the wellhead price we expect to receive for our future production could significantly reduce our cash flow and adversely affect our financial condition.

The prices that we expect to receive for our future oil and natural gas production will often reflect a regional discount, based on the location of production, to the relevant benchmark prices, such as NYMEX or ICE, that are used for calculating hedge positions. The prices we expect to receive for our future production are also affected by the specific characteristics of the production relative to production sold at benchmark prices. For example, California oil typically has a lower gravity, and a portion typically has higher sulfur content, than oil sold at certain benchmark prices. Therefore, because our oil will likely require more complex refining equipment to convert it into high value products, it may sell at a discount to those prices. These discounts, if significant, could reduce our cash flows and adversely affect our results of operations and financial condition.

The estimated quantities of petroleum contained in the SYU Assets are classified as “contingent resources” rather than “reserves” because they are subject to numerous contingencies. There is no assurance that any of the petroleum contained in the SYU Assets will ever be recovered or reclassified as “reserves.”

The resources are contingent upon (1) approval from federal, state and local regulators to restart production, (2) reestablishment of oil transportation systems to deliver production to market and (3) commitment to restart the wells and facilities. Some or all of the contingent resources may be reclassified as “reserves” if all of the contingencies are successfully resolved but there is no assurance that the contingencies will be resolved or resolved in a timely manner or that any of the petroleum in the SYU Assets will be recovered.

Our hedging strategy in the future may not effectively mitigate the impact of commodity price volatility from our cash flows, and our hedging activities could result in cash losses and may limit potential gains.

We expect that we will develop and maintain a portfolio of commodity derivative contracts covering a specified percentage or range of our estimated production from proved developed producing reserves over a one-to-three-year period at any given point in time. These commodity derivative contracts may include natural

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gas, oil and NGL financial swaps. The prices and quantities at which we enter into commodity derivative contracts covering our production in the future will be dependent upon oil and natural gas prices and price expectations at the time we enter into these transactions, which may be substantially higher or lower than current or future oil and natural gas prices. Accordingly, our price hedging strategy may not protect us from significant declines in oil, natural gas and NGL prices received for our future production. Many of the derivative contracts to which we will be a party will require us to make cash payments to the extent the applicable index exceeds a predetermined price, thereby limiting our ability to realize the benefit of increases in oil, natural gas and NGL prices. If our actual production and sales for any period are less than our hedged production and sales for that period (including reductions in production due to operational delays) or if we are unable to perform our drilling activities as planned, we might be forced to satisfy all or a portion of our hedging obligations without the benefit of the cash flow from our sale of the underlying physical commodity, which may materially impact our liquidity.

Developing and producing oil, natural gas and NGLs are costly and high-risk activities with many uncertainties that may result in a total loss of investment or otherwise adversely affect our business, financial condition, results of operations and cash flows. Many of these risks are heightened for us due to the fact that most of our equipment has been shut-in for more than eight years.

Our development and production operations may be curtailed, delayed, canceled or otherwise negatively impacted as a result of many factors, including:

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Many of these risks are heightened for us due to the fact that most of our equipment has been shut-in for more than eight years. Any of these risks can cause substantial losses, including personal injury or loss of life, damage to or destruction of property, natural resources and equipment, pollution, environmental contamination or loss of wells and other regulatory penalties. In the event that planned operations are delayed or canceled, or existing wells or development wells have lower than anticipated production due to one or more of the factors above or for any other reason, our financial condition and results of operations may be adversely affected. If any of these factors were to occur with respect to a particular field, we could lose all or a part of our investment in the field or we could fail to realize the expected benefits from the field, either of which could materially and adversely affect our business, financial condition, results of operations and cash flows.

The enactment of derivatives legislation could have an adverse effect on our ability to use derivative instruments to reduce the effect of commodity price, interest rate and other risks associated with our business.

The Dodd-Frank Wall Street Reform and Consumer Protection Act (“Dodd-Frank Act”), enacted in 2010, establishes federal oversight and regulation of, among other things, the over-the-counter derivatives market and certain participants in that market, including us. Rules and regulations applicable to over-the-counter derivatives transactions may affect both the size of positions that we may hold and the ability or willingness of counterparties to trade opposite us, potentially increasing costs for transactions. Moreover, such changes could materially reduce our hedging opportunities which could adversely affect our revenues and cash flow during periods of low commodity prices. While many Dodd-Frank Act regulations are already in effect, the rulemaking and implementation process is ongoing, and the ultimate effect of the adopted rules and regulations and any future rules and regulations on our business remains uncertain. See “Business—Other Regulation of the Oil and Natural Gas Industry—Derivatives Regulation” for additional information.

Development and production of oil, natural gas and NGLs in offshore waters have inherent and historically higher risk than similar activities onshore.

Our offshore operations are subject to a variety of operating risks specific to the marine environment, such as a dependence on a limited number of electrical transmission lines, as well as capsizing, collisions and damage or loss from adverse weather conditions. Offshore activities are subject to more extensive governmental regulation than onshore oil and natural gas activities. We are vulnerable to the risks associated with operating offshore California, including risks relating to:

In addition to lost production and increased costs, these hazards could cause serious injuries, fatalities, contamination or property damage for which we could be held responsible. The potential consequences of these hazards are particularly severe for us because significant portions of our offshore operations are conducted in environmentally sensitive areas, including areas with significant residential populations and public and commercial infrastructure. An accidental oil spill or release on or related to offshore properties and operations could expose us to joint and several strict liability, without regard to fault, under applicable law for all

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containment and oil removal costs and a variety of public and private damages including, but not limited to, the costs of remediating a release of oil, natural resource damages, and economic damages suffered by persons adversely affected by an oil spill. If an oil discharge or substantial threat of discharge were to occur, we may be subject to regulatory scrutiny and liable for costs and damages, which costs and damages could be material to our business, financial condition or results of operations and could subject us to criminal and civil penalties. Finally, maintenance activities undertaken to reduce operational risks can be costly and can require exploration, exploitation and development operations to be curtailed while those activities are being completed.

Oil and natural gas producers’ operations are substantially dependent on the availability of water and the disposal of waste, including produced water and drilling fluids. Restrictions on the ability to obtain water or dispose of waste may impact our operations.

Water is an essential component of oil and natural gas production during the drilling and production process. Our inability to locate sufficient amounts of water, or dispose of or recycle water used in our development and production operations, could adversely impact our operations. Moreover, the imposition of new environmental initiatives and regulations could include restrictions on our ability to conduct certain operations such as disposal of waste, including, but not limited to, produced water, drilling fluids and other wastes associated with the exploration, development or production of oil and natural gas. The Clean Water Act imposes restrictions and strict controls regarding the discharge of produced waters and other natural gas and oil waste into “waters of the United States.” Permits must be obtained to discharge pollutants to such waters and to conduct construction activities in such waters, which include certain wetlands. The Clean Water Act and similar state laws provide for civil, criminal and administrative penalties for any unauthorized discharges of pollutants and unauthorized discharges of reportable quantities of oil and other hazardous substances. State and federal discharge regulations prohibit the discharge of produced water and sand, drilling fluids, drill cuttings and certain other substances related to the natural gas and oil industry into coastal waters. Compliance with current and future environmental regulations and permit requirements governing the withdrawal, storage and use of surface water or groundwater necessary for the disposal and recycling of produced water, drilling fluids and other wastes may increase our operating costs and cause delays, interruptions or termination of our operations, the extent of which cannot be predicted. In addition, in some instances, the operation of underground injection wells for the disposal of waste has been alleged to cause earthquakes. In some jurisdictions, such issues have led to orders prohibiting continued injection or the suspension of drilling in certain wells identified as possible sources of seismic activity or resulted in stricter regulatory requirements relating to the location and operation of underground injection wells. Any orders or regulations addressing concerns about seismic activity from well injection in jurisdictions where we operate could affect our operations. See “Business—Environmental, Occupational Safety and Health Matters and Regulations—Water Discharges” for an additional description of the laws and regulations relating to the discharge of water and other wastes that affect us.

The unavailability or high cost of rigs, equipment, supplies and crews could delay our operations, increase our costs and delay forecasted revenue.

Our industry is cyclical, and historically there have been periodic shortages of rigs, equipment, supplies and crew. Sustained declines in oil and natural gas prices may reduce the number of service providers for such rigs, equipment, supplies and crews, contributing to or resulting in shortages. Alternatively, during periods of higher oil and natural gas prices, the demand for rigs, equipment, supplies and crews is increased and can lead to shortages of, and increasing costs for, development equipment, supplies, services and personnel. While we have mitigated some of these issues with our dedicated rig, shortages of, or increasing costs for, experienced development crews and oil field equipment and services could restrict our ability to drill the wells and conduct the operations that we currently have planned relating to the fields where our properties are located. In addition, some of our operations require supply materials for production, such as CO2, which could become subject to shortages and increased costs. Any delay in the development of new wells or a significant increase in development costs could reduce our revenues and impact our development plan, which would thus affect our financial conduction, results of operations and our cash flows.

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The third parties on whom we rely for transportation services are subject to complex federal, state and other laws that could adversely affect the cost, manner or feasibility of conducting our business.

The operations of the third parties on whom we rely for transportation services are subject to complex and stringent laws and regulations that require obtaining and maintaining numerous permits, approvals and certifications from various federal, state and local government authorities. These third parties may incur substantial costs in order to comply with existing laws and regulations. If existing laws and regulations governing such third-party services are revised or reinterpreted, or if new laws and regulations become applicable to their operations, these changes may affect the costs that we pay for such services. Similarly, a failure to comply with such laws and regulations by the third parties on whom we rely for transportation services could impact the availability of those services. Any potential impact to the availability of transportation services could impact our ability to market and sell our production, which could have a material adverse effect on our business, financial condition and results of operations. See “Business—Environmental, Occupational Safety and Health Matters and Regulations” and “Business—Other Regulation of the Oil and Natural Gas Industry” for a description of the laws and regulations that affect the third parties on whom we rely for transportation services.

Our business depends in part on pipelines, gathering systems and processing facilities owned by us or others. Any limitation in the availability of those facilities could interfere with our ability to market our oil, natural gas and NGL production.

The marketability of our oil, natural gas and NGL production depends in part on the availability, proximity and capacity of pipelines and other transportation methods, gathering systems and processing facilities owned by us or third parties. The amount of oil, natural gas and NGLs that can be produced and sold is subject to curtailment in certain circumstances, such as pipeline interruptions due to scheduled and unscheduled maintenance, excessive pressure, physical damage or lack of contracted capacity on such systems. For example, our ability to produce and sell oil from SYU will depend on the continued availability of the pipeline infrastructure between platforms, for delivery of that oil to shore, and for further delivery to market, and any unavailability of that pipeline infrastructure could cause us to shut in all or a portion of the production from the SYU properties for the length of such unavailability. Our access to transportation options can also be affected by U.S. federal and state regulation of oil and natural gas production and transportation, general economic conditions and changes in supply and demand. The curtailments arising from these and similar circumstances may last from a few days to several months or more. In many cases, we are provided with only limited, if any, notice as to when these circumstances will arise and their duration. Any significant curtailment in gathering system or transportation or processing facility capacity could reduce our ability to market our oil and natural gas production and harm our business, financial condition, results of operations and cash flows. See “Business—Grey Fox Matter” for additional information.

Our independent registered public accounting firm’s report contains an explanatory paragraph that expresses substantial doubt about our ability to continue as a “going concern.”

Management believes the Company has sufficient capital to maintain operations and complete the repairs necessary to restart production at SYU. However, the Company’s plans for production restart are contingent upon approvals from federal, state and local regulators. Additionally, if the Company’s estimates of the costs of restarting production are less than the actual amounts necessary to do so, the Company may have insufficient funds available to operate its business prior to first production and will need to raise additional capital. If the Company is unable to raise additional capital, it may be required to take additional measures to conserve liquidity, which could include, among other things, suspending repair efforts and reducing overhead expenses. The Company cannot provide any assurance that new financing will be available to it on commercially acceptable terms, if at all.

Due to the remaining regulatory approvals necessary to restart production, along with the timing of ongoing construction repair efforts, substantial doubt exists about the Company’s ability to continue as a going concern.

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Loss of our key executive officers or other key personnel, or an inability to attract and retain such officers and personnel, could negatively affect our business and, in one instance, could cause a default under the primary agreement governing our existing indebtedness.

Our future success depends on the skills, experience and efforts of our executive officers. The sudden loss of any of these executives’ services or our failure to appropriately plan for any expected executive succession could materially and adversely affect our business and prospects, as we may not be able to find suitable individuals to replace them on a timely basis, if at all. Additionally, we also depend on our ability to attract and retain qualified personnel to operate and expand our business. If we fail to attract or retain talented new employees, our business and results of operations could be negatively affected. Workers may choose to pursue employment with our competitors or in other fields. Additionally, the Senior Secured Term Loan Agreement (the “Term Loan”), dated as of the Closing Date by and among Sable, EMC, as lender, and Alter Domus Products Corp., as the administrative agent for the benefit of the lender, requires that James C. Flores, our Chairman and Chief Executive Officer, remains directly and actively involved in the day-to-day management of our business, subject to the right of the holder of such indebtedness to approve his replacement, such approval not to be unreasonably withheld.

We may incur losses as a result of title defects or deficiencies in our properties.

The existence of a material title deficiency can render a lease worthless and can adversely affect our results of operations and financial condition. While we have done extensive title diligence in connection with the Business Combination and typically obtain title opinions prior to commencing drilling operations on a lease or in a unit, the failure of title or other defects or deficiencies may not be discovered until after a well is drilled, in which case we may lose the lease and the right to produce all or a portion of the minerals under the property.

We do not own all of the land on which our assets are located or all of the land that we must traverse in order to conduct our operations. There are disputes with respect to certain of the rights-of-way or other interests and any unfavorable outcomes of such disputes could require us to incur additional costs.

We do not own in fee all of the land on which our assets are located or all of the land that we must traverse in order to conduct our operations. Rather, many of the properties or rights are derived from surface use agreements, rights-of-way or other easement rights and, therefore, we will be subject to the possibility of more onerous terms or increased costs to retain necessary land access if we do not have valid rights-of-way or if such rights-of-way lapse or terminate. Some of the rights to land owned by third parties and governmental agencies are obtained for a specific period of time and under certain conditions. We believe that we will have obtained sufficient right-of-way grants from public authorities (subject to receipt of certain governmental permits and consents) and private parties for us to operate our business. However, certain private landowners along sectors of the Pipelines have made claims that the easement agreements with them are no longer effective because the pipeline is not transporting oil. If these landowners are successful with their claims, we may be required to make further easement payments. Our loss of any of these surface use agreements, rights-of-way or other easement rights through lapse or failure to satisfy or maintain certain conditions could require us to cease operations on the affected land or find alternative locations for our operations at increased costs, any of which could have a material adverse effect on our business, financial condition and results of operations.

We may be unable to restart production by January 1, 2026, which would permit EM to exercise a reassignment option and take ownership of SYU without any compensation or reimbursement other than the deemed repayment in full of the principal and accrued interest outstanding under the Term Loan.

If we fail to restart production of the SYU Assets by January 1, 2026 (the “Restart Failure Date”), then pursuant to the Purchase and Sale Agreement dated November 1, 2022, by and among Legacy Sable, EMC and MPPC relating to the purchase of SYU and the Pipelines (“Sable-EM Purchase Agreement”), for 180 days thereafter, EM will have the exclusive right, but not the obligation, to require us to reassign the SYU Assets and rights to

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EM or its designated representative, without reimbursing us for any of our costs or expenditures (the “Reassignment Option”). If we have acquired any additional rights or assets or have developed additional improvements related to the SYU Assets, records or benefits, on EM’s request we also would be required to assign and deliver those additional rights, assets, improvements, records or benefits to EM without being reimbursed for any of our additional costs or expenses. If we are unable to restart production of the SYU Assets by the Restart Failure Date and EM exercises its Reassignment Option, EM will become the owner of substantially all of our business and we may be forced to wind-down our operations. Our ability to restart production of the SYU Assets is subject to several risks, and there is no assurance that we will be able to restart production of the SYU Assets by the Restart Failure Date. See “Risk Factors—Risks Related to the Restart of Production.”

Restrictive covenants in the Term Loan or any future agreements governing our indebtedness could limit our growth and our ability to finance our operations, fund our capital needs, respond to changing conditions and engage in other business activities that may be in our best interests.

Restrictive covenants in the Term Loan impose significant operating and financial restrictions on us and our subsidiaries and we may be prevented from taking advantage of business opportunities that arise because of the limitations imposed on us by the Term Loan unless we gain EM’s consent. These restrictions limit our ability to, among other things:

The Term Loan also contains representations and warranties, affirmative covenants, additional negative covenants and events of default (including a change of control). During the pendency of the Term Loan and in case of an event of default thereunder, EM may exercise all remedies at law or equity, and may foreclose upon substantially all of our assets and the assets of our subsidiaries, including, in the event of a deficiency, cash and any other assets not acquired from EM in the Business Combination to the extent constituting collateral under the applicable financing documents. We may not be able to obtain amendments, waivers or consents for potential or actual breaches of such representations and warranties or covenants, or we may be unable to obtain such amendments waivers or consents on acceptable terms, all of which could limit management’s flexibility to operate the business.

Under the terms of the Term Loan, restarting production will trigger a springing maturity date following a specified grace period, and the terms on which we will be able to refinance the Term Loan, if necessary, will depend on then-prevalent market conditions.

The Term Loan includes a springing maturity date of ninety (90) days after Restart Production (as defined in the Sable-EM Purchase Agreement) (i.e., one hundred eighty (180) days after resumption of actual production from the wells), which could require a future refinancing of the indebtedness under the Term Loan or the incurrence of new indebtedness. The terms on which we would be able to obtain any refinancing of the Term Loan will depend on market conditions at the time of any such refinancing.

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We may in the future refinance our existing indebtedness or incur new indebtedness at variable rates and without the option to pay interest in-kind, which would subject us to interest rate risk and could cause our debt service obligations to increase significantly.

The outstanding principal amount under our Term Loan bears interest at a fixed rate and we have the option of capitalizing the interest onto the principal rather than paying cash interest, but we may in the future refinance our existing indebtedness or incur new indebtedness with variable rates and mandatory cash interest payments, which would expose us to interest rate risk and additional liquidity burdens. If interest rates increase, our debt service obligations on the variable rate indebtedness would increase even if the principal amount remained the same, and our net income and cash available for servicing our indebtedness would decrease.

Our business plans require a significant amount of capital. In addition, our future capital needs may require us to issue additional equity or debt securities that may dilute our stockholders or introduce covenants that may restrict our operations or ability to pay dividends.

Our business and operations may consume resources faster than we anticipate. In the future, we may need to raise additional funds through the issuance of new equity or debt securities, or a combination thereof. Additional financing may not be available on favorable terms or at all. If adequate funds are not available on acceptable terms, we may be unable to fund our capital requirements. If we issue new debt, the debt holders would have rights senior to holders of our Common Stock to make claims on our assets and the terms of any debt could restrict our operations, including our ability to pay dividends on our Common Stock. If we issue additional equity securities or securities convertible into equity securities, existing stockholders will experience dilution and the new equity securities could have rights senior to those of our Common Stock. Because our decision to issue securities in any future offering will depend on market conditions and other factors beyond our control, we cannot predict or estimate the amount, timing or nature of our future offerings and their impact on the market price of our Common Stock.

