Sempra Energy: 10-K Risk Factor Changes

Credit rating agencies routinely evaluate Sempra, SDG&E, SoCalGas, SI Partners and certain of our other businesses whose ratings are based on a number of factors, including the factors described below and the ability to generate cash flows; indebtedness levels; overall financial strength; specific transactions or events, such as share repurchases and significant litigation; the status of certain capital projects; and general economic and industry conditions. These credit ratings could be downgraded or subject to other negative rating actions at any time. We discuss these credit ratings in “Part II – Item 7. MD&A – Capital Resources and Liquidity.” For Sempra, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪expansion of natural gas liquefaction projects or other unregulated businesses in a manner inconsistent with its present level of credit quality ▪the PA LNG Phase 1 project experiences higher construction costs ▪Sempra’s consolidated financial measures consistently weaken, or it fails to meet certain financial credit metrics ▪catastrophic wildfires caused by SDG&E or by any California electric IOUs that participate in the Wildfire Fund, which could exhaust the fund considerably earlier than expected ▪a ratings downgrade at SDG&E, SoCalGas, Oncor and/or SI Partners For SDG&E, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪catastrophic wildfires caused by SDG&E or by any California electric IOUs that participate in the Wildfire Fund, which could exhaust the fund considerably earlier than expected ▪a consistent weakening of SDG&E’s financial metrics, or it fails to meet certain financial credit metrics ▪a deterioration in the regulatory environment, including credit negative outcomes of its pending regulatory proceedings ▪a ratings downgrade at Sempra For SoCalGas, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪SoCalGas’ financial measures consistently weaken, or it fails to meet certain financial credit metrics ▪SoCalGas experiences increased business risk due to a deterioration in the regulatory environment, including credit negative outcomes of its pending regulatory proceedings or elevated risk concerning its natural gas utility business ▪a ratings downgrade at Sempra For SI Partners, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪SI Partners’ failure to meet certain financial credit metrics ▪a deterioration in SI Partners’ business risk profile, including incremental construction risk or adverse changes in the operating environment in Mexico ▪the PA LNG Phase 1 project experiences challenges or delays in construction that have an adverse financial impact on SI Partners ▪a ratings downgrade at Sempra, IEnova and/or Cameron LNG, LLC A downgrade of any of our businesses’ credit ratings or ratings outlooks, as well as the reasons for such downgrades, could materially adversely affect the interest rates at which borrowings can be made and debt securities issued and the various fees on our credit facilities. This could make it more costly to borrow money, issue securities and/or raise other types of capital, any of which could reduce our ability to meet our debt obligations and contractual commitments and otherwise materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Credit rating agencies routinely evaluate Sempra, SDG&E, SoCalGas and SI Partners and certain of our other businesses, and their ratings are based on a number of factors, including the factors described below and the ability to generate cash flows; level of indebtedness; overall financial strength; specific transactions or events, such as share repurchases and significant litigation; the status of certain capital projects; and the state of the economy and our industry generally. These credit ratings could be downgraded or other negative credit rating actions could occur at any time. We discuss these credit ratings in “Part II – Item 7. MD&A – Capital Resources and Liquidity.” For Sempra, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪expansion of natural gas liquefaction projects or other unregulated businesses in a manner inconsistent with its present level of credit quality ▪Sempra’s consolidated financial measures do not improve, or it fails to meet certain financial credit metrics ▪catastrophic wildfires caused by SDG&E or by any California electric IOUs that participate in the Wildfire Fund, which could exhaust the fund considerably earlier than expected For SDG&E, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪catastrophic wildfires caused by SDG&E or by any California electric IOUs that participate in the Wildfire Fund, which could exhaust the fund considerably earlier than expected ▪a consistent weakening of SDG&E’s financial metrics or a deterioration in the regulatory environment ▪a ratings downgrade at Sempra For SoCalGas, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪SoCalGas’ financial measures consistently weaken, or it fails to meet certain financial credit metrics ▪SoCalGas experiences increased business risk, including a deterioration in the regulatory environment, leading to weakening of its stand-alone business risk profile ▪a ratings downgrade at Sempra For SI Partners, the Rating Agencies have noted that the following events, among others, could lead to negative ratings actions: ▪SI Partners’ failure to meet certain financial credit metrics ▪a deterioration in SI Partners’ business risk profile, including incremental construction risk or adverse changes in the operating environment in Mexico ▪a ratings downgrade at Sempra, IEnova and/or Cameron LNG, LLC A downgrade of any of our businesses’ credit ratings or ratings outlooks, as well as the reasons for such downgrades, may materially adversely affect the market prices of our securities, the interest rates at which borrowings can be made and debt securities issued, and the various fees on our credit facilities. This could make it more costly for the affected businesses to borrow money, issue securities and/or raise other types of capital, any of which could materially adversely affect our ability to meet our debt obligations and contractual commitments, and our results of operations, financial condition, cash flows and/or prospects.