We are exposed to trade credit risk in the ordinary course of our business activities.

We are exposed to risks of loss in the event of nonperformance by our vendors and other counterparties. Some of our vendors and other counterparties may be highly leveraged and subject to their own operating and regulatory risks. Many of our vendors and other counterparties finance their activities through cash flow from operations, the incurrence of debt or the issuance of equity. The combination of reduction of cash flow resulting from declines in commodity prices and the lack of availability of debt or equity financing may result in a significant reduction in our vendors’ and other counterparties’ liquidity and ability to make payments or perform on their obligations to us. Even if our credit review and analysis mechanisms work properly, we may experience financial losses in our dealings with other parties. Any increase in the nonpayment or nonperformance by our vendors or other counterparties could adversely affect our business, financial condition, results of operations and cash flows.

We may incur substantial losses and be subject to substantial liability claims as a result of catastrophic events. We may not be insured for, or our insurance may be inadequate to protect us against, these risks. Expenses not covered by our insurance could have a material adverse effect on our financial position and results of operations.

Our operations are subject to all of the hazards and operating risks associated with drilling for and production of oil and natural gas, including natural disasters, the risk of fire, explosions, blowouts, surface cratering, uncontrollable flows of natural gas, oil and formation water, pipe or pipeline failures, abnormally pressured formations, casing collapses and environmental hazards such as oil spills, natural gas leaks, ruptures or discharges of toxic gases, all of which could cause substantial financial losses. The location of any properties and other assets near environmentally sensitive areas or near populated areas, including residential areas, commercial business centers and industrial sites, could significantly increase the level of potential damages resulting from these risks. Other catastrophic events such as earthquakes, floods, mudslides, fires, droughts, contagious diseases,

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terrorist attacks and other events that cause operations to cease or be curtailed may adversely affect our business and the communities in which we operate. For example, utilities have begun to suspend electric services to avoid wildfires during windy periods in California, a business disruption risk that is not insured. We may be unable to obtain, or may elect not to obtain, insurance for certain risks if we believe that the cost of available insurance is excessive relative to the risks presented. The occurrence of any of these or other similar events could result in substantial losses to us due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigation and penalties, suspension or disruption of operations, substantial revenue losses and repairs to resume operations.

We maintain insurance coverage against potential losses that we believe is customary in the industry. However, insurance against all operational risk is not available to us. These insurance policies may not cover all liabilities, claims, fines, penalties or costs and expenses that we may incur in connection with our business and operations, including those related to environmental claims. Pollution and environmental risks generally are not fully insurable. In addition, we cannot assure you that we will be able to maintain adequate insurance at rates we consider reasonable. We may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the perceived risks presented. A liability, claim or other loss not fully covered by insurance could have a material adverse effect on our business, financial position, results of operations and cash flows.

We may be unable to compete effectively with larger companies.

The oil and natural gas industry is intensely competitive with respect to marketing oil and natural gas and securing equipment and trained personnel. Many of our larger competitors not only drill for and produce oil and natural gas but also carry on refining operations and market petroleum and other products on a regional, national or worldwide basis, which offers them greater access and economies of scale. In addition, there is substantial competition for investment capital in the oil and natural gas industry and many of our competitors have access to capital at a lower cost than that available to us. These larger companies may have a greater ability to continue development activities during periods of low oil and natural gas prices and to absorb the burden of present and future federal, state, local and other laws and regulations. Furthermore, we may not be able to aggregate sufficient quantities of production to compete with larger companies that are able to sell greater volumes of production to intermediaries, thereby reducing the realized prices attributable to our production. Any inability to compete effectively with larger companies could have a material adverse impact on our business activities, financial condition, results of operations and cash flows.

We are subject to complex federal, state, local and other laws, regulations and permits that could adversely affect the cost, manner, ability or feasibility of conducting our operations.

Our oil and natural gas development and production operations are subject to complex and stringent laws and regulations administered by governmental authorities vested with broad authority relating to the exploration for and the development, production and transportation of oil, natural gas, and NGLs. To conduct our operations in compliance with these laws and regulations, we must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. We may incur substantial costs in order to maintain compliance with these existing laws and regulations. Failure to comply with laws and regulations applicable to our operations, including any evolving interpretation and enforcement by governmental authorities, could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Our oil, natural gas, and NGLs development and production operations are also subject to stringent and complex federal, state and local laws and regulations governing the release or discharge of materials into or through the environment, worker health and safety aspects of our operations, or otherwise relating to environmental protection, resource protection, and damage to natural resources. These laws and regulations may impose numerous obligations applicable to our operations, including the ability to obtain a permit before conducting our operations, including regulated drilling activities; the restriction of types, quantities and concentrations of

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materials that can be released or discharged into or through the environment; the limitation or prohibition of drilling, production and transportation activities on certain lands lying within wilderness, wetlands, seismically active areas and other protected or preserved areas; the application of specific health and safety criteria addressing worker protection; and the imposition of substantial liabilities for pollution and natural resources damages potentially resulting from our operations. The U.S. Environmental Protection Agency (“EPA”), Bureau of Ocean Energy Management (“BOEM”) and the Bureau of Safety and Environmental Enforcement (“BSEE”), California Public Utility Commission (“CPUC”), California Department of Forestry and Fire Protection’s Office of the State Fire Marshal (the “OSFM”), California Department of Conservation’s Geologic Energy Management Division (“CalGEM”), and numerous other governmental authorities have the authority to enforce compliance with these laws and regulations and the permits issued by them, often requiring difficult and costly compliance measures or corrective actions. Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil or criminal penalties, the imposition of investigatory or remedial obligations, injunctive and mitigation relief, the suspension or revocation of necessary permits, licenses and authorizations, the requirement that additional pollution controls be installed and, in some instances, the issuance of orders limiting or prohibiting some or all of our operations. We may also experience delays in obtaining or be unable to obtain required permits, including authorizations necessary to restart or replace the Pipelines, which may delay or interrupt our operations and limit our growth and revenue, or may result in a failure to restart production by the Restart Failure Date.

Under certain environmental laws that impose strict as well as joint and several liability, we may be required to remediate or conduct other response actions at or in relation to contaminated properties currently owned or operated by us or facilities of third parties that received waste generated by our operations regardless of whether such contamination resulted from the conduct of others or from the consequences of our own actions that were in compliance with all applicable laws at the time those actions were taken. In addition, claims for damages to persons or property, including natural resources, may result from the environmental, health and safety impacts of our operations. Moreover, public interest in the protection of the environment has increased in recent years. New laws and regulations continue to be enacted, particularly at the state level, and, under the Biden Administration, the long-term trend of more expansive and stringent environmental legislation and regulations applied to the crude oil and natural gas industry could continue, resulting in increased costs of doing business and consequently affecting profitability. To the extent laws are enacted, or other governmental action is taken that restricts drilling, production and transportation activities, or imposes more stringent and costly operating, waste handling, disposal and cleanup requirements, our business, prospects, financial condition or results of operations could be materially adversely affected.

See “Business—Environmental, Occupational Safety and Health Matters and Regulations” and “Business— Other Regulation of the Oil and Natural Gas Industry” for a description of the more significant laws and regulations that affect us.

The listing of a species as either “threatened” or “endangered” under the U.S. Endangered Species Act and/or the California Endangered Species Act could result in increased costs, new operating restrictions, or delays in our operations, which could adversely affect our results of operations and financial condition.

The U.S. Endangered Species Act (the “ESA”) and analogous state laws regulate activities that could have an adverse effect on threatened and endangered species. Operations in areas where threatened or endangered species or their habitat are known to exist may require us to incur increased costs to implement mitigation or protective measures and also may restrict or preclude our activities in those areas or during certain seasons, such as breeding and nesting seasons. The listing of species in areas where we operate or, alternatively, entry into certain range-wide conservation planning agreements could result in increased costs to us from species protection measures, time delays or limitations on our activities, which costs, delays or limitations may be significant and could adversely affect our results of operations and financial position.

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Conservation measures, technological advances and increasing public attention and activism with respect to climate change and environmental matters could reduce demand for oil, natural gas and NGLs and have an adverse effect on our business, financial condition and reputation.

Fuel conservation measures, alternative fuel requirements, incentives to conserve energy or use alternative energy sources, increasing consumer demand for alternatives to oil, natural gas and NGLs, and technological advances in fuel economy and energy generation devices could reduce demand for oil, natural gas and NGLs. Such initiatives or related activism aimed at limiting climate change and reducing air pollution, as well as negative investor sentiment toward our industry and the impact of the changing demand for oil and natural gas services and products may have a material adverse effect on our business, financial condition, results of operations, cash flows, and ability to access capital. Negative public perception regarding us and/or our industry resulting from, among other things, concerns raised by advocacy groups about climate change, may also lead to increased litigation risk, and regulatory, legislative and judicial scrutiny, which may, in turn, lead to new state and federal safety and environmental laws, regulations, guidelines and enforcement interpretations. Governmental authorities exercise considerable discretion in the timing and scope of permit issuance and the public may engage in the permitting process, including through intervention in the courts. Negative public perception could cause the permits we need to conduct our operations to be withheld, delayed, or burdened by requirements that restrict our ability to profitably conduct our business. In addition, claims have been made against certain energy companies alleging that GHG emissions from oil and natural gas operations constitute a public nuisance or have caused other redressable injuries under federal and/or state common law. While our business is not a party to any such litigation, we could be named in actions making similar allegations. An unfavorable ruling in any such case could adversely impact our business, financial condition and results of operations. Moreover, parties concerned about the potential effects of climate change have directed their attention at sources of funding for energy companies, which has resulted in certain financial institutions, funds and other sources of capital, restricting or eliminating their investment in oil and natural gas activities.

Climate change legislation or regulations restricting emissions of “greenhouse gases,” or GHGs, could result in increased operating costs and reduced demand for the oil, natural gas and NGLs we expect to produce.

In December 2009, the EPA published its findings that emissions of GHGs present a danger to public health and the environment because emissions of such gases are contributing to the warming of the Earth’s atmosphere and other climatic changes. Based on these findings, the EPA has adopted and implemented regulations to restrict emissions of GHGs under existing provisions of the Clean Air Act. In addition, the EPA has also adopted rules requiring the monitoring and reporting of GHG emissions from specified sources on an annual basis in the United States, including, among others, certain oil and natural gas production facilities, which includes certain of our operations. The adoption or revision and implementation of any regulations imposing reporting obligations on, or limiting emissions of GHGs from, our equipment and operations could require us to incur costs to reduce emissions of GHGs associated with our operations or could adversely affect demand for the oil, natural gas and NGLs we produce. Such climate change regulatory and legislative initiatives could have a material adverse effect on our business, financial condition and results of operations.

On August 16, 2022, President Biden signed into law the Inflation Reduction Act (the “IRA”), which targets methane from oil and gas sources by imposing an applicable “waste emissions charge” on petroleum and natural gas production facilities that exceed a specified waste emissions threshold and requiring the reporting of emissions that exceed 25,000 metric tons of carbon dioxide equivalent per year. On January 12, 2024 the EPA published a proposed rule to implement this waste emissions charge as required by the IRA. In addition to the IRA, almost one-half of the states have taken legal measures to reduce emissions of GHGs, including through the planned development of GHG emission inventories and/or regional GHGs cap and trade programs. On an international level, the United States was one of nearly 200 countries to sign an international climate change agreement in Paris, France that requires member countries to set their own GHG emissions reduction goals beginning in 2020. However, the United States formally announced its intent to withdraw from the Paris Agreement in November 2019, which became effective in November 2020. On January 20, 2021, President

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Biden issued written notification to the United Nations of the United States’ intention to rejoin the Paris Agreement, which became effective on February 19, 2021. In addition, various states and local governments have vowed to continue to enact regulations to achieve the goals of the Paris Agreement.

Although it is not possible at this time to predict how legislation or new regulations that may be adopted to address GHG emissions would impact our business, any such future laws and regulations that require additional reporting of GHGs or otherwise limit emissions of GHGs from our equipment and operations could require us to incur costs to monitor and report on GHG emissions or reduce emissions of GHGs associated with our operations, and such requirements also could adversely affect demand for the oil, natural gas and NGL that we produce. Finally, it should be noted that numerous scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts and floods and other climatic events. If any such effects were to occur in sufficient proximity to the SYU facilities, they could have an adverse effect on our financial condition and results of operations. For example, such effects could adversely affect or delay demand for the oil or natural gas produced or cause us to incur significant costs in preparing for or responding to the effects of climatic events themselves. Potential adverse effects could include disruption of our production activities, increases in our costs of operation or reductions in the efficiency of our operations, impacts on our personnel, supply chain, or distribution chain, as well as potentially increased costs for insurance coverages in the aftermath of such effects. Our ability to mitigate the adverse physical impacts of climate change depends in part upon our disaster preparedness and response and business continuity planning. See “Business— Environmental, Occupational Safety and Health Matters and Regulations—Regulation of ‘Greenhouse Gas’ Emissions” for a description of the climate change laws and regulations that affect us. Also see “Risk Factors—Risks Related to the Business of the Company—Attempts by the California state government to restrict the production of oil and gas could negatively impact our operations and result in decreased demand for fossil fuels in California.”

If we are engaged in intrastate common carrier operations, our financial results with respect to the Pipelines will primarily depend on the outcomes of ratemaking proceedings with the California Public Utilities Commission and we may not be able to earn an adequate rate of return in a timely manner or at all.

If determined to be a regulated intrastate common carrier in California, the Pipelines’ tariffs will be set by the CPUC on a prospective basis and will generally be designed to allow us to collect sufficient revenues to recover reasonable costs of providing service on the basis of revenues, expenses and a return on our capital investments. Our financial results with respect to the Pipelines could be materially affected if the CPUC does not authorize sufficient revenues for us to safely and reliably serve our pipeline customers and earn an adequate return of equity. The outcome of the ratemaking proceedings can be affected by many factors, including the level of opposition by intervening parties; potential rate impacts; increasing levels of regulatory review; changes in the political, regulatory, or legislative environments; and the opinions of our regulators, consumer and other stakeholder organizations, and customers, about our ability to provide safe and reliable oil transportation pipeline transportation.

In addition to the amount of authorized revenues, our financial results with respect to the Pipelines could be materially affected if our actual costs to safely and reliably serve our pipeline customers differ from authorized or forecast costs. We may incur additional costs for many reasons including changing market circumstances, unanticipated events (such as wildfires, storms, earthquakes, accidents, or catastrophic or other events affecting our pipeline operations), or compliance with new state laws or policies. Although we may be allowed to recover some or all of the additional costs, there may be a substantial delay between when we incur the costs and when we are authorized to collect revenues to recover such costs. Alternatively, the CPUC may disallow certain costs that they determine were not reasonably or prudently incurred.

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Attempts by the California state government to restrict the production of oil and gas could negatively impact our operations and result in decreased demand for fossil fuels in California.

California, where our operations and assets are located, is heavily regulated with respect to oil and gas operations. Federal, state and local laws and regulations govern most aspects of exploration and production in California. Collectively, the effect of the existing laws and regulations is to potentially limit the number and location of our wells through restrictions on the use of our properties, limit our ability to develop certain assets and conduct certain operations, and reduce the amount of oil and natural gas that we can produce from our wells below levels that would otherwise be possible. The regulatory burden on the industry increases our costs and consequently may have an adverse effect upon capital expenditures, earnings or competitive position. Violations and liabilities with respect to these laws and regulations could result in significant administrative, civil, or criminal penalties, remedial clean-ups, natural resource damages, permit modifications or revocations, operational interruptions or shutdowns and other liabilities. The costs of remedying such conditions may be significant, and remediation obligations could adversely affect our financial condition, results of operations and prospects.

Additionally, the California state government recently has taken several actions that could adversely impact future oil and gas production and other activities in the state. For example:

At this time, we cannot predict the potential future actions that may result from these orders or how such actions might potentially impact our operations.

In February 2021, California State Senators Scott Wiener and Monique Limón introduced Senate Bill 467, which proposes to halt the issuance or renewal of permits for hydraulic fracturing, acid well stimulation treatments, cyclic steaming, and water and steam flooding starting January 1, 2022, and then prohibit these extraction methods entirely starting January 1, 2027. SB 467 also would have prohibited all new or renewed permits for oil and gas extraction within 2,500 feet of any homes, schools, healthcare facilities or long-term care institutions such as dormitories or prisons, by January 1, 2022. However, SB 467 never made it out of committee and other bills to limit well stimulation treatments have also previously been introduced and failed to pass through the California legislature. Although these legislative efforts have failed, it is possible that SB 467 or similar legislation could be reintroduced in the future and we cannot predict the results of such future efforts.

On June 3, 2022, the U.S. Court of Appeals for the Ninth Circuit prohibited the federal government from issuing new permits for hydraulic fracturing and acidizing of oil wells in federal waters off the coast of California until a full environmental review is completed by federal agencies. The injunction was the result of lawsuits filed by the State of California, the California Coastal Commission and environmental groups alleging that federal agencies violated environmental laws when they authorized unconventional drilling methods on offshore California platforms before the unconventional drilling methods had been fully reviewed. The court also found that the California Coastal Commission must determine if hydraulic fracturing and acidizing are consistent with California’s coastal management program.

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While currently none of our California operations rely on hydraulic fracturing stimulation or acidizing of wells as discussed in the Ninth Circuit decision, any restrictions on the future use of those well stimulation treatments or other forms of injection may adversely impact our operations, including causing operational delays, increased costs, and reduced production, which could adversely affect our revenues, results of operations and net cash provided by operating activities.

Our assets are located exclusively onshore and offshore in California, making us vulnerable to risks associated with having operations concentrated in this geographic area.

We operate exclusively in California and in the waters off the coast of California. This geographic concentration disproportionately affects the success and profitability of our operations, exposing us to local price fluctuations, changes in state or regional laws and regulations, political risks, limited acquisition opportunities where we have the most operating experience and infrastructure, limited storage options, drought conditions, and other regional supply and demand factors, including gathering, pipeline and transportation capacity constraints, limited potential customers, infrastructure capacity and availability of rigs, equipment, oil field services, supplies and labor. We discuss such specific risks to our operations in more detail elsewhere in this section. In addition, we may not have the resources to effectively diversify our operations or benefit from the possible spreading of risks or offsetting of losses.

All of our operations are conducted in areas that may be at risk of damage from fire, mudslides, earthquakes or other natural disasters.

We currently conduct operations in California and adjacent offshore areas near known wildfire and mudslide areas and earthquake fault zones. A future natural disaster, such as a fire, mudslide or an earthquake, could cause substantial interruption and delays in our operations, damage or destroy equipment, prevent or delay transport of our products and cause us to incur additional expenses, which would adversely affect our business, financial condition and results of operations. In addition, our facilities would be difficult to replace and would require substantial lead time to repair or replace. These events could occur with greater frequency as a result of the potential impacts from climate change. The insurance we maintain against earthquakes, mudslides, fires and other natural disasters would not be adequate to cover a total loss of our facilities, may not be adequate to cover our losses in any particular case and may not continue to be available to us on acceptable terms, or at all.

Increasing attention to environmental, social and governance (“ESG”) matters may impact our business.

Increasing attention to, and social expectations on companies to address, climate change and other environmental and social impacts, investor and societal explanations regarding voluntary ESG disclosures, and increased consumer demand for alternative forms of energy may result in increased costs, reduced demand for our products, reduced profits, increased investigations and litigation, and negative impacts on our stock price and access to capital markets. Increasing attention to climate change and environmental conservation, for example, may result in demand shifts for oil and natural gas products and additional governmental investigations and private litigation against us. To the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to our causation of or contribution to the asserted damage, or to other mitigating factors. While we may participate in various voluntary frameworks and certification programs to improve the ESG profile of our operations and products, we cannot guarantee that such participation or certification will have the intended results on our or our products’ ESG profile.

Moreover, while we may create and publish voluntary disclosures regarding ESG matters from time to time, many of the statements in those voluntary disclosures will be based on hypothetical expectations and assumptions that may or may not be representative of current or actual risks or events or forecasts of expected risks or events, including the costs associated therewith. Such expectations and assumptions are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach to identifying, measuring, and reporting on many ESG matters. Additionally,

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while we may also announce various voluntary ESG targets in the future, such targets are aspirational. We may not be able to meet such targets in the manner or on such a timeline as initially contemplated, including, but not limited to as a result of unforeseen costs or technical difficulties associated with achieving such results. To the extent we do meet such targets through operational changes, they may be achieved through various contractual arrangements, including the purchase of various credits or offsets that may be deemed to mitigate our ESG impact. Also, despite these aspirational goals, we may receive pressure from investors, lenders, or other groups to adopt more aggressive climate or other ESG-related goals, but we cannot guarantee that we will be able to implement such goals because of potential costs or technical or operational obstacles.

In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings may lead to increased negative investor sentiment toward us or our customers and to the diversion of investment to other industries which could have a negative impact on our stock price and/or our access to and costs of capital. Moreover, to the extent ESG matters negatively impact our reputation, we may not be able to compete as effectively or recruit or retain employees, which may adversely affect our operations.

Such ESG matters may also impact our customers or suppliers, which may adversely impact our business, financial condition, or results of operations.

Environmental groups may initiate litigation and take other actions to delay or prevent us from obtaining required approvals to restart and continue production.

Environmental groups have had increasing success in limiting oil and gas production by appealing to regulatory agencies, filing lawsuits and applying political pressure. In order to restart production, we are required to obtain a series of permits or regulatory approvals from, among other agencies, the OSFM. The laws and procedures governing these and other permits and regulatory approvals often allow third parties, including environmental groups, to challenge the draft permits and/or permit approvals through the relevant agencies and other administrative appeal processes. These groups may also file lawsuits that delay or prevent the issuance of the approvals through an injunction and/or prevailing on the legal merits. In addition, these groups may leverage the increased public attention and concern with respect to climate change and other environmental and social impacts in order to encourage government officials to withhold or delay the necessary approvals. There is no assurance that these groups will not be successful in delaying or preventing us from obtaining the required approvals through litigation or other actions.

The Inflation Reduction Act of 2022 could accelerate the transition to a low carbon economy and will impose new costs on our operations.

On August 16, 2022, President Biden signed into law the IRA. The IRA contains hundreds of billions of dollars in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles and supporting infrastructure and carbon capture and sequestration, amongst other provisions. These incentives could further accelerate the transition of the U.S. economy away from the use of fossil fuels towards lower-or zero-carbon emissions alternatives, which could decrease demand for the oil and gas we produce and consequently materially and adversely affect our business and results of operations. In addition, the IRA imposes the first ever federal fee on the emission of GHGs through a methane emissions charge. The IRA amends the Clean Air Act to impose a fee on the emission of methane from sources required to report their GHG emissions to the EPA, including those sources in the petroleum and natural gas production category. The methane emissions charge started in calendar year 2024 at $900 per ton of methane, will increase to $1,200 in 2025, and be set at $1,500 for 2026 and each year thereafter. Calculation of the fee is based on certain thresholds established in the IRA. The methane emissions charge could increase our capital expenditures to limit methane releases and further increase our costs to the extent we exceed the limits, which may adversely affect our business and results of operations.

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The cost of decommissioning and the cost of financial assurance to satisfy decommissioning obligations are uncertain.

We are required to maintain reserve funds to provide for the payment of decommissioning costs associated with our properties. The estimates of decommissioning costs are inherently imprecise and subject to change due to changing cost estimates, oil and natural gas prices and other factors. If actual decommissioning costs exceed such estimates, or we are required to provide a significant amount of collateral in cash or other security as a result of a revision to such estimates, our financial condition, results of operations and cash flows may be materially adversely affected.

We may be required to post cash collateral pursuant to our agreements with sureties, letter of credit providers or regulators under our existing or future bonding or other arrangements, which may have a material adverse effect on our liquidity and our ability to execute our capital expenditure plan and our asset retirement obligation plan and comply with the agreements governing our existing or future indebtedness.

Pursuant to the terms of our existing bonding arrangements with various sureties in connection with the decommissioning obligations and government-mandated financial assurance obligations related to our properties, or under any future bonding arrangements we may enter into, we may be required to post collateral at any time, on demand, at the sureties’ sole discretion. If additional collateral is required to support surety bond obligations, this collateral would probably be in the form of cash or letters of credit, certificates of deposit or other similar forms of liquid collateral. Letter of credit providers would also in turn likely expect collateral to support such obligations, primarily in the form of cash or other liquid collateral.

If sureties become unwilling to enter into or continue bonding arrangements with us, regulators would likely require us to post additional collateral or fully fund our obligations with cash or other forms of liquid collateral. We cannot provide any assurance that we will be able to satisfy collateral demands for current or future bonds or letters of credit, or that we will be able to satisfy funding requirements for other arrangements with regulators. If we are required to provide additional collateral or fully fund these obligations and we cannot obtain alternative financing, our liquidity position may be negatively impacted and we may be forced to reduce our capital expenditures in the current year or future years, may be unable to execute our asset retirement obligation plan or may be unable to comply with the agreements governing our existing or future indebtedness.

Our business could be negatively affected by security threats, including cybersecurity threats, destructive forms of protest and opposition by activists and other disruptions.

As an oil and natural gas producer, we face various security threats, including cybersecurity threats to gain unauthorized access to sensitive information, to misappropriate financial assets or to render data or systems unusable; threats to the security of our facilities and infrastructure or third-party facilities and infrastructure, such as processing plants and pipelines; and threats from terrorist acts. The potential for such security threats has subjected our operations to increased risks that could have a material adverse effect on our business. In particular, our implementation of various procedures and controls to monitor and mitigate security threats and to increase security for our information, facilities and infrastructure may result in increased capital and operating costs. There can be no assurance that our cybersecurity risk management program and processes, including our policies, controls or procedures, will be fully implemented, complied with or effective in protecting our systems and information. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security breaches from occurring. If any of these security breaches were to occur, they could lead to losses of financial assets, sensitive information, critical infrastructure or capabilities essential to our operations and could have a material adverse effect on our reputation, financial position, results of operations or cash flows.

Cybersecurity attacks in particular are becoming more sophisticated and include, but are not limited to, malicious software, attempts to gain unauthorized access to data and systems, and other electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or otherwise protected

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information, and corruption of data. These events could lead to financial losses from remedial actions, loss of business or potential liability. In addition, destructive forms of protest and opposition by activists and other disruptions, including acts of sabotage or eco-terrorism, against oil and gas production and activities could potentially result in damage or injury to people, property or the environment or lead to extended interruptions of our operations, adversely affecting our financial condition and results of operations.

Risks Related to Being a Public Company

The market prices of our securities could be highly volatile or may decline regardless of our operating performance. You may lose some or all of your investment.

The trading price of our Common Stock is likely to be volatile and subject to significant fluctuations. The trading price of our Common Stock will depend on many factors, including those described in this “Risk Factors” section, many of which are beyond our control and may not be related our operating performance. You may not be able to resell your shares at an attractive price due to a number of factors, such as the following:

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Broad market and industry factors may materially harm the market price of our securities irrespective of our operating performance. The stock market in general and the NYSE have experienced extreme price and volume fluctuations that have often been unrelated or disproportionate to the operating performance of the particular companies affected. The trading prices and valuations of these stocks, and of our securities, may not be predictable. A loss of investor confidence in the market for the stocks of other companies which investors perceive to be similar to ours could depress our Common Stock price regardless of our business, prospects, financial conditions or results of operations.

In addition, in the past, following periods of volatility in the overall market and the market prices of particular companies’ securities, securities class action litigations have often been instituted against these companies. Litigation of this type, if instituted against us, could result in substantial costs and a diversion of our management’s attention and resources. Any adverse determination in any such litigation or any amounts paid to settle any such actual or threatened litigation could require that we make significant payments.

Our stock price may be exposed to additional risks because we became a public company through a “de-SPAC” transaction. There has been increased focus by government agencies on such transactions, and we expect that increased focus to continue, and we may be subject to increased scrutiny by the SEC and other government agencies on holders of our securities as a result, which could adversely affect the price of our Common Stock.

The NYSE may not continue to list our securities, which could limit investors’ ability to make transactions in our securities and subject us to additional trading restrictions.

We cannot assure you that our securities will continue to be listed on the NYSE in the future. In order for our securities to remain listed on the NYSE, we must maintain certain financial, distribution and stock price levels.

If the NYSE delists our securities from trading on its exchange and we are not able to list our securities on another national securities exchange, we expect our securities could be quoted on an over-the-counter market. If this were to occur, we could face significant material adverse consequences, including:

We have identified material weaknesses in our internal control over financial reporting. These material weaknesses could continue to adversely affect investor confidence in us and materially adversely affect our ability to report our results of operations and financial condition accurately and in a timely manner.

Our management is responsible for establishing and maintaining adequate internal control over financial reporting designed to provide reasonable assurance regarding the reliability of financial reporting and the

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preparation of financial statements for external purposes in accordance with GAAP. Our management also evaluates the effectiveness of our internal controls and we will disclose any changes and material weaknesses identified through such evaluation in those internal controls. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or surrounding interim financial statements will not be prevented or detected on a timely basis.

We identified a material weakness in our internal control over financial reporting related to the accounting for the warrants we issued in connection with the Company IPO. As a result of this material weakness, our management concluded that our internal control over financial reporting was not effective as of December 31, 2023. This material weakness resulted in a material misstatement of our warrant liabilities, change in fair value of warrant liabilities and related financial disclosures for the fiscal year ended December 31, 2021.

We also identified a material weakness in our internal control over financial reporting of complex financial instruments related to our classification of redeemable shares of Flame’s Class A common stock, par value $0.0001 per share (“Flame Class A common stock”). As a result of this material weakness, our management has concluded that our internal control over financial reporting was not effective as of December 31, 2023. Historically, a portion of the Flame Class A common stock was classified as permanent equity. Following our re-evaluation of the accounting classification of the Flame Class A common stock, our management has determined that the Flame Class A common stock requires classification as temporary equity.

Management designed and implemented new processes and controls over the financial reporting of complex financial instruments, including the engagement of subject matter expert accounting consultants and the implementation of additional layers of review and approval related to its technical accounting review process. The Company has tested the operating effectiveness of these new controls and has concluded that they are operating effectively. If we identify any new material weaknesses in the future, any such newly identified material weakness could limit our ability to prevent or detect a misstatement of our accounts or disclosures that could result in a material misstatement of our annual or interim financial statements. In such case, we may be unable to maintain compliance with securities law requirements regarding timely filing of periodic reports in addition to applicable stock exchange listing requirements, investors may lose confidence in our financial reporting and our stock price may decline as a result. We cannot assure you that the measures we have taken to date, or any measures we may take in the future, will be sufficient to avoid potential future material weaknesses. To respond to these material weaknesses, we have devoted, and plan to continue to devote, significant effort and resources to the remediation and improvement of our internal control over financial reporting. While we have processes to identify and appropriately apply applicable accounting requirements, we plan to enhance these processes to better evaluate our research and understanding of the nuances of the complex accounting standards that apply to our financial statements. Our plans at this time include providing enhanced access to accounting literature, research materials and documents and increased communication among our personnel and third-party professionals with whom we consult regarding complex accounting applications. The elements of our remediation plan can only be accomplished over time, and we can offer no assurance that these initiatives will ultimately have the intended effects.

Any failure to maintain such internal control could adversely impact our ability to report our financial position and results from operations on a timely and accurate basis. If our financial statements are not accurate, investors may not have a complete understanding of our operations. Likewise, if our financial statements are not filed on a timely basis, we could be subject to sanctions or investigations by the stock exchange on which our Common Stock is listed, the SEC or other regulatory authorities. In either case, this could in result a material adverse effect on our business. Failure to timely file will cause us to be ineligible to utilize short-form registration statements on Form S-3, which may impair our ability to obtain capital in a timely fashion to execute our business strategies or issue shares to effect an acquisition. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which could have a negative effect on the trading price of our stock.

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We can give no assurance that the measures we have taken and plan to take in the future will remediate the material weaknesses identified or that any additional material weaknesses or restatements of financial results will not arise in the future due to a failure to implement and maintain adequate internal control over financial reporting or circumvention of these controls. In addition, even if we are successful in strengthening our controls and procedures, in the future those controls and procedures may not be adequate to prevent or identify irregularities or errors or to facilitate the fair presentation of our financial statements.

If we fail to develop and maintain an effective system of disclosure controls and internal control over financial reporting, our ability to produce timely and accurate financial statements or comply with applicable regulations could be impaired, which may adversely affect investor confidence in us and, as a result, the market price of our Common Stock.

As a U.S. public company, we are required to comply with the requirements of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), including, among other things, that we maintain effective disclosure controls and procedures and internal control over financial reporting. We are continuing to develop and refine our disclosure controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports that we file with the SEC is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to our management, including our principal executive and financial officers.

We will be required to make a formal assessment of the effectiveness of our internal control over financial reporting and, after we cease to be an emerging growth company, we will be required to include an attestation report on internal control over financial reporting issued by our independent registered public accounting firm. To achieve compliance with these requirements within the prescribed time period, we have begun a process to document and evaluate our internal control over financial reporting, which is both costly and challenging. We will need to continue to dedicate internal resources, potentially engage outside consultants and adopt a detailed work plan to assess and document the adequacy of our internal control over financial reporting, validate through testing that controls are functioning as documented and implement a continuous reporting and improvement process for internal control over financial reporting. There is a risk that we will not be able to conclude, within the prescribed time period or at all, that our internal control over financial reporting is effective as required by Section 404 of the Sarbanes-Oxley Act. Moreover, our testing, or the subsequent testing by our independent registered public accounting firm, may reveal additional deficiencies in our internal control over financial reporting that are deemed to be material weaknesses.

Any failure to implement and maintain effective disclosure controls and procedures and internal control over financial reporting, including the identification of one or more material weaknesses, could cause investors to lose confidence in the accuracy and completeness of our financial statements and reports, which would likely adversely affect the market price of our Common Stock. In addition, we could be subject to sanctions or investigations by the stock exchange on which our Common Stock is listed, the SEC and other regulatory authorities.

Sales of a substantial number of our securities in the public market by the Selling Holders or by our existing securityholders could cause the price of our shares of Common Stock to fall.

Sales of a substantial number of our shares of Common Stock in the public market by the Selling Holders or by our other existing securityholders, or the perception that those sales might occur, could depress the market price of our shares of Common Stock and could impair our ability to raise capital through the sale of additional equity securities. We are unable to predict the effect that such sales may have on the prevailing market price of our shares of Common Stock.

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Our issuance of additional shares of Common Stock or convertible securities may dilute your ownership of us and could adversely affect our stock price.

On April 19, 2024, we filed a registration statement on Form S-8 with the SEC (the “Form S-8”) providing for the registration of 30,000,000 shares of our Common Stock issued or reserved for issuance under the Sable Offshore Corp. 2023 Incentive Award Plan (the “Incentive Plan”). The Incentive Plan provides for automatic increases in the shares reserved for grant or issuance under the plan, which could result in additional dilution to our stockholders. Subject to the satisfaction of vesting conditions and the expiration of any applicable lockup restrictions, shares registered under the Form S-8 are generally available for resale immediately in the public market without restriction. From time to time in the future, we may also issue additional shares of our Common Stock or securities convertible into our Common Stock pursuant to a variety of transactions, including acquisitions. The issuance by us of additional shares of our Common Stock or securities convertible into our Common Stock would dilute your ownership of us and the sale of a significant amount of such shares in the public market could adversely affect prevailing market prices of our Common Stock.

In the future, we may seek to obtain financing or to further increase our capital resources by issuing additional shares of our capital stock or offering debt or other equity securities, including senior or subordinated notes, debt securities convertible into equity, or shares of preferred stock. Issuing additional shares of our capital stock, other equity securities, or securities convertible into equity may dilute the economic and voting rights of our existing stockholders, reduce the market price of our Common Stock, or both. Debt securities convertible into equity could be subject to adjustments in the conversion ratio pursuant to which certain events may increase the number of equity securities issuable upon conversion. Preferred stock, if issued, could have a preference with respect to liquidating distributions or a preference with respect to dividend payments that could limit our ability to pay dividends to the holders of our Common Stock. Our decision to issue securities in any future offering will depend on market conditions and other factors beyond our control, which may adversely affect the amount, timing or nature of our future offerings. As a result, holders of our Common Stock bear the risk that our future offerings may reduce the market price of our Common Stock and dilute their percentage ownership. See the section of this prospectus entitled “Description of Securities.”

Members of our management team and our Board and their respective affiliated companies have been, and may from time to time be, involved in legal proceedings or governmental investigations unrelated to our business.

Members of our management team and our Board have been involved in a wide variety of businesses. Such involvement has, and may lead to, media coverage and public awareness. As a result of such involvement, members of our management team and our Board and their respective affiliated companies have been, and may from time to time be, involved in legal proceedings or governmental investigations unrelated to our business. Any such proceedings or investigations may be detrimental to our reputation and could negatively affect our ability to identify and complete an initial business combination and may have an adverse effect on the price of our securities.

If securities or industry analysts do not publish research or reports about us, or publish negative reports, our stock price and trading volume could decline.

The trading market for our Common Stock will depend, in part, on the research and reports that securities or industry analysts publish about us. We will not have any control over these analysts. If our financial performance fails to meet analyst estimates or one or more of the analysts who cover us downgrade our Common Stock or change their opinion, our stock price would likely decline. If one or more of these analysts cease coverage of us or fail to regularly publish reports on us, we could lose visibility in the financial markets, which could cause our stock price or trading volume to decline.

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Our operating results may fluctuate significantly, which makes our future operating results difficult to predict and could cause our operating results to fall below expectations or any guidance it may provide.