Our operations in Mexico pose foreign currency exchange rate and inflation risks. Exchange and inflation rates with respect to Mexico and fluctuations in those rates may have an impact on the revenue, cash flows and costs from our international operations, which could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. We may attempt to hedge cross-currency transactions and earnings exposure through various means, including financial instruments and short-term investments, but these hedges may not fully achieve our objectives of mitigating earnings volatility that would otherwise occur due to exchange rate fluctuations. Because we do not hedge our net investments in foreign countries, we are susceptible to volatility in OCI caused by exchange rate fluctuations for entities whose functional currencies are not the U.S. dollar. Moreover, Mexico has experienced periods of high inflation and exchange rate instability in the past, and severe devaluation of the Mexican peso could result in governmental intervention to institute restrictive exchange control policies, as has occurred before in Mexico and other Latin American countries. We discuss our foreign currency exposure at our Mexican subsidiaries in “Part II – Item 7. MD&A” and “Part II – Item 7A. Quantitative and Qualitative Disclosures About Market Risk.”

Our operations in Mexico pose foreign currency and inflation risks. Exchange and inflation rates with respect to the Mexican peso and fluctuations in those rates may have an impact on the revenue, costs and cash flows from our international operations, which could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. We may attempt to hedge cross-currency transactions and earnings exposure through various means, including financial instruments and short-term investments, but these hedges may not fully achieve our objectives of mitigating earnings volatility that would otherwise occur due to exchange rate fluctuations. Because we do not hedge our net investments in foreign countries, we are susceptible to volatility in OCI caused by exchange rate fluctuations for entities whose functional currencies are not the U.S. dollar. Moreover, Mexico has experienced periods of high inflation and exchange rate instability in the past, and severe devaluation of the Mexican peso could result in governmental intervention to institute restrictive exchange control policies, as has occurred before in Mexico and other Latin American countries. We discuss our foreign currency exposure at our Mexican subsidiaries in “Part II – Item 7. MD&A” and “Part II – Item 7A. Quantitative and Qualitative Disclosures About Market Risk.”

At February 21, 2023, we had 314,569,519 shares of our common stock and 900,000 shares of our non-convertible series C preferred stock outstanding. We may seek to raise capital by issuing additional equity or convertible debt securities, which may materially dilute the voting rights and economic interests of holders of our outstanding common and preferred stock and materially adversely affect the trading price of our common and preferred stock.

We depend on electric transmission lines, natural gas pipelines and other transportation facilities and services owned and operated by third parties to, among other things: ▪deliver the natural gas, LNG, electricity and LPG we sell to customers or use for our LNG export facilities ▪supply natural gas to our gas storage and electric generation facilities ▪provide retail energy services to customers If transportation is disrupted, the construction of necessary interconnecting infrastructure is not completed on schedule or at all or capacity is inadequate, we may be delayed in completing projects under development and/or unable to meet our contractual obligations to customers of those projects or existing projects, in which case we may be responsible for damages they incur, such as the cost of acquiring alternative supplies at then-current spot market rates, and we could lose customers that may be difficult to replace. Any such occurrence could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

We depend on electric transmission lines, natural gas pipelines and other transportation facilities and services owned and operated by third parties to, among other things: ▪deliver the natural gas, LNG, electricity and LPG we sell to customers or use for our LNG export facilities ▪supply natural gas to our gas storage and electric generation facilities ▪provide retail energy services to customers If transportation is disrupted, if the construction of new or modified interconnecting infrastructure is not completed on schedule or if capacity is inadequate, we may not be able to move forward with our projects on schedule, we may be unable to sell and deliver our commodities, electricity and other services to our customers, we may be responsible for damages incurred by these customers, such as the cost of acquiring alternative supplies at then-current spot market rates, and we could lose customers that may be difficult to replace in competitive market conditions. Any such occurrence could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Our businesses are capital-intensive, with significant and increasing capital spending expected in future periods. In general, we rely on long-term debt to fund a significant portion of our capital expenditures and repay outstanding debt, and we rely on short-term debt to fund a significant portion of day-to-day operations. Sempra has also raised and may continue to seek capital by issuing equity or selling equity interests in our subsidiaries or investments. Limitations on the availability of credit, increases in interest rates or credit spreads due to inflation or otherwise or other negative effects on the terms of any financing we pursue could cause us to fund operations and capital expenditures at a higher cost or fail to raise our targeted amount of funds, which could negatively impact our ability to meet contractual and other commitments, progress development projects, make non-safety related capital expenditures and effectively sustain operations. Any of these outcomes could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. In addition to market and economic conditions, factors that can affect the availability and cost of capital include: ▪adverse changes to laws and regulations, including recent and proposed changes to energy market regulation in Mexico ▪for Sempra and SDG&E, risks related to California wildfires ▪for Sempra, SDG&E and SoCalGas, any deterioration of or uncertainty in the political or regulatory environment for local natural gas distribution companies operating in California ▪credit ratings downgrades

Our businesses are capital-intensive, with significant capital spending expected in future periods. In general, we rely on long-term debt to fund a significant portion of our capital expenditures and repay outstanding debt and we rely on short-term borrowings to fund a significant portion of day-to-day business operations. Sempra may also seek to raise capital by issuing equity or selling equity interests in our subsidiaries or investments. Limitations on the availability of credit, increases in interest rates or credit spreads due to inflationary pressures or otherwise or other negative effects on the terms of any financing we pursue could cause us to fund operations and capital expenditures at a higher cost or fail to raise our targeted amount of funding, which could negatively impact our ability to meet contractual and other commitments, progress development projects, make non-safety related capital expenditures and effectively sustain operations. Any of these outcomes could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. In addition to market and economic conditions, factors that can affect the availability and cost of capital include: ▪adverse changes to laws and regulations, including recent and proposed changes to the regulation of the energy market in Mexico ▪the overall health of the energy industry ▪volatility in electricity or natural gas prices ▪for Sempra, SDG&E and SoCalGas, risks related to California wildfires ▪for Sempra, SDG&E and SoCalGas, any deterioration of or uncertainty in the political or regulatory environment for local natural gas distribution companies operating in California ▪credit ratings downgrades