Our quarterly and annual operating results may fluctuate significantly, which makes it difficult for us to predict our future operating results. These fluctuations may occur due to a variety of factors, many of which are outside of our control, including, but not limited to:

The cumulative effects of these factors could result in large fluctuations and unpredictability in our quarterly and annual operating results. As a result, comparing our operating results on a period-to-period basis may not be meaningful. Investors should not rely on past results as an indication of future performance. This variability and unpredictability could also result in us failing to meet the expectations of industry or financial analysts or investors for any period. If our revenue or operating results fall below the expectations of analysts or investors or below any forecasts we may provide to the market, or if the forecasts we provide to the market are below the expectations of analysts or investors, the price of our Common Stock could decline substantially. Such a stock price decline could occur even when we have met any previously publicly stated revenue or earnings guidance we may provide.

Changes in laws, regulations or rules, or a failure to comply with any laws, regulations or rules, may adversely affect our business, investments and results of operations.

We are subject to laws, regulations and rules enacted by national, regional and local governments and the NYSE. In particular, We are required to comply with certain SEC, NYSE and other legal or regulatory requirements. Compliance with, and monitoring of, applicable laws, regulations and rules may be difficult, time consuming and costly. Such laws, regulations or rules and their interpretation and application may also change from time to time and such changes could have a material adverse effect on our business, investments and results of operations. In addition, any failure by us to comply with applicable laws, regulations or rules, as interpreted and applied, could have a material adverse effect on our business and results of operations.

We are an “emerging growth company” and the reduced reporting and disclosure requirements applicable to emerging growth companies could make our Common Stock less attractive to investors.

We are an “emerging growth company,” as defined in the JOBS Act. For as long as we remain an emerging growth company, we may choose to take advantage of exemptions from various reporting requirements applicable to other public companies but not to “emerging growth companies,” including:

As a result, our stockholders may not have access to certain information that they may deem important.

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Our status as an emerging growth company will end as soon as any of the following takes place:

Under the JOBS Act, emerging growth companies can also delay the adoption of new or revised accounting standards until such time as those standards apply to private companies. We may elect to take advantage of this extended transition period and as a result, our financial statements may not be comparable with similarly situated public companies.

We cannot predict if investors will find our Common Stock less attractive if we choose to rely on any of the exemptions afforded emerging growth companies. If some investors find our Common Stock less attractive because we rely on any of these exemptions, there may be a less active trading market for our Common Stock and the market price of our Common Stock may be more volatile and may decline.

Because there are no current plans to pay cash dividends on our Common Stock for the foreseeable future, you may not receive any return on investment unless you sell your shares of our Common Stock at a price greater than what you paid for it.

We intend to retain future earnings, if any, for future operations, expansion and debt repayment and there are no current plans (at least until the restart of production at SYU and the repayment or refinancing of the Term Loan Agreement) to pay any cash dividends for the foreseeable future. The declaration, amount and payment of any future dividends on shares of our Common Stock will be at the sole discretion of our Board and subject to restrictions and limitations in the Term Loan Agreement or any other then-existing indebtedness of the Company. Our Board may take into account general and economic conditions, our financial condition and results of operations, our available cash and current and anticipated cash needs, capital requirements, contractual, legal, tax and regulatory restrictions, implications of the payment of dividends by us to our stockholders or by our subsidiaries to us and such other factors as our Board may deem relevant. As a result, you may not receive any return on an investment in our Common Stock unless you sell your shares of our Common Stock for a price greater than that which you paid for it.

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USE OF PROCEEDS

We are filing the registration statement of which this prospectus is a part to permit the Selling Holders to resell their shares of Common Stock. All of the Common Stock offered by the Selling Holders pursuant to this prospectus will be sold by the Selling Holders for their respective accounts. We will not receive any of the proceeds from these sales.

DETERMINATION OF OFFERING PRICE

We cannot currently determine the price or prices at which shares of Common Stock may be sold by the Selling Holders under this prospectus.

MARKET INFORMATION FOR COMMON STOCK AND DIVIDEND POLICY

Market Information

Our Common Stock and Public Warrants are currently listed on NYSE under the symbols “SOC” and “SOC.WS,” respectively.

As of October 10, 2024, Sable had 81,682,618 shares of Common Stock outstanding held of record by 79 holders and 5,765,892 Public Warrants outstanding held of record by one holder. Such amounts do not include DTC participants or beneficial owners holding shares through nominee names.

Dividend Policy

The Company has not paid any cash dividends on its Common Stock to date. The payment of cash dividends in the future will be dependent upon the Company’s revenues and earnings, if any, capital requirements and general financial condition, as well as the applicable provisions of the Sable certificate of incorporation, the Company’s bylaws and applicable law. The payment of any cash dividends will be within the discretion of the Company’s board of directors at such time. The Company’s ability to declare dividends will also be limited by restrictive covenants pursuant to any debt financing agreements, including the Term Loan Agreement. In addition, the Company’s board of directors is not currently contemplating and does not anticipate declaring any stock dividends in the foreseeable future.

Securities Authorized for Issuance under Equity Compensation Plans.

As of December 31, 2023, we had no equity compensation plans or outstanding equity awards. In connection with the Business Combination, the Company adopted the Incentive Plan in order to facilitate the grant of cash and equity incentives to directors, employees, including named executive officers, and consultants to help attract and retain the services of these individuals. The aggregate number of shares of Common Stock that were initially reserved for issuance under the Incentive Plan is 15,621,569, provided that the number of shares of Common Stock authorized for issuance under the Incentive Plan is subject to an annual increase for ten years on the first day of each calendar year beginning January 1, 2024, in an amount equal to the lesser of (A) 5% of the aggregate number of shares of Common Stock outstanding on the final day of the immediately preceding calendar year and (B) such smaller number of shares as is determined by the Board. To date, we have granted awards covering 4,807,270 shares of restricted Common Stock under the Incentive Plan.

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UNAUDITED PRO FORMA FINANCIAL INFORMATION

Introduction

Flame was a blank check company formed under the laws of the State of Delaware on October 16, 2020, for the purpose of effecting a merger, capital stock exchange, asset acquisition, stock purchase, reorganization or other similar business combination with one or more businesses. Flame effectuated its initial business combination using cash from the proceeds of the Company IPO and the sale of the Private Placement Warrants, capital stock, debt or a combination of cash, stock and debt.

Beginning in 1968 and over the course of 14 years, Exxon Mobil Corporation (“EM”) consolidated more than a dozen offshore federal oil leases and organized them into a streamlined production unit known as SYU. SYU consists of three offshore platforms and a wholly owned onshore processing facility located along the Gaviota Coast at Las Flores Canyon in Santa Barbara County, California (the “Assets”).

The Company IPO net proceeds of $287,500,000 were placed into the trust account of Flame that held the proceeds from the Company IPO (the “trust account”).

On November 2, 2022, Flame entered into the Merger Agreement with Holdco and Sable, which, among other things, provides for each of Holdco and Sable to be merged with and into Flame, with Flame being the surviving company in the Merger.

EM agreed to sell the Assets, including 100% of the equity interests in each of Pacific Offshore Pipeline Company and Pacific Pipeline Company (the “Pipelines”), to Legacy Sable for $625,000,000 payable in cash and seller-financed indebtedness, subject to certain adjustments as further described below.

On February 12, 2024, Flame held a special meeting of stockholders (the “Special Meeting”), at which the Flame stockholders considered and adopted, among other matters, a proposal to approve the Business Combination, including (a) adopting the Merger Agreement and (b) approving the other transactions contemplated by the Merger Agreement.

Pursuant to the terms and subject to the conditions set forth in the Merger Agreement, following the Special Meeting, on February 14, 2024, the Business Combination was consummated.

In connection with the Business Combination, on February 12, 2024, stockholders holding 150,823 public shares exercised their right to redeem those shares for a pro rata portion of the funds in the trust account, representing approximately 2.47% of Flame’s then issued and outstanding public shares. As a result, approximately $1,572,250 (approximately $10.42 per share) was removed from the trust account to pay such redeeming stockholders on February 14, 2024. As of February 14, 2024, the remaining balance of the trust account immediately following that payment was approximately $62.2 million.

The unaudited pro forma condensed combined financial information is prepared in accordance with Article 11 of Regulation S-X as amended by the final rule, Release No. 33-10786 “Amendments to Financial Disclosures about Acquired and Disposed Businesses.”

The unaudited pro forma condensed combined financial information gives effect to the transactions summarized below (for the purposes of this section “Unaudited Pro Forma Condensed Financial Information,” the “Transactions”) the Merger, together with the other transactions contemplated by the Merger Agreement (including the consummation of the First PIPE Investment) and the related agreements, collectively referred to as the “Business Combination”.

The unaudited pro forma condensed combined statements of operations for the six months ended June 30, 2024, and for the year ended December 31, 2023, combines the historical statement of operations of Flame, the historical combined statement of SYU, the predecessor entity (including the Assets, as defined by the Sable-EM Purchase Agreement, excluding the Pipelines) and the historical condensed consolidated statement of operations

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of Sable, the successor entity, for the period February 14, 2024 through June 30, 2024, for such period on a pro forma basis, as if the Transactions had been consummated on January 1, 2023, the beginning of the earliest period presented. Since the Business Combination was consummated on February 14, 2024, and its affect and related transactions have been reflected in the unaudited condensed consolidated statement of operations of Sable for the period from February 14, 2024, through June 30, 2024, the associated one-time transaction related activities have not been reflected in the pro forma transaction accounting adjustments in the unaudited pro forma combined statement of operations for the year ended December 31, 2023. The combined statements of operations reflect Sable’s purchase of the Assets (as defined in the Sable-EM Purchase Agreement), including the Pipelines.

The unaudited pro forma condensed combined financial statements have been developed from and should be read in conjunction with:

The Business Combination is accounted for under the scope of Financial Accounting Standards Board’s Accounting Standards Codification (“ASC”) Topic 805, Business Combinations (“ASC 805”). Pursuant to ASC 805, Flame was determined to be the accounting acquirer based on evaluation of the following facts and circumstances:

The preponderance of the evidence discussed above supports the conclusion that Flame was the accounting acquirer in the Business Combination. SYU constitutes a business in accordance with ASC 805 and the Business Combination constitutes a change in control. Accordingly, the Business Combination was accounted for using the acquisition method of accounting. Upon consummation of the Business Combination, SYU is considered the predecessor entity and its historical operations are presented as that of Sable on a going forward basis.

Description of the Business Combination

Pursuant to the Merger Agreement, on the Closing Date and contemporaneously with the completion of the transactions contemplated under the Sable-EM Purchase Agreement (including certain transactions contemplated by the Term Loan), Holdco merged with and into Flame, with Flame as the surviving company, and immediately thereafter, Sable merged with and into Flame, with Flame as the surviving company. The aggregate consideration received by holders of limited liability company membership interests in Holdco designated as Class A shares (“Holdco Class A shares”) immediately prior to the Holdco Merger Effective Time was 3,000,000 shares of Flame Class A common stock.

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In accordance with the terms and subject to the conditions of the Merger Agreement, at the Holdco Merger Effective Time:

In accordance with the terms and subject to the conditions of the Merger Agreement, at the Sable Merger Effective Time, each share of Common Stock issued and outstanding immediately prior to the Sable Merger Effective Time was cancelled and no consideration was delivered in exchange therefor.

For the avoidance of doubt, at and after each of the Holdco Merger Effective Time and the Sable Merger Effective Time, each share of Flame common stock issued and outstanding immediately prior thereto was not affected by the Merger.

In addition, immediately prior to the Holdco Merger Effective Time, each founder share issued and outstanding immediately prior to the Holdco Merger Effective Time was automatically converted into shares of Flame Class A common stock on a one-for-one basis.

In connection with the Closing, Flame Acquisition Corp. was renamed Sable Offshore Corp.

First PIPE Subscription Agreement

As previously disclosed on November 2, 2022, July 21, 2023, July 27, 2023, August 3, 2023, December 18, 2023, January 16, 2024, February 12, 2024 and February 13, 2024, in connection with the Business Combination, Holdco and Flame entered into subscription agreements (collectively, the “First PIPE Subscription Agreements”) with certain investors (the “First PIPE Investors”) and, pursuant thereto, on February 14, 2024, immediately following the Closing, Sable issued 44,024,910 shares of Common Stock, at a price of $10.00 per share for an aggregate purchase price of $440,249,100 in accordance with the terms of the First PIPE Subscription Agreements (the “First PIPE Investments”).

The following summarizes the shares of Common Stock outstanding following the consummation of the Business Combination:

Excluded Securities:

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Assumptions and estimates underlying the unaudited pro forma adjustments set forth in the unaudited pro forma condensed combined financial statements are described in the accompanying notes. The unaudited pro forma condensed combined financial statements have been presented for illustrative purposes only and are not necessarily indicative of the operating results and financial position that would have been achieved had the Transactions and the other related transactions occurred on the dates indicated. Further, the unaudited pro forma condensed combined financial information does not purport to project the future operating results or financial position of Sable following the completion of the Transactions and the other related transactions. The unaudited pro forma adjustments represent our management’s estimates based on information available as of the date of these unaudited pro forma condensed combined financial statements and are subject to change as additional information becomes available and analyses are performed.

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Unaudited Pro Forma Condensed Combined Statement of Operations

For the six months ended June 30, 2024

See accompanying notes to unaudited pro forma condensed combined financial information.

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Unaudited Pro Forma Condensed Combined Statement of Operations

For the year ended December 31, 2023

See accompanying notes to unaudited pro forma condensed combined financial information.

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NOTES TO UNAUDITED PRO FORMA COMBINED FINANCIAL INFORMATION

Note 1. Basis of Presentation

The unaudited pro forma condensed combined financial information has been prepared using the acquisition method of accounting in accordance with ASC 805, with Flame as the accounting acquirer, using the fair value concepts as defined in the ASC Topic 820, Fair Value Measurement (“ASC 820”), and based on the historical financial statements of Flame and SYU.

An unaudited pro forma combined balance sheet as of June 30, 2024, is not presented as the Business Combination was consummated on February 14, 2024, and is thus included in the unaudited condensed consolidated balance sheet as of June 30, 2024. The unaudited pro forma combined statement of operations for the year ended December 31, 2023, gives pro forma effect to the Business Combination and related transactions as if they had been completed on January 1, 2023, except as described in the following sentence. Since the Business Combination was consummated on February 14, 2024, and its affect and related transactions have been reflected in the unaudited condensed consolidated statement of operations of Sable for the period from February 14, 2024, through June 30, 2024, the associated one-time transaction related activities have not been reflected in the pro forma transaction accounting adjustments in the unaudited pro forma combined statement of operations for the year ended December 31, 2023.

The unaudited pro forma condensed combined financial information does not give effect to any anticipated synergies, operating efficiencies, tax savings, or cost savings that may be associated with the Business Combination and related transactions. The unaudited pro forma condensed combined financial information is not necessarily indicative of what the actual results of operations and financial position would have been had the Business Combination and related transactions taken place on the dates indicated, nor are they indicative of the future consolidated results of operations or financial position of the post-combination company. They should be read in conjunction with the historical financial statements and notes thereto of Sable, SYU and Flame.

Note 2. Accounting Policies

Upon consummation of the Business Combination, management performed a comprehensive review of the two entities’ accounting policies. Based on its initial analysis, management did not identify any differences that would have a material impact on the unaudited pro forma condensed combined financial information. As a result, the unaudited pro forma condensed combined financial information does not assume any differences in accounting policies.

Note 3. Adjustments to Unaudited Pro Forma Condensed Combined Financial Information

The unaudited pro forma condensed combined financial information has been prepared to illustrate the effect of the Business Combination and related transactions and has been prepared for informational purposes only.

The following unaudited pro forma condensed combined financial information has been prepared in accordance with Article 11 of Regulation S-X as amended by the final rule, Release No. 33-10786 “Amendments to Financial Disclosures about Acquired and Disposed Businesses.” Release No. 33-10786 replaced the then existing pro forma adjustment criteria with simplified requirements to depict the accounting for the transaction (“Transaction Accounting Adjustments”). The Company has elected not to present any synergies or other potential transaction effects and will only be presenting Transaction Accounting Adjustments in the accompanying unaudited pro forma condensed combined financial information.

The pro forma basic and diluted net loss per share amounts presented in the unaudited pro forma condensed combined statement of operations are based upon the number of the post-combination company’s shares outstanding, assuming the Business Combination occurred on January 1, 2023.

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Adjustments to the Unaudited Pro Forma Combined Statements of Operations

The following adjustments have been reflected in the unaudited pro forma combined statements of operations:

(A) Reflects the elimination of historical depreciation and accretion expense amounting to $2.6 million and $21.0 million for the period January 1, 2024, through February 13, 2024, and the year ended December 31, 2023, respectively, as if the Business Combination had been completed on January 1, 2023, considering oil and gas properties not operative during the periods presented. No historical amortization or depletion was recorded.

(B) Reflects the accretion expense on the asset retirement obligations amounting to $1.5 million and $11.0 million for the period January 1, 2024, through February 13, 2024, and the year ended December 31, 2023, respectively, as if the Business Combination had been completed on January 1, 2023.

(C) Reflects additional New Sable executive compensation based on executed agreements amounting to $1.1 million and $9.1 million for the period January 1, 2024, through February 13, 2024, and the year ended December 31, 2023, respectively, as if the Business Combination had been completed on January 1, 2023.

(D) Reflects elimination of investment income on the trust account amounting to $4.4 million for the year ended December 31, 2023, respectively.

(E) Reflects the elimination of the change in fair value of convertible promissory notes of $3.7 million for the year ended December 31, 2023.

(F) Reflects recognition of interest expense on the Term Loan, calculated at the rate of 10% per annum amounting to $10.5 million for the period January 1, 2024 through February 13, 2024.

(G) Reflects recognition of interest expense on the Term Loan, calculated at the rate of 10% per annum amounting to $76.3 million for the year ended December 31, 2023.

(H) Reflects the change in fair value of the Flame Acquisition Corp. warrants and convertible promissory notes from January 1, 2024 through February 13, 2024 of $24.5 million. The Flame Acquisition Corp. statement of operations for the period January 1, 2024 through February 13, 2024 is not presented separately herein due to immateriality.

(I) On February 12, 2024, as previously noted, Flame shareholders redeemed 150,823 public shares for approximately $10.42 per share.

Note 4. Net Loss per Share

The net loss per share was calculated using the historical weighted average shares outstanding, and the issuance of additional shares in connection with the Business Combination, the First PIPE Investment and other related events, assuming the shares were outstanding since January 1, 2023. As the actual redemptions, Business Combination, First PIPE Investment and related equity transactions are being reflected as if they had occurred at the beginning of the periods presented, the calculation of weighted average shares outstanding for basic and diluted net loss per share assumes that the shares issued relating to the Business Combination have been outstanding for the entire periods presented.

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BUSINESS

References in this section to “we,” “our” and “us” generally refer to Legacy Sable prior to the Business Combination and Sable after the Business Combination.