The NEM program is an electric billing tariff mechanism designed to promote the installation of on-site renewable generation (primarily solar installations) for residential and business customers. Depending on when the on-site generation is installed, NEM customers receive a full retail rate or a reduced retail rate for energy they generate but do not use that is fed to the utility’s power grid, which results in these customers not paying their proportionate share of the cost of maintaining and operating the electric transmission and distribution system, subject to certain exceptions, but still receiving electricity from the system when their self-generation is inadequate to meet their electricity needs. As more and higher electric-use customers switch to NEM and self-generate energy, the burden on remaining non-NEM customers, who effectively subsidize the unpaid NEM costs, increases, which in turn encourages more self-generation and further increases rate pressure on remaining non-NEM customers. The current electric residential rate structure in California is primarily based on consumption volume, which places a higher rate burden on customers with higher electric use while subsidizing lower-use customers. In December 2023, a new Net Billing Tariff was implemented for customers who interconnect their qualifying on-site renewable generation after April 2023. The new Net Billing Tariff revised the NEM structure for new customers with a retail export compensation rate that is better aligned with the value provided to the grid by behind-the-meter energy generation systems and retail import rates that encourage electrification and adoption of solar systems paired with storage. The new Net Billing Tariff is designed to compensate customers for the value of their exports to the grid based on avoided cost. Additionally, in response to California legislation adopted in 2022, the CPUC has initiated a rulemaking to broadly restructure the way fixed costs are collected, moving away from volumetric only charges and incorporating an income-graduated fixed charge for default residential rates. The intent of such a fixed charge is to establish a rate structure that allows the utility to collect a greater portion of its fixed costs on a non-volumetric basis, achieve the state’s climate goals through end-use electrification and provide a more affordable rate design on average for lower-income customers. We expect a CPUC decision adopting the fixed charge by July 2024 with implementation occurring as early as the second half of 2025. Depending on the effectiveness of the new Net Billing Tariff and fixed charge, which are uncertain, the risks associated with the existing NEM tariff and rate design could continue or increase. SDG&E believes the establishment of a charge independent of consumption volume for residential customers is critical to help distribute rates among all customers that rely on the electric transmission and distribution system, including those participating in the NEM program. The absence of a charge independent of consumption volume coupled with the continuing increase of solar installation and other forms of self-generation and DER, as well as energy efficiency initiatives that could also reduce delivered volumes, could adversely impact electricity rates and the reliability of the electric transmission and distribution system. Any such impact could subject SDG&E to increased customer dissatisfaction, increased likelihood of noncompliance with CPUC or other safety or operational standards and increased risks attendant to any such noncompliance, as we discuss above, as well as increased costs, including power procurement, operating and capital costs, and potential disallowance of recovery for these costs. If the CPUC does not adequately reform SDG&E’s residential rate structure to better achieve reasonable, cost-based electric rates that are competitive with alternative sources of power and adequate to maintain the reliability of the electric transmission and

The NEM program is an electric billing tariff mechanism designed to promote the installation of on-site renewable generation (primarily solar installations) for residential and business customers. Depending on when the on-site generation was installed, NEM customers receive a full retail rate or a reduced retail rate for energy they generate but do not use that is fed to the utility’s power grid, which results in these customers not paying their proportionate share of the cost of maintaining and operating the electric transmission and distribution system, subject to certain exceptions, but still receiving electricity from the system when their self-generation is inadequate to meet their electricity needs. As more and higher electric-use customers switch to NEM and self-generate energy, the burden on remaining non-NEM customers, who effectively subsidize the unpaid NEM costs, increases, which in turn encourages more self-generation and further increases rate pressure on remaining non-NEM customers. The current electric residential rate structure in California is primarily based on consumption volume, which places a higher rate burden on customers with higher electric use while subsidizing lower-use customers. In August 2020, the CPUC initiated a rulemaking to further develop a successor to the existing NEM tariff. In November 2022, a previous proposed decision was withdrawn and a new proposed decision was issued, recommending substantial reform of the NEM program through the establishment of a new Net Billing Tariff that would apply to new net metered customers. The new Net Billing Tariff revises the current NEM structure for new customers with a retail export compensation rate that is better aligned with the value provided to the grid by behind-the-meter energy generation systems and retail import rates that encourage electrification and adoption of solar systems paired with storage. The new Net Billing Tariff is designed to compensate customers for the value of their exports to the grid based on avoided cost. In December 2022, the CPUC approved the new Net Billing Tariff for customers who interconnect their qualifying on-site renewable generation after April 14, 2023. Additionally, in response to California legislation adopted in 2022, the CPUC has initiated a rulemaking to broadly restructure the way fixed costs are collected, moving from volumetric charges to an income-graduated fixed charge for default residential rates by July 1, 2024. The intent of such a fixed charge would be to further help reduce cost shifts through an equitable approach to the distribution of electric costs. Depending on the effectiveness of the new Net Billing Tariff and any new rules related to fixed charges, which are uncertain, the risks associated with the existing NEM tariff could continue or increase. SDG&E believes the establishment of a charge independent of consumption volume for residential customers is critical to help distribute rates among all customers that rely on the electric transmission and distribution system, including those participating in the NEM program. The absence of a charge independent of consumption volume coupled with the continuing increase of solar installation and other forms of self-generation, as well as the progression of DER and energy efficiency initiatives that could also reduce delivered volumes, could adversely impact electricity rates and the reliability of the electric transmission and distribution system. Any such impact could subject SDG&E to increased customer dissatisfaction, increased likelihood of noncompliance with CPUC or other safety or operational standards and increased risks attendant to any such noncompliance, as we discuss above, as well as increased costs, including power procurement, operating and capital costs, and potential disallowance of recovery for these costs. If the CPUC does not continue to adequately reform SDG&E’s residential rate structure for all customers to better achieve reasonable, cost-based electric rates that are competitive with alternative sources of power and adequate to maintain the reliability of the electric transmission and distribution system, such failure could have a material adverse effect on SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects.

We have been and may in the future be subject to activist shareholder attention. Activist shareholders may engage in proxy solicitations, advance shareholder proposals or otherwise attempt to effect changes in or assert influence on our board of directors and management. In taking these steps, activist shareholders could seek to acquire our capital stock, which at certain ownership levels could threaten our ability to use some or all our NOL or tax credit carryforwards if our corporation experiences an “ownership change” under applicable tax rules. Responding to activist shareholders can be costly and time-consuming and requires time and attention by our board of directors and management, diverting their attention from our business strategies.

Activist shareholders may engage in proxy solicitations, advance shareholder proposals or otherwise attempt to effect changes in or assert influence on our board of directors and management. In taking these steps, activist shareholders could seek to acquire our capital stock, which at certain ownership levels could threaten our ability to use some or all our NOL carryforwards if our corporation experiences an “ownership change” under applicable tax rules. Responding to activist shareholders could require us to

We could experience a reduction in the fair value of our assets, including our investments that we account for under the equity method, upon the occurrence of many of the risks discussed in these risk factors and elsewhere in this report, such as from any inability to operate our existing facilities or develop new projects in Mexico due to recent and proposed changes to laws or regulations or other circumstances affecting the energy sector or our assets in that country, and more generally any loss of permits or approvals that requires us to adjust or cease certain operations and any failure to complete or receive an adequate return on our investments in capital projects. Any such reduction in the fair value of our assets or investments could result in an impairment loss that could materially adversely affect our results of operations for the period in which the charge is recorded. We discuss our impairment testing of long-lived assets and goodwill and the factors considered in such testing in “Part II – Item 7. MD&A – Critical Accounting Estimates” and in Note 1 of the Notes to Consolidated Financial Statements.

We could experience a reduction in the fair value of our assets, including our long-lived assets, intangible assets or goodwill, and/or our investments that we account for under the equity method upon the occurrence of many of the risks discussed in these risk factors and elsewhere in this report, including any closure of the Aliso Canyon natural gas storage facility without adequate cost recovery, any inability to operate our existing facilities or develop new projects in Mexico due to proposed changes to existing laws or regulations or other circumstances affecting the energy sector or our assets in that country, and more generally any loss of permits or approvals that requires us to adjust or cease certain operations and any investment in capital projects that do not receive required approvals or are changed, abandoned or otherwise not completed. Any such reduction in the fair value of our assets or investments could result in an impairment loss that could materially adversely affect our results of operations for the period in which the charge is recorded. We discuss our impairment testing of long-lived assets and goodwill and the factors considered in such testing in “Part II – Item 7. MD&A – Critical Accounting Estimates” and in Note 1 of the Notes to Consolidated Financial Statements.