Overview

Beginning in 1968 and over the course of 14 years, EM consolidated more than a dozen offshore federal oil leases and organized them into a streamlined production unit known as SYU. SYU consists of three offshore platforms and a wholly owned onshore processing facility located along the Gaviota Coast at Las Flores Canyon in Santa Barbara County, California. SYU’s onshore facilities and the three offshore platforms remained in continuous operation until 2015. In May 2015, a Plains Pipeline that transported produced oil from SYU experienced a leak, as further described below under “ —Pipeline 324 Incident.” The SYU platforms and facilities suspended production after the Line 324 incident, the SYU Assets were shut in and the facilities were placed in a safe state. The facilities are not currently producing oil and gas; however, all equipment remains in place in an operation-ready state, requiring ongoing inspections, maintenance and surveillance. As part of these suspension efforts, all SYU equipment was drained, flushed and purged in 2016. All hydrocarbon pipelines within SYU have been placed in a safe state and remain under regular monitoring. In 2020, Plains entered into a Consent Decree, described further below under “ —Pipeline 324 Incident,” that provides a path for a potential restart of Lines 324 and 325.

Assets

SYU is comprised of three platforms located in federal waters offshore California and its onshore processing facility.

The offshore position is comprised of 16 federal leases across approximately 76,000 acres and includes 100% working interest with an average 83.6% net revenue interest. The Hondo platform and the Harmony platform develop the Hondo Field, and the Heritage platform develops the Pescado and Sacate Fields. The platforms are located 5 to 9 miles offshore of Santa Barbara County in shallow water depths of 900 to 1,200 feet and service 112 wells, comprised of 90 producers, 12 injectors and 10 idle with an additional 102 identified, undrilled opportunities. A 2015 analysis identified step-out potential for untested fault compartments or sub-accumulations and indicated a potential technical opportunity for up to an additional 102 identified, undrilled opportunities based on spacing assumptions ranging from 20 to 80 acres. For each platform, more opportunities exist than there are available donor wellbores based on current spacing assumptions (i.e., each platform is slot-constrained).

The wholly owned onshore processing facility is a fully integrated oil and gas processing facility with additional capacity for development. The natural gas and NGLs it processed prior to the Line 324 incident were sold into the Southern California markets and the oil volumes were sold to California refineries. The onshore position is approximately 1,480 surface acres, which include the processing facility and parts of the surrounding canyons. The onshore facilities occupy approximately 35 acres and are comprised of:

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In addition to SYU, Sable also acquired in the Business Combination the Pipelines, which were owned and operated by Plains and were recently acquired by EM. The Pipelines were used to deliver oil to local refinery markets. Following the crude oil release described further below, Plains indicated it shut down the pipeline, initiated its emergency response plan, and the Pipelines were subsequently emptied and placed in a safe state.

Line 324 is a 24-inch, approximately 10.8 mile long crude oil pipeline that extends from the Los Flores Station on the California Coast to the Gaviota Pump Station in Santa Barbara County, California. Line 325 is a 30-inch, approximately 113 mile long crude oil pipeline that extends from the Gaviota Pump Station in Santa Barbara County, California to the 30-inch pig receiver located in Pentland Station in Kern County, California with an intermediate station at Sisquoc mile post 38.5 in San Louis Obispo, California.

SYU Production History

Between 1981 and 2014, SYU produced over 671 MMBoe of oil and gas. An average of 27 MMcf of natural gas and 29 MBbls of oil and condensate was produced per day (gross) in 2014, the last full year when the assets were online. After the Line 324 incident, the SYU platforms and facilities suspended production, the SYU Assets were shut in and the facilities were placed in a safe state as described below under “ —Pipeline 324 Incident.”

SYU Contingent Resources

The estimated quantities of petroleum contained in the SYU Assets are classified as “contingent resources” as of June 30, 2024 rather than “reserves” because they are subject to numerous contingencies. There is no assurance that any of the petroleum contained in the SYU Assets will ever be recovered or reclassified as “reserves.”

The resources are contingent upon (1) approval from federal, state and local regulators to restart production, (2) reestablishment of oil transportation systems to deliver production to market and (3) commitment to restart the wells and facilities. Some or all of the contingent resources maybe reclassified as “reserves” if all of the contingencies are successfully resolved but there is no assurance that the contingencies will be resolved or resolved in a timely manner or that any of the petroleum in the SYU Assets will be recovered.

As a result of the contingencies noted above, none of the estimated petroleum quantities attributed to the SYU Assets as of June 30, 2024 meet the requirements for disclosure as reserves pursuant to the guidelines published by the SEC in Rule 4-10(a) of Regulation S-X.

Pipeline 324 Incident

In May 2015, Plains All American Pipeline, L.P. (“Plains”) experienced a crude oil release from the Las Flores to Gaviota Pipeline (Line 324) in Santa Barbara County, California (the “Line 324 incident”). According to Plains, a portion of the released crude oil reached the Pacific Ocean at Refugio State Beach through a drainage culvert. Following the release, Plains indicates that it shut down the pipeline and initiated its emergency response plan. A Unified Command, which included the U.S. Coast Guard, the EPA, the State of California Department of Fish and Wildlife (“CDFW”), the California Office of Spill Prevention and Response and the Santa Barbara Office of Emergency Management, was established for the response effort. Clean-up and remediation operations

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with respect to impacted shoreline and other areas has been determined by the Unified Command to be complete, and the Unified Command has been dissolved. Plains’ estimate of the amount of oil spilled, based on relevant facts, data and information, and as set forth in the Consent Decree described below, is approximately 2,934 barrels; of this amount, Plains estimated that 598 barrels reached the Pacific Ocean.

Several governmental agencies and regulators initiated investigations into the Line 324 incident, various claims were made against Plains and a number of lawsuits were filed against Plains, the majority of which Plains indicates have been resolved.

Following the Line 324 incident, Plains entered into a cooperative Natural Resource Damage Assessment (“NRDA”) process with the federal and state agencies designated or authorized by law to act as trustees for the natural resources of the United States and the State of California (collectively, the “Trustees”). Additionally, various government agencies sought to collect civil fines and penalties from Plains under applicable state and federal regulations. On March 13, 2020, Plains entered into a pre-negotiated settlement agreement in the form of a Consent Decree (the “Consent Decree”) with the U.S. Department of Justice, Environmental and Natural Resources Division, the U.S. Department of Transportation, Pipeline and Hazardous Materials Safety Administration, the EPA, CDFW, the California Department of Parks and Recreation, the California State Lands Commission, the California Department of Forestry and Fire Protection’s Office of the State Fire Marshal, Central Coast Regional Water Quality Control Board, and Regents of the University of California. The Consent Decree was approved and entered by the Federal District Court for the Central District of California on October 14, 2020. The Consent Decree resolved all regulatory claims related to the incident and Plains was required to pay various civil penalties and compensation related to the Line 324 incident. The Consent Decree also contains requirements for potentially restarting Line 324 and the Sisquoc to Pentland portion of Line 325.

On October 13, 2022, Plains sold Line 324 and the Sisquoc to Pentland portion of Line 325 to PPC. As required by the terms of the Consent Decree, PPC assumed responsibility for compliance with the Consent Decree as it relates to the future ownership and operation of Line 324 and the Sisquoc to Pentland portion of Line 325.

The EM-Plains Purchase Agreement requires Plains to indemnify EM against certain liabilities directly arising out of or directly relating to the oil spilled from Line 324 and the subsequent clean up and remediation. The Sable-EM Purchase Agreement requires EM to indemnify Sable against certain liabilities associated with the Line 324 incident prior to January 1, 2022 and for a period of two years following the closing under the Sable-EM Purchase Agreement.

We consider the following to be material, albeit achievable requirements to restarting Line 324 and Line 325: (1) satisfaction of all California Assembly Bill 864 (“AB-864”) provisions requiring pipelines be equipped with the Coastal Best Available Technology (“CBAT”) that provides the greatest degree of protection by limiting the quantity of release in the event of an oil spill, (2) approval by Santa Barbara County of PPC’s transition plan demonstrating we have adequate training and a good working knowledge of any and all county compliance plans, and (3) approval from the OSFM of a restart plan for Lines 324 and 325 (application for which is to be submitted at least 60 days prior to restart).

The parties continue to progress the processing and receipt of the above material regulatory actions in order to meet a production restart schedule of fourth quarter 2024:

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Given our current progress on these requirements, we believe that these requirements will not inhibit our ability to restart the onshore and offshore facilities consistent with our timeline of restarting production during fourth quarter 2024.

Operations

General

Sable is the owner of the SYU Assets and the Pipelines. Prior to consummation of the Business Combination, EM was the owner and operator of the SYU Assets and Plains was the owner and operator of the Pipelines. EM acquired the Pipelines from Plains on October 13, 2022 pursuant to the EM-Plains Purchase Agreement. In connection with the Business Combination, a substantial portion of the existing employees of SYU have continued in their same capacity with Sable. The offshore platforms have permanent drilling systems in place.

Title to Properties

The interests in the properties on which the SYU Assets and the Pipelines are located and their operations are conducted derive from ownership, leases, easements, rights-of-way, permits, or licenses from landowners or governmental authorities, permitting the use of such real property for their operations. EM did not make rental payments for use of a right-of-way easement for the Pipelines and there is some risk the government could allege the easement has lapsed, as further described under “Risk Factors— We do not own all of the land on which our assets are located or all of the land that we must traverse in order to conduct our operations. There are disputes with respect to certain of the rights-of-way or other interests and any unfavorable outcomes of such disputes could require us to incur additional costs.” Aside from the foregoing, the owners of the SYU Assets and the Pipelines believe they have satisfactory title or other rights to all such properties in accordance with industry standards, and Sable conducted thorough diligence and title investigations in advance of the Business Combination. Individual properties may be subject to burdens that do not materially interfere with the use or affect the value of the properties. Burdens on properties may include customary royalty interests, liens incident to operating agreements and for current taxes, obligations or duties under applicable laws, development obligations under natural gas leases, or net profits interests.

Delivery Commitments

Sable has no commitments to deliver a fixed and determinable quantity of its oil or natural gas production in the near future under any existing sales contracts.

Derivative Activities

Sable is not currently party to any commodity derivative contracts but as the restart of production approaches Sable may enter into commodity derivative contracts with unaffiliated third parties to achieve more predictable cash flows and to reduce exposure to fluctuations in oil and natural gas prices. Sable may enter into commodity derivative contracts at times and on terms desired to maintain a portfolio of commodity derivative contracts covering a specified percentage or range of its estimated production over a one-to-three-year period at any given point of time. It may, however, hedge more or less than this approximate amount from time to time.

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Sable is not currently party to any interest rate swaps and substantially all of Sable’s indebtedness from the Business Combination consists of fixed-rate indebtedness. However, if Sable incurs variable rate indebtedness in the future it may periodically enter into interest rate swaps to mitigate exposure to market rate fluctuations by converting variable interest rates to fixed interest rates.

Sable will only enter into derivative contracts with creditworthy counterparties (generally, financial institutions) deemed by management as competent and competitive market makers. Those counterparties may include existing or future lenders or their affiliates. Sable will continue to evaluate the benefit of employing derivatives in the future. Pursuant to the Term Loan, Sable has agreed not to enter into any derivative contracts until after the term loan is refinanced in full.

Competition

Sable operates in a highly competitive environment for securing trained personnel, contracting for drilling equipment, and from time to time leasing or otherwise acquiring new acreage. Many of its competitors possess and employ financial, technical and personnel resources substantially greater than Sable’s, which can be particularly important in the areas in which it operates. As a result, Sable’s competitors may be able to pay more for productive oil and natural gas properties and exploratory prospects, as well as evaluate, bid for and purchase a greater number of properties and prospects than its financial or personnel resources permit. Sable’s ability to acquire additional properties and to find and develop reserves and resources will depend on its ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. In addition, there is substantial competition for capital available for investment in the oil and natural gas industry and many of its competitors have access to capital at a lower cost than that available to SYU or Sable.

Seasonality

Sable’s offshore operations can be impacted by inclement weather from time to time. The price Sable will receive for natural gas production is typically impacted by seasonal fluctuations in demand for natural gas. The demand for natural gas typically peaks during the coldest months and tapers off during the milder months, with a slight increase during the summer to meet the demands of electric generators. The weather during any particular season can affect this cyclical demand for natural gas. Seasonal anomalies such as mild winters or hot summers can lessen or intensify this fluctuation. In addition, certain natural gas users utilize natural gas storage facilities and purchase some of their anticipated winter requirements during the summer. This can also lessen seasonal demand fluctuations. Recently there has been elevated global demand for natural gas due to shortages exacerbated by geopolitical issues and conflicts but there is no assurance that demand will remain elevated.

Insurance

In accordance with customary industry practice, Sable will maintain insurance against many, but not all, potential losses or liabilities arising from its operations and at costs that it believes to be economic. Sable will regularly review its risks of loss and the cost and availability of insurance and revise its insurance accordingly. Its insurance will not cover every potential risk associated with its operations, including the potential loss of significant revenues. Sable can provide no assurance that its coverage will adequately protect it against liability from all potential consequences, damages and losses. Prior to or upon the restart of production Sable expects to have insurance policies including the following:

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Sable monitors regulatory changes and comments and considers their impact on the insurance market, along with SYU’s overall risk profile. As necessary, Sable expects to adjust its risk and insurance program to provide protection at a level it considers appropriate while weighing the cost of insurance against the potential and magnitude of disruption to its operations and cash flows. Changes in laws and regulations could lead to changes in underwriting standards, limitations on scope and amount of coverage, and higher premiums, including possible increases in liability caps for claims of damages from oil spills.

Potential Opportunities for Carbon Sequestration

Sable may pursue new opportunities on the Outer Continental Shelf for long-term sequestration of carbon dioxide that would otherwise go into the atmosphere. The 2021 Infrastructure Investment and Jobs Act gives the Secretary of the Interior new authority to allow the long-term sequestration of carbon dioxide on the OCS and directs the Secretary to promulgate regulations to implement the authority. As the regulatory program is developed over time, Sable intends to evaluate the potential to leverage its infrastructure for carbon sequestration in light of the new program and applicable local, state, and federal permitting requirements.

Environmental, Occupational Safety and Health Matters and Regulations

General

SYU’s oil and natural gas development and production operations are subject to stringent and complex federal, state and local laws and regulations governing the release or discharge of materials into the environment, health and safety aspects of its operations, or otherwise relating to protection of the environment and natural resources. These laws and regulations impose numerous obligations applicable to its operations, as well as future plug and abandonment and decommissioning activities, including the issuance of certain permits before conducting regulated drilling activities; the restriction of types, quantities and concentration of materials that can be released or discharged into or through the environment; the limitation or prohibition of drilling activities on certain lands lying within wilderness, wetlands, seismically active areas and other protected or preserved areas; the application of specific health and safety criteria addressing worker protection; and the imposition of substantial liabilities for pollution and natural resources damages potentially resulting from its operations. Numerous governmental authorities, such as the EPA, PHMSA, OSFM, CalGEM and the California State Lands Commission, and other governmental agencies have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring difficult and costly compliance or corrective actions. Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil or criminal penalties, the imposition of investigatory or remedial obligations, injunctive relief, the suspension or revocation of necessary permits, licenses and authorizations, the requirement that additional pollution controls be installed and in some instances, the issuance of orders limiting or prohibiting some or all of its operations. We may also experience delays in obtaining or be unable to obtain required permits, including authorizations necessary to restart or replace the Pipelines, which may delay or interrupt SYU’s operations and limit its growth and revenue. In addition, the long-term trend in environmental regulation has been to place more restrictions and limitations on activities that may affect the environment. SYU’s costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to its operations. Changing perspectives within the Executive Branch of the U.S. federal government and environmental litigation involving the validity of certain regulatory requirements associated with exploration, development and decommissioning may materially impact our compliance costs. Consequently, SYU’s costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to its operations.

Under certain environmental laws that impose strict as well as joint and several liability, SYU may be required to remediate contaminated properties currently or formerly owned or operated by it or facilities of third parties that

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received waste generated by its operations, regardless of whether such contamination resulted from its conduct or the conduct of others that was in compliance with all applicable laws at the time of such conduct. In addition, claims for damages to persons or property, including natural resources, may result from the environmental, health and safety impacts of its operations. Moreover, public interest in the protection of the environment has increased in recent years. New laws and regulations continue to be enacted, particularly at the state level, and the long-term trend of more expansive and stringent environmental legislation and regulations applied to the crude oil and natural gas industry could continue, resulting in increased costs of doing business and consequently affecting profitability. To the extent new or more stringent laws are enacted or other governmental action is taken that restricts drilling or imposes more stringent and costly operating, waste handling, disposal and cleanup requirements, SYU’s business, prospects, financial condition or results of operations could be materially adversely affected.

The following is a summary of the more significant existing environmental, occupational safety and health laws and regulations to which SYU’s business operations are subject and for which compliance may have a material adverse impact on its capital expenditures, results of operations or financial position.

Offshore Operations

Our oil and gas operations associated with SYU are conducted on offshore leases in federal waters and those operations are regulated by agencies such as BOEM and BSEE, which have broad authority to regulate oil and gas operations associated with SYU.

BOEM is responsible for managing environmentally and economically responsible development of the nation’s offshore resources. Its functions include offshore leasing, resource evaluation, review and administration of oil and gas exploration and development plans, renewable energy development, and National Environmental Policy Act (“NEPA”) analysis and environmental review. Lessees must obtain BOEM approval for exploration, development and production plans prior to the commencement of offshore operations. BOEM generally requires that lessees have substantial net worth, post supplemental bonds or provide other acceptable assurances that the lease obligations will be met. In April 2024, BOEM published a proposed final rule that, if adopted, would substantially revise the financial assurance requirements applicable to offshore oil and gas operations by requiring certain oil, gas, and sulfur lessees; right-of-use and easement grant holders; and pipeline right-of-way grant holders to obtain supplemental financial assurance for decommissioning activities on Outer Continental Shelf (“OCS”) leases, rights-of-way and rights-of-use and easements. The final rule became effective on June 29, 2024.

BSEE is responsible for safety and environmental oversight of offshore oil and gas operations. Its functions include the development and enforcement of safety and environmental regulations, permitting offshore exploration, development and production, inspections, offshore regulatory programs, oil spill response and training and environmental compliance programs. BSEE regulations require offshore production facilities and pipelines located on the OCS to meet stringent engineering and construction specifications, and BSEE has proposed and/or promulgated additional safety-related regulations concerning the design and operating procedures of these facilities and pipelines, including regulations to safeguard against or respond to well blowouts and other catastrophes. BSEE regulations also restrict the flaring or venting of natural gas, prohibit the flaring of liquid hydrocarbons and govern the plugging and abandonment of wells located offshore and the installation and removal of all fixed drilling and production facilities. In April 2023, BSEE issued a final rule clarifying and providing transparency to the process by which BSEE will enforce decommissioning obligations on existing lessees and rights-of-use and easement grant holders. BSEE’s final rule adopted new timeframes for predecessors to respond to a decommissioning order to perform accrued decommissioning obligations, and clarified that right-of-use and easement grant holders also accrue decommissioning obligations.