We have significant debt service obligations, which could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects by, among other things: ▪making it more difficult and costly to service, pay or refinance debts as they come due, particularly when interest rates increase or economic or industry conditions are otherwise unfavorable ▪limiting flexibility to pursue strategic opportunities or react to business developments or industry changes ▪causing lenders to require materially adverse terms for new debt, such as restrictions on uses of proceeds, limitations on incurring additional debt, paying dividends, repurchasing stock, or receiving distributions from subsidiaries or equity method investments and the creation of liens Sempra’s goal is to maintain or improve its credit ratings, but it may not be able to do so. To maintain these credit ratings, we may seek to reduce our outstanding indebtedness or our need for additional indebtedness by issuing equity securities or selling equity interests in our subsidiaries or development projects. We may not be able to complete any such equity sales on terms we consider acceptable or at all, and any new equity issued by Sempra may dilute the voting rights and economic interests of Sempra’s existing equity holders. Any such outcome could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Our businesses have debt service obligations, which could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects by, among other things: ▪making it more difficult and costly for each of these businesses to service, pay or refinance their debts as they come due, particularly during adverse economic or industry conditions or in periods of significant increases in interest rates ▪limiting flexibility to pursue strategic opportunities or react to business developments or changes in the industry sectors in which they operate ▪requiring cash to be used for debt service payments, thereby reducing the cash available for other purposes ▪causing lenders to require materially adverse terms in the instruments for new debt, such as restrictions on uses of proceeds or other assets or limitations on incurring additional debt, creating liens, paying dividends, repurchasing stock, making investments or receiving distributions from subsidiaries or equity method investments Sempra’s goal is to maintain or improve its credit ratings, but it may not be able to do so. To maintain these credit ratings, we may seek to reduce our outstanding indebtedness or our need for additional indebtedness with the proceeds from issuances of equity securities by Sempra or the sale of equity interests in our subsidiaries or development projects. We may not be able to complete any such equity sales on terms we consider acceptable or at all, and any new equity issued by Sempra may dilute the voting rights and economic interests of existing holders of Sempra’s common and preferred stock. Any such outcome could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

We buy energy-related commodities from time to time for pipeline operations, LNG facilities or power plants to satisfy contractual obligations with customers. The regional and other markets in which we purchase these commodities are competitive and can be subject to significant pricing volatility as a result of many factors, including inflation, adverse weather conditions, supply and demand changes, availability of competitively priced alternative energy sources, commodity production levels and storage capacity, energy and environmental legislation and regulations, and economic and financial market conditions. Our results of operations, financial condition, cash flows and/or prospects could be materially adversely affected if the prevailing market prices for natural gas, LNG, electricity or other commodities we buy change in a direction or manner not anticipated and for which we have not provided adequately through purchase or sale commitments or other hedging transactions.

We buy energy-related commodities from time to time for pipeline operations, LNG facilities or power plants to satisfy contractual obligations with customers. The regional and other markets in which we purchase these commodities are competitive and can be subject to significant pricing volatility as a result of many factors, including adverse weather conditions, supply and demand changes, availability of competitively priced alternative energy sources, commodity production levels and storage capacity, energy and environmental legislation and regulations, and economic and financial market conditions. Our results of operations, financial condition, cash flows and/or prospects could be materially adversely affected if the prevailing market prices for natural gas, LNG, electricity or other commodities we buy change in a direction or manner not anticipated and for which we have not provided adequately through purchase or sale commitments or other hedging transactions.

Table of Contents Table of Contents LNG Export Projects In addition to the risks described above that are applicable to all our energy infrastructure projects, we are exposed to additional risks in connection with our LNG export projects, including the ECA LNG Phase 1 project and PA LNG Phase 1 project under construction and our potential development of additional LNG export facilities. We discuss our LNG export projects in “Part II – Item 7. MD&A – Capital Resources and Liquidity – Sempra Infrastructure.” Each of these projects faces numerous risks. Our ability to reach a final investment decision for each project and, if a positive decision is made and a project is completed, the overall success of the project depend in part on global energy markets. In general, depressed natural gas and LNG prices in the markets we intend to serve could reduce the pricing and cost advantages of exporting domestically produced natural gas and LNG, which could lead to decreased demand. In addition, global oil prices and their associated current and forward projections could reduce demand for natural gas and LNG in some sectors. Although demand for natural gas is currently strong due to increased recognition of the importance of energy security and climate aims, a reduction in natural gas demand could also occur from higher penetration of alternative fuels in new power generation, reduced economic activity in general, or as a result of calls by some to limit or eliminate global reliance on natural gas. Both the U.S. and Mexico will hold federal elections in 2024 and LNG exports face increased political scrutiny in connection with these elections. Moreover, because LNG projects take a number of years to develop and construct, it is difficult to match current and expected demand with the projected supply from projects under development. Additionally, shifts in U.S. and foreign energy policy could impact supply, demand and other matters critical to LNG projects, such as permitting and other approval processes. The current Administration has temporarily paused LNG export approvals while the DOE reviews the economic and environmental analyses it uses to evaluate LNG export applications to non-FTA countries, and the DOE has recently implemented changes to its approach to requests for extensions of time to commence LNG exports under existing non-FTA approvals. These actions, as well as other market factors such as oil prices, could delay or hamper the development of U.S. LNG export facilities and make LNG projects in other parts of the world more feasible and competitive with LNG projects in North America, thus increasing supply and competition for global LNG demand. Any of these occurrences could impact competition and prospects for developing LNG export projects and negatively affect the performance and prospects of any of our projects that are or become operational. Our projects may face distinct disadvantages relative to some LNG projects being pursued by other project developers, including: ▪The proposed Cameron LNG Phase 2 project is subject to certain restrictions and conditions under the financing agreements for the Cameron LNG Phase 1 facility and requires unanimous consent of all JV members, including with respect to the equity investment obligations of each partner. We may not be able to satisfy the conditions under the financing agreements, receive members’ consent or obtain the extension of our non-FTA approval, in which case our ability to develop the Cameron LNG Phase 2 project would be jeopardized. ▪The ECA LNG projects under construction and in development are subject to ongoing land and permit disputes that could obstruct efforts to find or maintain suitable partners, customers and financing arrangements and hinder or halt construction and, if the projects are completed, operations. We discuss these risks below and under “Risks Related to Sempra Infrastructure – Legal and Regulatory Risks.” In addition, the Mexican regulatory process and overlay of U.S. regulation for natural gas exports to LNG facilities in Mexico are not well developed, which, among other factors, contributed to delays in obtaining a necessary permit from the Mexican government for the ECA LNG Phase 1 project and could cause similar delays or other hurdles in the future and lead to difficulties finding or maintaining suitable partners, customers and financing arrangements. Further, while we do not expect the construction or operation of the ECA LNG Phase 1 project to disrupt operations at the ECA Regas Facility, we expect construction of the proposed ECA LNG Phase 2 project would conflict with the current operations at the ECA Regas Facility, which currently has long-term regasification contracts for 100% of the regasification facility’s capacity through 2028. This makes the decisions on whether, when and how to pursue the proposed ECA LNG Phase 2 project dependent in part on whether the investment in this project would, over the long term, be more beneficial financially than continuing to supply regasification services under our existing contracts. In addition, the Baja California region does not have extensive sources of natural gas, and our development opportunities in Mexico, including the proposed ECA LNG Phase 2 project, would require significant upgrades in natural gas transportation infrastructure that would be costly and time-consuming. ▪The PA LNG Phase 1 project under construction and the PA LNG Phase 2 project in development are located at a greenfield site and therefore are subject to disadvantages relative to projects being constructed or developed at brownfield sites, including increased time and costs to develop and construct the projects. Additionally, in February 2020, Sempra Infrastructure filed an application with the DOE to permit LNG produced from the proposed PA LNG Phase 2 project to be exported to all current and future FTA and non-FTA countries. We do not expect the DOE to act on this application until after the conclusion of the temporary pause on the DOE’s LNG export approvals. Development of these or any other LNG export projects will depend on the expansion of our existing pipeline interconnections or the ability to permit and construct new pipeline facilities, each of which may require us to enter into additional pipeline interconnection agreements with third-party pipelines, which may not be possible on commercially reasonable terms or at all.