BOEM and BSEE have adopted regulations providing for enforcement actions, including civil penalties and lease forfeiture or cancellation for failure to comply with regulatory requirements for offshore operations. If we fail to

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pay royalties or comply with safety and environmental regulations, BOEM and BSEE may take action that seeks the curtailment, suspension, or termination of SYU’s operations and we may be subject to civil or criminal liability.

Additionally, delays in the approval or refusal of plans and issuance of permits by BOEM or BSEE because of staffing, economic, environmental, legal or other reasons (or other actions taken by BOEM or BSEE) could adversely affect SYU’s offshore operations. The requirements imposed by BOEM and BSEE regulations are frequently changed and subject to new interpretations. Also, in addition to permits and approvals required by BOEM and BSEE, approvals and permits may be required from other agencies for the oil and gas operations associated with SYU’s properties, such as the U.S. Coast Guard, the EPA, U.S. Department of Transportation, U.S. Army Corps of Engineers and state and local authorities.

Hazardous Substances and Waste Handling

Our operations are subject to environmental laws and regulations relating to the management and release of hazardous substances, solid and hazardous wastes and petroleum hydrocarbons. These laws generally regulate the generation, storage, treatment, transportation and disposal of solid and hazardous waste and may impose strict and, in some cases, joint and several liability for the investigation and remediation of affected areas where hazardous substances may have been released or disposed. The Comprehensive Environmental Response, Compensation and Liability Act, as amended (“CERCLA”), also referred to as the Superfund law and comparable state laws, impose liability, without regard to fault or the legality of the original conduct, on certain potentially responsible parties. These persons include current owners or operators of the site where a release of hazardous substances occurred, prior owners or operators that owned or operated the site at the time of the release or disposal of hazardous substances and companies that disposed or arranged for the disposal of the hazardous substances found at the site. Under CERCLA, these persons may be subject to strict and joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover the costs they incur from the responsible classes of persons. Despite the “petroleum exclusion” of Section 101(14) of CERCLA, which currently encompasses natural gas, SYU may nonetheless handle hazardous substances within the meaning of CERCLA, or similar state statutes, in the course of its ordinary operations and as a result, may be jointly and severally liable under CERCLA for all or part of the costs required to clean up sites at which these hazardous substances have been released into the environment. Also, comparable state statutes may not contain a similar exemption for petroleum, and it is also not uncommon for neighboring landowners and other third parties to file common law-based claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. In addition, SYU may have liability for releases of hazardous substances at its properties by prior owners or operators or other third parties.

The Oil Pollution Act is the primary federal law imposing oil spill liability. The Oil Pollution Act contains numerous requirements relating to the prevention of, and response to petroleum releases into waters of the United States, including the requirement that operators of offshore facilities and certain onshore facilities near or crossing waterways must maintain certain significant levels of financial assurance to cover potential environmental cleanup and restoration costs. Under the Oil Pollution Act, strict, joint and several liability may be imposed on “responsible parties” for all containment and cleanup costs and certain other damages arising from a release, including, but not limited to, the costs of responding to a release of oil to surface waters and natural resource damages resulting from oil spills into or upon navigable waters, adjoining shorelines or in the exclusive economic zone of the United States. A “responsible party” includes the owner or operator of an onshore facility. The Oil Pollution Act establishes a liability limit for onshore facilities, but these liability limits may not apply if: a spill is caused by a party’s gross negligence or willful misconduct; the spill resulted from violation of a federal safety, construction or operating regulation; or a party fails to report a spill or to cooperate fully in a cleanup. We are also subject to analogous state statutes that impose liabilities with respect to oil spills. For example, the

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California Department of Fish and Wildlife’s Office of Oil Spill Prevention and Response has adopted oil-spill prevention regulations that overlap with federal regulations.

We also generate solid wastes, including hazardous wastes, which are subject to the requirements of the Resource Conservation and Recovery Act, as amended (“RCRA”), and comparable state statutes. Although RCRA regulates both solid and hazardous wastes, it imposes stringent requirements on the generation, storage, treatment, transportation and disposal of hazardous wastes. Certain petroleum production wastes are excluded from RCRA’s hazardous waste regulations. These wastes, instead, are regulated under RCRA’s less stringent solid waste provisions, state laws or other federal laws. It is possible that these wastes, which could include wastes expected to be generated during SYU’s operations, could be designated as “hazardous wastes” in the future and, therefore, be subject to more rigorous and costly disposal requirements. Indeed, legislation has been proposed from time to time in Congress to re-categorize certain oil and gas exploration and production wastes as “hazardous wastes.” Also, in December 2016, the EPA entered into a consent decree requiring it to review its regulation of oil and gas waste. In April 2019, the EPA determined that revisions to the RCRA regulations were not required, concluding that any adverse effects related to oil and gas waste are more appropriately and readily addressed within the framework of existing state regulatory programs. However, any such changes to state programs could result in an increase in SYU’s costs to manage and dispose of oil and gas waste, which could have a material adverse effect on its maintenance capital expenditures and operating expenses.

It is possible that SYU’s oil and natural gas operations may require it to manage naturally occurring radioactive materials (“NORM”). NORM is present in varying concentrations in sub-surface formations, including hydrocarbon reservoirs, and may become concentrated in scale, film and sludge in equipment that comes into contact with crude oil and natural gas production and processing streams. Some states have enacted regulations governing the handling, treatment, storage and disposal of NORM.

Administrative, civil and criminal penalties can be imposed for failure to comply with hazardous substance and waste handling requirements. For ownership and operation of the idled SYU and Pipelines, we believe that we are in substantial compliance with the requirements of CERCLA, Oil Pollution Act, RCRA and other applicable federal and related state and local laws and regulations, and that we hold all necessary and up-to-date permits, registrations and other authorizations required under such laws and regulations. Although SYU believes that the costs of managing its hazardous substances and wastes as they are presently classified are reflected in its budget, any legislative or regulatory reclassification of oil and natural gas exploration and production wastes could increase its costs to manage and dispose of such wastes.

Water Discharges

The Federal Water Pollution Control Act (the “Clean Water Act”), the Safe Drinking Water Act (“SDWA”), the Oil Pollution Act and analogous state laws, impose restrictions and strict controls with respect to the discharge of pollutants, including oil and hazardous substances, into navigable waters of the United States, as well as state waters. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. These laws and regulations also prohibit certain activity in wetlands unless authorized by a permit issued by the U.S. Army Corps of Engineers. In May 2023, the Supreme Court issued an opinion in Sackett v. EPA that limited the jurisdiction of the U.S. Army Corps of Engineers to wetlands with a continuous surface connection to a permanent body of water connected to traditional navigable waters, such as streams, oceans, rivers, and lakes. To the extent a new rule or further litigation expands the scope of the Clean Water Act’s jurisdiction or impacts available agency resources, we could face increased costs and/or delays with respect to obtaining permits for dredge and fill activities in wetland areas.

The EPA has also adopted regulations requiring certain oil and natural gas exploration and production facilities to obtain individual permits or coverage under general permits for storm water discharges. Costs may be associated with the treatment of storm water or developing and implementing storm water pollution prevention

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plans, as well as for monitoring and sampling the storm water runoff from certain of SYU’s facilities. Some states also maintain groundwater protection programs that require permits or specify other requirements for discharges or operations that may impact groundwater conditions. These same regulatory programs may also limit the total volume of water that can be discharged, hence limiting the rate of development and requiring us to incur compliance costs. Additionally, we are required to develop and implement spill prevention, control and countermeasure plans, in connection with on-site storage of significant quantities of oil.

These laws and any implementing regulations provide for administrative, civil and criminal penalties for any unauthorized discharges of oil and other substances in reportable quantities and may impose substantial potential liability for the costs of removal, remediation and damages. Additionally, obtaining permits has the potential to delay the development of natural gas and oil projects. For ownership and operation of the idled SYU and Pipelines, we believe that we maintain all required discharge permits necessary to conduct our operations and that we are in substantial compliance with their terms.

In addition, in some instances the operation of underground injection wells for the disposal of wastewater has been alleged to cause earthquakes. For example, the EPA released a report with findings and recommendations related to public concern about induced seismic activity from disposal wells. The report recommended strategies for managing and minimizing the potential for significant injection-induced seismic events. Any future orders or regulations addressing concerns about seismic activity from well injection could affect or curtail SYU’s operations.

Air Emissions

The federal Clean Air Act, as amended (“CAA”), and comparable state laws restrict the emission of air pollutants from many sources, including compressor stations, through the issuance of permits and the imposition of other requirements. The SYU properties and associated facilities are also subject to regulation by state and local authorities. Federal and state laws and regulations may require us to obtain pre-approval for the construction or modification of certain projects or facilities expected to produce or significantly increase air emissions, obtain and strictly comply with stringent air permit requirements or utilize specific equipment or technologies to control emissions of certain pollutants.

The EPA has developed, and continues to develop, stringent regulations governing emissions of air pollutants at specified sources. New facilities may be required to obtain permits before work can begin, and modified and existing facilities may be required to obtain additional permits. In June 2016, the EPA finalized regulations establishing New Source Performance Standards, known as Subpart OOOOa, for methane and volatile organic compounds from new and modified oil and natural gas production and natural gas processing and transmission facilities. In September 2020, the EPA finalized two sets of amendments to the 2016 Subpart OOOOa standards. The first, known as the 2020 Technical Rule, reduced the 2016 rule’s fugitive emissions monitoring requirements and expanded exceptions to pneumatic pump requirements, among other changes. The second, known as the 2020 Policy Rule, rescinded the methane-specific requirements for certain oil and natural gas sources in the production and processing segments. On January 20, 2021, President Biden issued an Executive Order directing the EPA to rescind the 2020 Technical Rule by September 2021 and consider revising the 2020 Policy Rule. On June 30, 2021, President Biden signed a Congressional Review Act (“CRA”) resolution passed by Congress that revoked the 2020 Policy Rule. The CRA did not address the 2020 Technical Rule.

Further, on November 15, 2021, the EPA issued a proposed rule intended to reduce methane emissions from oil and gas sources. The proposed rule would make the existing regulations in Subpart OOOOa more stringent and create a Subpart OOOOb to expand reduction requirements for new, modified, and reconstructed oil and gas sources, including standards focusing on certain source types that have never been regulated under the CAA (including intermittent vent pneumatic controllers, associated gas, and liquids unloading facilities). In addition, the proposed rule would establish “Emissions Guidelines,” creating a Subpart OOOOc that would require states to develop plans to reduce methane emissions from existing sources that must be at least as effective as

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presumptive standards set by the EPA. On December 6, 2022, the EPA issued a supplemental proposed rule to reduce methane emissions from oil and natural gas operations. The supplemental proposed rule added proposed requirements for additional sources not covered by the November 2021 proposed rule and provided additional detail to assist states in developing their compliance plans. The EPA announced that it had finalized the rule on December 2, 2023. While the final version of the rule has not yet been published in the Federal Register, as currently written the final rule would subject new, modified, and reconstructed oil and gas sources to emissions reduction requirements and require states to develop the required plans on a modified timeline.

Similarly, in September 2018, the BLM issued a rule that relaxed or rescinded certain requirements of the agency’s 2016 Waste Prevention Rule, which aimed to reduce methane emissions from venting, flaring, and leaks during oil and gas operations on public lands, but both the 2016 rule and its 2018 rescission were invalidated in federal district court. Environmental groups appealed the invalidation of the 2016 rule to the U.S. Court of Appeals for the Tenth Circuit, which is stayed pending a review of the rule by BLM. As a result of these regulatory changes, the scope of any final methane regulations or the costs for complying with the federal methane regulations are uncertain. However, any future changes to the regulations governing methane emissions, and other air quality programs, may require us to obtain pre-approval for the expansion or modification of existing facilities or the construction of new facilities expected to produce air emissions, impose stringent air permit requirements, or utilize specific equipment or technologies to control emissions. Compliance with such rules could result in significant costs, including increased capital expenditures and operating costs, and could adversely impact SYU’s business.

On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (the “Inflation Reduction Act”). The Inflation Reduction Act amends the Clean Air Act to impose a fee on the emission of methane from sources required to report their GHG emissions to the EPA, including those sources in the petroleum and natural gas production category. The methane emissions charge will start in calendar year 2024 at $900 per ton of methane, increase to $1,200 in 2025, and be set at $1,500 for 2026 and each year thereafter. Calculation of the fee is based on certain thresholds established in the Inflation Reduction Act. The methane emissions charge may have the effect of increasing our capital expenditures to limit methane releases and increasing our costs to the extent we exceed the limits.

SYU may be required to incur certain capital expenditures in the next few years for air pollution control equipment in connection with maintaining or obtaining operating permits addressing air emission related issues, which may have a material adverse effect on its operations. Obtaining permits also has the potential to delay the development of oil and natural gas projects and increase their costs of development, which costs could be significant. SYU believes that it is currently in substantial compliance with all air emissions regulations and that it holds all necessary and valid construction and operating permits for its current operations.

Regulation of “Greenhouse Gas” Emissions

In December 2015, the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change resulted in nearly 200 countries, including the United States, coming together to develop the Paris Agreement, which calls for the parties to undertake “ambitious efforts” to limit the average global temperature. Although the agreement does not create any binding obligations for nations to limit their greenhouse gas emissions, it does include pledges to voluntarily limit or reduce future emissions. On June 1, 2017, President Trump announced that the U.S. would withdraw from the Paris Agreement and completed the process of withdrawing on November 4, 2020. However, on January 20, 2021, President Biden issued written notification to the United Nations of the United States’ intention to rejoin the Paris Agreement, which became effective on February 19, 2021. In addition, in September 2021, President Biden publicly announced the Global Methane Pledge, a pact that aims to reduce global methane emissions at least 30% below 2020 levels by 2030. Since its formal launch at the United Nations Climate Change Conference (“COP26”), over 100 countries have joined the pledge.

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While Congress has from time to time considered legislation to reduce emissions of GHGs, there has not been significant, economy-wide activity in the form of adopted legislation to reduce GHG emissions at the federal level in recent years. However, on August 16, 2022, President Biden signed the Inflation Reduction Act into law, which imposes fees on methane emissions, beginning in calendar year 2024. In the absence of significant federal climate legislation, a number of states have taken legal measures to reduce emissions of GHGs, including through the planned development of GHGs emission inventories and/or regional GHGs cap and trade programs.

The adoption and implementation of any regulations imposing reporting obligations on, or limiting emissions of GHGs from, SYU’s equipment and operations could require it to incur costs to reduce emissions of GHGs or could adversely affect demand for the oil and natural gas it produces. For example, any GHG regulation could increase its costs of compliance by potentially delaying the receipt of permits and other regulatory approvals; requiring it to monitor emissions, install additional equipment or modify facilities to reduce GHG and other emissions; purchase emission credits; or utilize electric driven compression at facilities to obtain regulatory permits and approvals in a timely manner. Such climate change regulatory and legislative initiatives could have a material adverse effect on SYU’s business, financial condition and results of operations.

While SYU is subject to certain federal GHG monitoring and reporting requirements, its operations are not adversely impacted by existing federal, state and local climate change initiatives and, at this time, it is not possible to accurately estimate how potential future laws or regulations addressing GHG emissions would impact its business.

In addition, claims have been made against certain energy companies alleging that GHG emissions from oil and natural gas operations constitute a public nuisance or have caused other redressable injuries under federal and/or state common law. While SYU’s business is not a party to any such litigation, it could be named in actions making similar allegations. An unfavorable ruling in any such case could adversely impact its business, financial condition and results of operations.

Moreover, any legislation or regulatory programs to reduce GHG emissions could increase the cost of consumption, and thereby reduce demand for, the oil and natural gas we produce. Consequently, legislation and regulatory programs to reduce emissions of GHGs could have an adverse effect on SYU’s business, financial condition and results of operations. Incentives to conserve energy or use alternative energy sources as a means of addressing climate change could also reduce demand for the oil and natural gas we produce. In addition, parties concerned about the potential effects of climate change have directed their attention at sources of funding for energy companies, which has resulted in certain financial institutions, funds and other sources of capital restricting or eliminating their investment in oil and natural gas activities. Finally, it should be noted that most scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events. If any such effects were to occur in sufficient proximity to SYU’s facilities, they could have an adverse effect on SYU’s development and production operations, as well as potentially increased costs for insurance coverages in the aftermath of such effects.

National Environmental Policy Act

Oil and natural gas exploration and production activities on federal lands are subject to NEPA. NEPA requires federal agencies, including the U.S. Departments of the Interior and Agriculture, to evaluate major federal actions having the potential to significantly impact the human environment. In July 2020, the White House’s Council on Environmental Quality published a final rule to amend the NEPA implementing regulations intended to streamline the environmental review process, including shortening the time for review as well as eliminating the requirement to evaluate cumulative impacts. The new regulations are subject to ongoing litigation, which has been stayed pending an ongoing review of the 2020 rule. On October 7, 2021, the Council on Environmental Quality published its Phase 1 rule, the first of two planned rules to roll back the 2020 rule. On July 28, 2023, the Council on Environmental Quality proposed its Phase 2 rule. If finalized, the Phase 2 rule could substantially

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alter how federal agencies carry out their responsibilities under NEPA by requiring agencies to consider climate change impacts and disproportionate impacts to communities with environmental justice concerns, among other things. All of SYU’s current and proposed development and production activities and plans on federal lands, including those in the Pacific Ocean, require governmental permits that are expected to be subject to the requirements of NEPA. This environmental review process has the potential to delay the development of oil and natural gas projects. Authorizations under NEPA also are subject to protest, appeal or litigation, which can delay or halt projects.

Endangered Species Act and Migratory Bird Treaty Act

The federal ESA and analogous state statutes restrict activities that may adversely affect endangered and threatened species or their habitat. In August 2019, the U.S. Fish and Wildlife Service (the “FWS”) and National Marine Fisheries Service (“NMFS”) issued three rules amending the implementation of the ESA regulations revising, among other things, the process for listing species and designating critical habitats. A coalition of states and environmental groups have challenged these rules and the litigation remains pending. In addition, on December 18, 2020, the FWS amended its regulations governing critical habitat designations and the amended regulations are subject to ongoing litigation. In June 2021, FWS and NMFS announced plans to begin rulemaking processes to rescind these rules. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act (“MBTA”), which makes it illegal to, among other things, hunt, capture, kill, possess, sell, or purchase migratory birds, nests, or eggs without a permit. This prohibition covers most bird species in the U.S. On January 7, 2021, the Department of the Interior finalized a rule limiting the application of the MBTA. However, the Department of the Interior revoked the rule in October 2021 and issued an advanced notice of proposed rulemaking seeking comment on the Department of the Interior’s plan to develop regulations that authorize incidental take under certain prescribed conditions. Future implementation of the rules implementing the ESA and the MBTA are uncertain. The designation of previously unidentified endangered or threatened species in areas where we operate could cause us to incur additional costs or become subject to operating delays, restrictions or bans. Numerous species have been listed or proposed for protected status in areas in which we currently, or could in the future, undertake operations. The presence of protected species in areas where SYU operates could impair its ability to timely complete or carry out those operations, lose leaseholds if it is not permitted to timely commence drilling operations, cause it to incur increased costs arising from species protection measures, and consequently, adversely affect its results of operations and financial position.

Occupational Safety and Health

We are also subject to the requirements of the federal Occupational Safety and Health Act (“OSHA”) and comparable state laws that regulate the protection of the health and safety of employees. In addition, OSHA’s hazard communication standard requires that information be maintained about hazardous materials used or produced in SYU’s operations and that this information be provided to employees, state and local government authorities and citizens. Other OSHA standards regulate specific worker safety aspects of SYU’s operations. For example, under a new OSHA standard limiting respirable silica exposure, the oil and gas industry was required to implement engineering controls and work practices to limit exposures below the new limits by June 2021. Failure to comply with OSHA requirements can lead to the imposition of penalties. SYU believes that its operations are in substantial compliance with the OSHA requirements.

Other Regulation of the Oil and Natural Gas Industry

The oil and natural gas industry is extensively regulated by numerous federal, state and local authorities. Legislation affecting the oil and natural gas industry is under constant review for amendment or expansion, frequently increasing the regulatory burden on SYU’s assets. For instance, the U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration (“PHMSA”), which regulates our hazardous liquid and natural gas pipelines and pipeline facilities, is reauthorized by Congress every four years by statute. When reauthorizing PHMSA’s authority to regulate natural gas and hazardous liquid pipelines and facilities, Congress

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often imposes mandates that require PHMSA to implement new regulatory requirements. Congress is currently drafting legislation for PHMSA’s reauthorization, which is scheduled to be completed by the end of 2024.

Numerous departments and agencies, both federal and state, are authorized by statute to issue rules and regulations that are binding on the oil and natural gas industry and its individual members, some of which carry substantial penalties for failure to comply. Although the regulatory burden on the oil and natural gas industry increases SYU’s cost of doing business and, consequently, affects its profitability, these burdens generally do not affect SYU any differently or to any greater or lesser extent than they affect other companies in the oil and natural gas industry with similar types, quantities and locations of production.

Legislation continues to be introduced in Congress, and the development of regulations continues by the U.S. Department of Homeland Security and other agencies concerning the security of industrial facilities, including oil and natural gas facilities. SYU’s operations may be subject to such laws and regulations. Presently, it is not possible to accurately estimate the costs we could incur to comply with any such facility security laws or regulations, but such expenditures could be substantial.

Drilling and Production

SYU’s operations are subject to various types of regulation at federal, state and local levels. These types of regulation include requiring permits for the drilling of wells, drilling bonds and reports concerning operations, including regulating one or more of the following:

Sale and Transportation of Gas and Oil

At the federal level, PHMSA regulates hazardous liquid and natural gas pipelines and pipeline facilities, including associated storage, pursuant to the Hazardous Liquids Pipeline Safety Act of 1979, as amended (the “HLPSA”), and the Natural Gas Pipeline Safety Act of 1968, as amended (the “NGPSA”). Federal regulations implementing the HLPSA and NGPSA establish minimum safety standards for pipeline transportation applicable to owners or operators of pipeline facilities regarding the design, installation, inspection, emergency plans and procedures, testing, construction, extension, operation, replacement, and maintenance of pipeline facilities. Among other things, these regulations require pipeline operators to conduct extensive emergency incident response training for pipeline personnel, including spill response drills for hazardous liquids pipelines. These regulations also require pipeline operators to develop and maintain a written qualification program for individuals performing covered tasks on pipeline facilities.

As part of its authority, PHMSA regulates the safety of pipeline transportation in or affecting interstate or foreign commerce, including pipeline facilities on the OCS. Pipelines 324 and 325 are subject to regulation by PHMSA.

At the state level, our intrastate hazardous liquid and natural gas pipeline facilities are regulated by the CPUC and OSFM. The CPUC has jurisdiction over the construction and operations of intrastate natural gas pipeline facilities in California and the rates, terms and conditions of service under which companies provide intrastate transportation of gas, oil and other liquids by pipeline. If the Pipelines engage in intrastate common carrier

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operations, the Pipelines will be subject to regulation by the CPUC and intrastate tariffs filed by us with the CPUC will be regulated under a cost-of-service methodology and established on the basis of revenues, expenses and any investments. A variety of factors can affect the rates of return permitted by the CPUC. Tariff rates with respect to intrastate pipeline service in California are subject to challenge by complaint by interested parties or by independent action of the CPUC. The CPUC could limit our ability to increase our rates or could order us to reduce our rates and require the payment of refunds to shippers. The OSFM regulates the safety of intrastate hazardous liquid pipeline facilities in California. Both the CPUC and the OSFM are certified by PHMSA to regulate intrastate pipeline safety as certified state partners under the natural gas program and hazardous liquid program, respectively. Through this certification with PHMSA, they are required to adopt the minimum federal pipeline safety regulations and they may establish more stringent regulatory requirements as long as they are compatible with federal regulations.

Our transportation of gas, oil and other liquids by pipeline in California is also subject to state and local regulation. Opposition from community members or state and local government officials to pipeline infrastructure could delay or prevent us from obtaining permits required for the operation of or updates made to our Pipelines.

PHMSA has broad authority to investigate potential compliance issues, issue requests for information, inspect pipelines facilities, and issue enforcement. PHMSA’s enforcement authority includes the ability to issue corrective actions, which may include the shut down or restriction of the operation pressure of a pipeline pending completion of the corrective measures. Federal pipeline safety regulations include reporting, design, construction, testing, operations and maintenance, qualification, corrosion control, and other minimum requirements.

Operators are required to prepare procedural manuals to implement these minimum requirements and those procedures are enforceable by PHMSA. Effective April 2017, PHMSA adopted new rules significantly increasing the maximum administrative civil penalties for violation of the pipeline safety laws and regulations.

PHMSA updates the maximum administrative civil penalties each year to account for inflation, and as of January 2024, the penalty limits are up to $266,015 per violation per day and up to $2,660,135 for a related series of violations.

PHMSA is active in proposing and finalizing additional regulations for natural gas and hazardous liquids pipelines. For example, in October 2019 PHMSA finalized new regulations for hazardous liquid pipelines that significantly extend and expand the reach of certain PHMSA integrity management requirements (i.e., periodic assessments, repairs and leak detection), regardless of the pipeline’s proximity to a high consequence area (“HCA”). The final rule also requires all pipelines in or affecting an HCA to be capable of accommodating in-line inspection tools within the next 20 years. In addition, the final rule extends annual and accident reporting requirements to gravity lines and all liquids gathering lines and also imposes inspection requirements on pipelines in areas affected by extreme weather events and natural disasters, such as hurricanes, landslides, floods, earthquakes, or other similar events that are likely to damage infrastructure.

In addition, in April 2016, PHMSA proposed a rule regarding the safety of natural gas transmission pipelines and gas gathering pipelines. This proposed rule resulted in three separate final rules applicable to natural gas pipelines: (1) an October 2019 final rule on the natural gas transmission lines focused on material verification and maximum allowable operating pressure reconfirmation; (2) a November 2021 final rule applicable to onshore gas gathering lines; and (3) an August 24, 2022 final rule applicable to gas transmission lines with a focus on repair criteria and corrosion. Under the final November 2021 rules applicable to gas gathering lines, operators of certain onshore natural gas gathering pipelines that were previously excluded from certain PHMSA regulations face additional testing, safety and reporting requirements or may be forced to reduce their allowable operating pressures, which would reduce the amount of capacity available to us. Certain reporting requirements arising from the new PHMSA gas gathering rule took effect in May 2022, with additional requirements taking effect

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later in 2022 and 2023. Other recent rules include an April 8, 2022 final rule requiring installation of remote control or automatic shutoff valves (or equivalent technology) on certain newly constructed or entirely replaced onshore transmissions pipelines, gathering pipelines (liquid and gas), and hazardous liquids pipelines.

In May 2023, PHMSA also issued a notice of proposed rulemaking that proposes to implement new and additional leak detection and repair requirements for natural gas pipelines. This proposed rule seeks to reduce methane emissions associated with the operation of natural gas pipelines by strengthening leakage survey and patrolling requirements, imposing an advanced leak detection program performance standard, implementing grading and repair schedules for identified leaks, requiring operators to reduce intentional sources of methane emissions, and expanding reporting requirements for methane emissions. The comment period on this proposal ended in August 2023.

Federal and state legislative and regulatory initiatives relating to pipeline safety that require the use of new or more stringent safety controls or result in more stringent enforcement of applicable legal requirements could subject us to increased capital costs, operational delays and costs of operation.

Anti-Market Manipulation Laws and Regulations

SYU’s sales of oil and natural gas are also subject to anti-manipulation and anti-disruptive practices authority under (i) the Commodity Exchange Act (“CEA”) and regulations promulgated thereunder by the CFTC, and (ii) the Energy Independence and Security Act of 2007 (“EISA”) and regulations promulgated thereunder by the FTC. The CEA prohibits any person from using or employing any manipulative or deceptive device in connection with any swap, or a contract for sale of any commodity, or for future delivery on such commodity, in contravention of the CFTC’s rules and regulations. It also prohibits knowingly delivering or causing to be delivered false, misleading or inaccurate reports concerning market information or conditions that affect or tend to affect the price of any commodity. The FTC’s Petroleum Market Manipulation Rule, issued pursuant to EISA, prohibits fraudulent or deceptive conduct (including false or misleading statements of material fact) in connection with wholesale purchases or sales of crude oil or refined petroleum products. Under both the CEA and the EISA, fines for violations can be up to $1,000,000 per day per violation (subject to adjustment for inflation) and certain knowing or willful violations may also lead to a felony conviction.

Derivatives Regulation

The Dodd-Frank Act directed the Commodities Futures Trading Commission (“CFTC”) to regulate certain markets for derivative products, including over-the-counter derivatives. Among other mandates, the CFTC has issued several new relevant regulations and rulemakings that require significant portions of the derivatives markets to clear through clearinghouses. While some of these rules have been finalized, some have not and the final form and timing of those rules remain uncertain.

In January 2020, the CFTC withdrew prior proposals and issued a new proposed rule, which includes limits on positions in (1) certain “Core Referenced Futures Contracts,” including contracts for several energy commodities; (2) futures and options on futures that are directly or indirectly linked to the price of a Core Referenced Futures Contract, or to the same commodity for delivery at the same location as specified in that Core Referenced Futures Contract; and (3) economically equivalent swaps. The proposal also includes exemptions from position limits for bona fide hedging activities. The proposal is not yet final and it remains subject to public comment and revision by the CFTC. Consequently, the potential impact of the proposed rule on SYU and its counterparties is uncertain at this time.

The Dodd-Frank Act and new related regulations may prompt potential derivative counterparties to spin off some of their derivatives activities to separate and less creditworthy entities. Any new regulations could significantly increase the cost of derivative contracts, materially alter the terms of derivative contracts, reduce the availability of derivatives to protect against risks we encounter, reduce SYU’s ability to monetize or restructure existing

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derivative contracts, and increase its exposure to less creditworthy counterparties. If SYU reduces its use of derivatives as a result of the regulations, its results of operations may become more volatile and its cash flows may become less predictable, which could adversely affect its ability to plan for and fund capital expenditures and to generate sufficient cash flow to pay dividends. Its revenues could be adversely affected if a consequence of the legislation and regulations is to lower commodity prices. Any of these consequences could have a material, adverse effect on SYU’s financial condition and results of operations. SYU’s use of derivative financial instruments does not eliminate its exposure to fluctuations in commodity prices and interest rates and could in the future result in financial losses or reduce its income.

Additional proposals and proceedings that may affect the crude oil and natural gas industry are pending before the U.S. Congress, federal agencies and the courts. SYU cannot predict the ultimate impact these proposals may have on its crude oil and natural gas operations, but it does not expect to be affected differently than its competitors.

State Regulation

The State of California also regulates the drilling for, and the production, gathering and sale of, oil and natural gas, and imposes taxes and drilling permit requirements. Among other things, the State of California also regulates the method of developing new fields, the spacing and operation of wells and the prevention of waste of natural gas resources. It does not regulate wellhead prices or engage in other similar direct economic regulation, but there can be no assurance that it will not do so in the future. The effect of these regulations may be to limit the amount of oil and natural gas that may be produced from SYU’s wells and to limit the number of wells or locations it can drill. The State of California has significantly increased the jurisdiction, duties and enforcement authority of CalGEM, the California State Lands Commission and other state agencies with respect to oil and natural gas activities in recent years, and CalGEM and other state agencies have also significantly revised their regulations, regulatory interpretations and data collection and reporting requirements. In addition, from time to time legislation has been introduced in the California Legislature seeking to further restrict or prohibit certain oil and gas operations. For additional information see “Risk Factors— Attempts by the California state government to restrict the production of oil and gas could negatively impact our operations and result in decreased demand for fossil fuels in California.”

Additionally, the rates charged by the Pipelines if engaged in intrastate common carrier operations will be subject to regulation by the CPUC under a cost-of-service methodology as described above under “ —Sale and Transportation of Gas and Oil.” For additional information, see “Risk Factors—If engaged in intrastate common carrier operations, our financial results with respect to the Pipelines will primarily depend on the outcomes of ratemaking proceedings with the California Public Utilities Commission and we may not be able to earn an adequate rate of return in a timely manner or at all.”

The petroleum industry is also subject to compliance with various other federal, state and local regulations and laws. Some of those laws relate to resource conservation and equal employment opportunity. We do not believe that compliance with these laws will have a material adverse effect on us.

Human Capital

Overview

As of June 30, 2024, we have approximately 123 employees, none of whom are represented by labor unions or covered by collective bargaining agreements. Under EM management, approximately 32 employees were previously represented by labor unions or covered by collective bargaining agreements. We strive to create a high-performing culture and positive work environment that allows us to attract and retain a diverse group of talented individuals who contribute to our success. To attract and retain top talent, our human resources programs are designed to reward and incentivize our employees through competitive compensation practices, our commitment to employee health and safety, training and talent development and our commitment to diversity and inclusion.

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Safety

Safety is our highest priority and we are dedicated to the well-being of our employees, contractors, business partners, stakeholders and the environment. We promote safety with a robust health and safety program, which includes employee orientation and training, contractor management, risk assessments, hazard identification and mitigation, audits, incident reporting and investigation, and corrective and preventative action development.

In addition, we employ environmental, health and safety personnel at each of our asset locations, who provide in-person safety training and regular safety meetings. We also utilize learning management software to provide safety training on a variety of topics, and we contract with third-party technical experts as needed to facilitate training on specialized topics that are unique to each of our areas of operation.

Compensation

We operate in a highly competitive environment and have designed our compensation program to attract, retain and motivate talented and experienced individuals. Our compensation philosophy is designed to align our workforce’s interests with those of our stakeholders and to reward them for achieving our business and strategic objectives and driving stockholder value. We consider competitive market compensation paid by our peers and other companies comparable to us in size, geographic location and operations in order to ensure compensation remains competitive and fulfills the goal of recruiting and retaining talented employees.

Training and Development

We are committed to the training and development of our employees. Employees are regularly provided training opportunities to develop skills in leadership, safety, and technical acumen, which bolster our efforts in conducting business in a safe manner and with high ethical standards. Further, supporting our employees in achieving their career and development goals is a key element of our approach to attracting and retaining top talent. We encourage our employees to advance their knowledge and skills and to network with other professionals in order to pursue career advancement and potential future opportunities with us. Our employees are able to attend training seminars and off-site workshops and to join professional associations that will enable them to remain up-to-date on the latest changes and best practices in their respective fields.

Diversity and Inclusion

We are committed to providing a diverse and inclusive workplace and career development opportunities to attract and retain talented employees. We recognize that a diverse workforce provides the opportunity to obtain unique perspectives, experiences, ideas, and solutions to help our business succeed. To that end, it is our policy to prohibit discrimination and harassment of any type and afford equal employment opportunities to employees and applicants without regard to race, color, religion, sex, national origin, age, disability, genetic information, veteran status, or any other basis protected by federal, state or local law. Further, it is our policy to forbid retaliation against any individual who reports, claims, or makes a charge of discrimination or harassment, fraud, unethical conduct, or a violation of company policies. To sustain and promote an inclusive culture, we maintain a robust compliance program rooted in our Code of Business Conduct and Ethics and other company policies, which provide policies and guidance on non-discrimination, anti-harassment, and equal employment opportunities. We require all employees to complete periodic training sessions on various aspects of our corporate policies through an annual acknowledgment and certification process.

Health and Wellness

We support our employees and their families by offering a robust package of health and welfare benefits, medical, dental, and vision insurance plans for employees and their families, life insurance and long-term disability plans, paid time off for holidays, vacation, sick leave, and other personal leave, and health and dependent care savings accounts. We also provide our employees with a 401(k) plan that includes a competitive company match, and employees have access to a variety of resources and services to help them plan for retirement.

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In addition to these programs, we have several other programs designed to further promote the health and wellness of its employees, as well as an employee assistance program that offers counseling and referral services for a broad range of personal and family situations.

In response to the COVID-19 pandemic, we implemented proactive measures to protect the health and safety of our employees. These measures have included implementation of a COVID-19 leave program to allow employees to take time off when they or their family members contract COVID-19, implementation of health screenings, COVID-19 testing for its offshore workforce, allowing employees to work remotely to reduce the number of employees on site in our field areas to comply with social distancing guidelines, maintaining social distancing policies, requiring the use of masks in compliance with governmental mandates, frequently and extensively disinfecting common areas, performing contact tracing protocols if and when necessary, and implementing quarantine requirements, among other things. We are committed to maintaining best practices with our COVID-19 response protocols and will continue to work under the guidance of public health officials to ensure a safe workplace as long as COVID-19 remains a threat to our employees and communities.

Offices

Our principal executive office is located at 845 Texas Avenue, Suite 2920, Houston, Texas 77002. Our main telephone number is (713) 579-6106.

Legal Proceedings

Proceedings and Investigations Relating to the Line 324 Incident

For information regarding the Line 324 incident and other legal proceedings, see “Business— Pipeline 324 Incident.”

Grey Fox Matter

On March 26, 2024, Sable entered into a Stipulation and Agreement of Settlement (the “Settlement Agreement”) among (i) Grey Fox, LLC, MAZ Properties, Inc., Bean Blossom, LLC, Winter Hawk, LLC, Mark Tautrim, Trustee of the Mark Tautrim Revocable Trust, and Denise McNutt, on behalf of themselves and the Court certified Settlement Class (the “Plaintiffs and Settlement Class Members”), (ii) Pacific Pipeline Company (“PPC”) and (iii) Sable, with respect to the settlement and release of certain claims related to the Pipelines, including claims impacting the right of way for the Pipelines (collectively, the “Released Claims”).

Pursuant to the terms of the Settlement Agreement, (i) the Plaintiffs and Settlement Class Members are obligated to, among other things, (a) release Sable, PPC and the other released parties from and against the Released Claims, (b) grant certain temporary construction easements to facilitate the repair of certain portions of the Pipelines, and (c) cooperate in good faith with Sable and PPC with respect to any and all steps reasonably required to restart the Pipelines and operate them thereafter, including obtaining all necessary regulatory approvals, consistent with the requirements of the relevant government agencies and the Consent Decree issued by the United States District Court for the Central District of California in relation to Civil Action No. 2:20 cv 02415 (United States of America and the People of the State of California v. Plains All American Pipeline, L.P. and Plains Pipeline, L.P.) and (ii) Sable has agreed to among other things, (a) pay $35.0 million into an interest bearing non reversionary Qualified Settlement Fund, and (b) deliver to class counsel an irrevocable direct pay letter of credit issued by J.P. Morgan & Co. or another federally insured bank in the amount of $35.0 million to secure Sable’s obligation to make certain payments under the Settlement Agreement.

On May 1, 2024, the United States District Court for the Central District of California entered an order granting preliminary approval of the Settlement Agreement. On May 9, 2024, the Company made the initial $35.0 million payment into the Qualified Settlement Fund and delivered the $35.0 million letter of credit to plaintiffs’ counsel.

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On September 17, 2024, the Court approved the Settlement Agreement in full. Pursuant to its terms, the Settlement Agreement will become effective thirty-five days thereafter, on October 22, 2024, in the absence of any post-judgment filing seeking appeal, review, or other relief in connection with the Settlement Agreement, the Settlement Class, and/or the Final Order and Judgment. If such document is filed or request is made, then the effective date will be thirty-five days after the date upon which any related proceedings are fully and finally terminated.

Upon the effective date, the settlement administrator will be authorized to make initial distributions from the Qualified Settlement Fund (from the initial $35.0 million payment) in accordance with the terms of the Settlement Agreement. Upon the final payment date, defined as the first of (a) one hundred eighty two calendar days following the restart of the SYU assets and the Pipeline and the resumption of oil sales therefrom, or (b) the date Sable pays ExxonMobil under the terms of the Purchase Agreement following the restart of the SYU assets and the Pipeline, or (c) June 30, 2025, the Class Counsel will be authorized to draw upon the irrevocable direct pay letter of credit for the remaining $35.0 million, together with certain interest earned thereupon, for deposit into the Settlement Fund and distribution in accordance with the terms of the Settlement Agreement.

Other Legal Proceedings

As part of Sable’s normal business activities, it may be named as a defendant in litigation and other legal proceedings, including those arising from regulatory and environmental matters. If Sable determines that a negative outcome is probable and the amount of loss is reasonably estimable, we will accrue the estimated amount. Sable is not aware of any pending or threatened legal proceedings against Sable as of the date of this prospectus and no amounts have been accrued for litigation or legal proceedings as of June 30, 2024. At times, SYU is involved in disputes or legal actions arising in the normal course of business. The outcome of such disputes or legal actions is not expected to have a material effect on SYU, and no amounts have been accrued as of June 30, 2024. There have been no fines or citations for any violations of governmental or environmental regulations that would have a material adverse effect on SYU as of December 31, 2023. See Note 5 “Commitments & Contingencies—Legal Proceedings” and “ —Government and Environmental Regulation” of the SYU financial statements.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with the accompanying combined financial statements and related notes of SYU included elsewhere in this prospectus. The combined financial statements of SYU do not reflect any results of operations of the Pipelines, and the discussion of historical results of operations below refers to the results of operations of SYU only. The following discussion contains forward-looking statements that reflect future plans, estimates, beliefs and expected performance of SYU and the SYU Assets. The forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. Actual results could differ materially from those discussed in these forward-looking statements. Such forward-looking statements relate to future events or future performance, but reflect management’s current beliefs, based on information currently available. A number of factors could cause actual events, performance, or results to differ materially from the events, performance and results discussed in the forward-looking statements. Please read “Risk Factors— Risks Related to the Business of the Company” and “Cautionary Note Regarding Forward-Looking Statements.” In light of these risks, uncertainties and assumptions, the forward-looking events discussed may not occur.

Overview

Sable Offshore Corp. is an independent oil and gas company headquartered in Houston, Texas. We were incorporated in Delaware on October 16, 2020 and, until February 14, 2024, were a blank check company formed for the purpose of effecting a merger, capital stock exchange, asset acquisition, stock purchase, reorganization or similar business combination with one or more businesses. We are an emerging growth company and, as such, we are subject to all of the risks associated with emerging growth companies.

Business Combination

On November 1, 2022 (as amended on June 13, 2023 and December 15, 2023), Sable Offshore Corp., a Texas corporation (“SOC”), entered into a purchase and sale agreement (the “Sable-EM Purchase Agreement”) with Exxon Mobil Corporation (“Exxon”) and Mobil Pacific Pipeline Company (“MPPC,” and together with Exxon, “EM”) pursuant to which SOC agreed to acquire from EM certain assets constituting the Santa Ynez field in Federal waters offshore California (“SYU”) and associated onshore processing and pipeline assets (such “Assets,” as defined in the Sable-EM Purchase Agreement, collectively the “SYU Assets”).

On November 2, 2022, Flame entered into an agreement and plan of merger, dated as of November 2, 2022 (as amended, the “Merger Agreement”), with SOC and Sable Offshore Holdings, LLC, a Delaware limited liability company and the parent company of SOC (“Holdco” and, together with SOC, “ Legacy Sable”), which provided for the following transactions at the closing: (i) Holdco would merge with and into Flame, with Flame surviving such merger (the “Holdco Merger”) and (ii) SOC would merge with and into Flame, with Flame surviving such merger (the “SOC Merger” and, together with the Holdco Merger, the “Mergers” and, along with the other transactions contemplated by the Merger Agreement, the “Business Combination”).

On February 12, 2024, Flame held a special meeting of stockholders (the “Special Meeting”), at which the Flame stockholders considered and adopted, among other matters, a proposal to approve the Business Combination, including (a) adopting the Merger Agreement and (b) approving the other transactions contemplated by the Merger Agreement.

Pursuant to the terms and subject to the conditions set forth in the Merger Agreement, following the Special Meeting, on February 14, 2024 (the “Closing Date”), the Business Combination was consummated (the “Closing”). In connection with the Business Combination, Flame changed its name to “Sable Offshore Corp.”.

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SYU

Beginning in 1968 and over the course of 14 years, EM consolidated more than a dozen offshore federal oil leases and organized them into a streamlined production unit known as SYU. SYU consists of three offshore platforms and a wholly owned onshore processing facility located along the Gaviota Coast at Las Flores Canyon in Santa Barbara County, California. SYU’s onshore facilities and the three offshore platforms remained in continuous operation until 2015. In May 2015, a pipeline operated by Plains All American Pipeline, L.P. (“Plains”) that transported produced oil from SYU experienced a leak, as further described under “Business—Pipeline 324 Incident.” The SYU platforms and facilities suspended production after the incident, the SYU Assets were shut in and the facilities were placed in a safe state. The facilities are not currently producing oil and gas; however, all equipment remains in place in an operation-ready state, requiring ongoing inspections, maintenance and surveillance. As part of these suspension efforts, all SYU equipment was drained, flushed and purged in 2016. All hydrocarbon pipelines within SYU have been placed in a safe state and remain under regular monitoring. In 2020, Plains entered into a Consent Decree, further described under “Business—Pipeline 324 Incident,” that provides a path for a potential restart of the Pipelines.

The discussion of the results of operations for the Predecessor periods below do not include the results from the Pipelines and the Pipelines are not included in the combined financial statements of the Predecessor included in the financial statements and related notes thereto included elsewhere in this Quarterly Report. Financial statements of the Pipelines have not been included because SEC guidance provides that the financial statements of recently acquired businesses such as the Pipelines need not be filed unless their omission would render Predecessors combined financial statements misleading or substantially incomplete. Based upon our quantitative and qualitative analysis, we do not believe omitting the financial statements of the Pipelines renders the Predecessor combined financial statements misleading or substantially incomplete. The Successor financial statements include the results from the Pipelines and the Pipelines are included in the unaudited condensed consolidated financial statements.

For the purposes of the unaudited condensed consolidated financial statements, periods on or before February 13, 2024 reflect the financial position, results of operations and cash flows of SYU prior to the Business Combination, referred to herein as the “Predecessor,” and periods beginning on or after February 14, 2024 reflect the financial position, results of operations and cash flows of the Company as a result of the Business Combination, referred to herein as the “Successor”.

Recent Events

On June 27, 2024, the Center for Biological Diversity and the Wishtoyo Foundation filed a complaint against Debra Haaland, Secretary of the U.S. Department of the Interior; the Bureau of Environmental Safety and Enforcement (“BSEE”); and Bruce Hesson, BSEE Pacific Regional Director in the U.S. District Court for the Central District of California (Case No. 2:24-cv-05459). In the complaint, plaintiffs allege that BSEE violated the National Environmental Policy Act (“NEPA”), the Outer Continental Shelf Lands Act (“OCSLA”), and the Administrative Procedure Act in November 2023 by approving an extension to resume operations associated with 16 oil and gas leases Sable holds in the Santa Ynez Unit in federal waters offshore of California in the Santa Barbara Channel. The complaint asks for the Court to issue an order finding that BSEE violated NEPA and OCSLA by approving the extension, to vacate and remand the extension to BSEE, to prohibit BSEE from authorizing further extensions until it complies with NEPA and OCSLA, and for an award of costs and attorneys’ fees. Although not named as a party to the case, Sable has moved to intervene to become a party to the lawsuit and to vigorously contest the plaintiffs’ allegations. Separately, BSEE has confirmed that Sable’s recent completion of lease-holding activities serves to maintain all 16 leases within the Santa Ynez Unit to October 9, 2025.

On July 29, 2024, PPC submitted restart plans for the Pipelines (the “Restart Plans”) to the California Department of Forestry and Fire Protection Office of the State Fire Marshal (“OSFM”) as required by the

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Consent Decree. PPC is required to submit the Restart Plans to the OSFM for approval at least sixty (60) days prior to returning the Pipelines to service.

On July 29, 2024, PPC submitted a letter to the OSFM requesting additional time to implement the 2021 CBAT Plan. On July 31, 2024, the OSFM approved PPC’s extension request, setting a new deadline for implementation of the approved 2021 CBAT Plan of July 1, 2025.

On August 30, 2024, Santa Barbara County acknowledged that it does not have jurisdiction over PPC’s installation of 16 new safety valves in Santa Barbara County along the Pipelines in accordance with AB-864. Santa Barbara County’s acknowledgement was delivered in the form of a conditional settlement agreement dated August 30, 2024 (the “Safety Valve Settlement Agreement”) among Santa Barbara County, PPC and the Company, and a subsequent acknowledgement by Santa Barbara County’s planning and development staff.

Pursuant to the Safety Valve Settlement Agreement, PPC agreed to the following additional surveillance and response enhancements in Santa Barbara County:

PPC, the Company and Santa Barbara County have further agreed, in the Safety Valve Settlement Agreement, to file a stipulation to dismiss the pending lawsuit, Pacific Pipeline Company and Sable Of shore Corp. v. Santa Barbara County Planning Commission and Board of Supervisors (Case No. 2:23-cv-09218-DMG-MRW) within 15 days of final installation of all 16 underground safety valves in Santa Barbara County.

On September 19, 2024, Sable entered into the Second PIPE Subscription Agreements with the Second PIPE Investors and, pursuant thereto, issued 7,500,000 shares of Common Stock at a price of $20.00 per share for an aggregate purchase price of $150,000,000 (the “Second PIPE Investments”). The Second PIPE Investments were consummated on September 23, 2024 (the “Second PIPE Closing”). Immediately following the Second PIPE Closing, the Company issued 7,500,000 shares of Common Stock to the Second PIPE Investors in accordance with the terms of the Second PIPE Subscription Agreements. The shares of Common Stock issued in the Second PIPE Investments were offered in a private placement under the Securities Act of 1933, as amended, pursuant to the Second PIPE Subscription Agreements.

On October 3, 2024, Sable Aviation, an entity controlled by our Chairman and Chief Executive Officer, and Sable entered into an Agreement of Purchase and Sale, pursuant to which Sable Aviation sold transportation assets and related equipment to Sable in exchange for 600,000 shares of Common Stock.

On October 3, 2024, Sable issued a press release announcing the redemption of all of its outstanding Public Warrants to purchase shares of Common Stock that were issued under the Warrant Agreement, as part of the units sold in the Company IPO. As of October 31, 2024 there have been 14,672,812 warrants exercised for $168.7 million in cash proceeds.

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Factors and Trends Impacting SYU’s Business and the Comparability of Future Financial Data of Sable Attributable to SYU to the Historical Financial Results of SYU’s Operations

Future financial data of Sable attributable to SYU may not be comparable to the historical results of operations of SYU for the periods presented due to the effects of the Business Combination and the following reasons:

Shut-in. Since May 2015, the assets have been shut in and the assets have not generated any substantial revenue. Since the shut-in the results of operations, including maintenance expenses, are not representative of what expenses will be if production is restarted as anticipated.

Crude Oil and Natural Gas Supply and Demand. Commodity price fluctuations due to inflation and other factors will directly impact our activities and results of operations over the long term after we restart production as anticipated. Generally, drilling and production activity may increase as crude oil and natural gas prices increase. The production volumes of our assets will depend on the market demand and our ability to deliver the resources to market. Commodity prices can be volatile and influenced by numerous variables beyond upstream operators’ control, including the domestic and global supply of and demand for crude oil, natural gas and NGL. Flow assurance is dependent upon adequate infrastructure to meet downstream market demands. The commodities markets as well as other supply and demand factors may also influence the selling prices of crude oil, natural gas and NGL.

Regulatory Compliance. The regulation of crude oil and natural gas production, processing and transportation by federal and state regulatory agencies has a material impact on our business. Our operations are also impacted by new regulations, which may increase the time that it takes to obtain required permits and restart production. Additionally, increased regulation of crude oil and natural gas producers in our immediate area of operation, and related water sourcing and water disposal requirements, could reduce the regional supply of crude oil and natural gas and, therefore, throughput on regional infrastructure assets.

Operation of Assets. We expect that operating expenses will increase significantly as production is restarted. Over time we project that maintenance and repairs costs will trend higher as the assets age and as the planned capital expenditure program advances. See “ —Liquidity and Capital Resources—Capital Requirements” for additional information on the planned capital expenditure program.

Public Company Expenses. Sable incurs direct, incremental G&A expense as a result of being a publicly traded company, including, but not limited to, costs associated with hiring new personnel, implementation of compensation programs that are competitive with Sable’s public company peer group, annual and quarterly reports to stockholders, tax return preparation, independent auditor fees, investor relations activities, registrar and transfer agent fees, incremental director and officer liability insurance costs, and independent director compensation. These direct, incremental G&A expenses are not included in SYU’s historical combined financial results of operations.

Components of Results of Operations

Revenue

The Company has not had any substantial revenues since the shut-in. The Company’s various operating expenses are the principal metrics used to assess its performance.

Operating Expenses

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Results of Operations

The comparability of our operating results for the three months ended June 30, 2024, the period February 14, 2024 through June 30, 2024 (Successor), the period January 1, 2024 through February 13, 2024 (Predecessor), and the three and six months ended June 30, 2023 (Predecessor) was impacted by the Business Combination. In the discussion of our results of operations for these periods, we may quantitatively disclose the impacts of the Business Combination to the extent they remain ascertainable. The entirety of our activity since inception through the Closing Date were related to our formation, the preparation for our initial public offering, and since the closing of our initial public offering, the search for a target for our initial business combination (Refer to Note 1 — Organization, Business Operations, and Going Concern of Sable’s condensed consolidated financial statements as of and for the period ended June 30, 2024). Following the Closing Date, all of our operations have focused on restarting production of the SYU Assets. We lack the ability to generate any operating revenues until we receive the necessary regulatory approvals and complete the repairs necessary to restart production. Our only source of non-operating income is generated in the form of interest income on cash and cash equivalents. Post the Business Combination, we expect to incur additional expenses as a result of being an operating public company, for legal, accounting and compliance expenses.

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Three Months Ended June 30, 2024 vs. Three Months Ended June 30, 2023

The following table presents selected consolidated financial results of operations for the Successor and Predecessor periods presented.

nm: not meaningful

Operating and maintenance expenses. Operating and maintenance expenses were $26.3 million for the three months ended June 30, 2024 (Successor), representing an increase of $12.2 million, or 86.3%, compared to $14.1 million for the three months ended June 30, 2023 (Predecessor). The increase in operating and maintenance expenses was primarily attributable to timing of maintenance expenses incurred in connection with restart efforts. Operations and maintenance expenses are expected to increase over the next several years as production is restarted.

Depletion, depreciation, amortization and accretion. Depletion, depreciation, amortization and accretion was $2.7 million for the three months ended June 30, 2024 (Successor), representing a decrease of $2.5 million, or 48.1%, compared to $5.3 million for the three months ended June 30, 2023 (Predecessor). The decrease in depletion, depreciation, amortization and accretion was primarily attributable to the Company not recognizing depreciation expense following the Business Combination, as the Company determined the assets were not in service since repairs are necessary prior to achieving production restart. The depletion, depreciation, amortization and accretion expense recognized for the three months ended June 30, 2024 (Successor) solely represents the recognition of ARO accretion for the period but depreciation will resume once the assets are placed in service. Depletion, depreciation, amortization and accretion expense is expected to increase over the next several years as production is restarted.

General and administrative expenses. General and administrative expenses (“G&A expenses”) were $33.2 million for the three months ended June 30, 2024 (Successor), representing an increase of $30.3 million compared to $2.9 million for the three months ended June 30, 2023 (Predecessor). The increase in G&A expenses was primarily attributable to the $21.0 million in share-based compensation expense and the recognition of salaries and wages following the Business Combination. Predecessor G&A expenses were allocated to SYU as a portion of certain other operating costs based on aggregated historical benchmarking data, as previously noted.

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Total other (income) expense, net. Total other expense, net was $98.1 million for the three months ended June 30, 2024 (Successor), representing an increase of $98.1 million compared to other income of less than $0.1 million for the three months ended June 30, 2023 (Predecessor). The increase in total other (income) expense, net was primarily attributable to an increase of $81.2 million in the fair value of the warrants and $19.2 million in interest expense, partially offset by interest income of $2.3 million. The increase during the Successor period is due to the fact that the Predecessor did not have any debt or associated interest expense, warrants, or interest income.

Income tax expense. Income tax expense for the three months ended June 30, 2024 (Successor) was $5.1 million, representing an increase of $5.1 million compared to $0.0 for the three months ended June 30, 2023 (Predecessor). Based on our ongoing assessment of our ability to recover our deferred tax assets, we concluded that it was more likely than not that our deferred tax assets in excess of deferred tax liabilities would not be realized. For the Successor period, we concluded that certain deferred tax liabilities in future periods do not have deferred tax assets available to offset, which is primarily due to our net operating losses being limited to 80% of taxable income. Therefore, a further valuation allowance of our deferred tax assets is necessary, which results in deferred tax expense for the Successor period. Our judgment regarding the likelihood of realization of these deferred tax assets could change in future periods, which could result in a material impact to our income tax provision in the period of change.

Comparison of the periods from January 1, 2024 through February 13, 2024 (Predecessor) and February 14, 2024 through June 30, 2024 (Successor) to the Six Months Ended June 30, 2023 (Predecessor).

The following table presents selected consolidated financial results of operations for the Successor and Predecessor periods presented.