Table of Contents Table of Contents LNG Export Projects In addition to the risks described above that are applicable to all our energy infrastructure projects, we are exposed to additional risks in connection with our LNG export projects, including the ECA LNG Phase 1 project under construction and our potential development of additional LNG export facilities. We discuss our LNG export projects in “Part II – Item 7. MD&A – Capital Resources and Liquidity – Sempra Infrastructure.” Each of these projects faces numerous risks. Our ability to reach a final investment decision for each project and, if a positive decision is made and a project is completed, the overall success of the project are dependent on global energy markets, including natural gas and oil supply, demand and pricing, the ability to reach advantageous agreements with our counterparties, including our partners, off-takers, and EPC contractors, risks inherent in construction, and the ability to obtain and maintain government approvals, among other things. In general, depressed natural gas and LNG prices in the markets we intend to serve due to shifts in supply or other factors could reduce the pricing and cost advantages of exporting domestically produced natural gas and LNG, which could lead to decreased demand. In addition, global oil prices and their associated current and forward projections could reduce demand for natural gas and LNG in some sectors. Although demand for natural gas is currently strong due to the geopolitical consequences of the war in Ukraine and increased recognition of the importance of energy security, a reduction in natural gas demand could also occur from higher penetration of alternative fuels in new power generation, or as a result of calls by some to limit or eliminate reliance on natural gas as an energy source globally. Oil prices could also make LNG projects in other parts of the world more feasible and competitive with LNG projects in North America, thus increasing supply and competition for any available LNG demand. Moreover, because LNG projects take a number of years to develop and construct, it is difficult to match current and expected demand with the projected supply from projects under development. Any of these occurrences could impact competition and prospects for developing LNG export projects and negatively affect the performance and prospects of any of our projects that are or become operational. Our projects may face distinct disadvantages relative to some LNG projects being pursued by other project developers, including: ▪The proposed Cameron LNG Phase 2 project is subject to certain restrictions and conditions under the financing agreements for the Cameron LNG Phase 1 facility and requires unanimous consent of all JV members, including with respect to the equity investment obligations of each partner. We may not be able to satisfy these conditions and requirements, in which case our ability to develop the Cameron LNG Phase 2 project would be jeopardized. ▪The ECA LNG projects under construction and in development are subject to ongoing land and permit disputes that could obstruct efforts to find or maintain suitable partners, customers and financing arrangements and hinder or halt construction and, if the projects are completed, operations. We discuss these risks below and under “Risks Related to Sempra Infrastructure – Legal Risks.” In addition, the Mexican regulatory process and overlay of U.S. regulation for natural gas exports to LNG facilities in Mexico are not well developed, which, among other factors, contributed to delays obtaining a necessary permit from the Mexican government for the ECA LNG Phase 1 project and could cause similar delays or other hurdles in the future and lead to difficulties finding or maintaining suitable partners, customers and financing arrangements. We have entered into contracts with affiliates and third parties, subject to certain conditions, to supply and transport gas across the U.S.-Mexico border to meet the requirements of the ECA LNG Phase 1 project if and when it becomes operational. If affiliates or third parties experience delays or fail to obtain and maintain necessary permits and arrangements to provide such supply or transportation services or if we fail to maintain adequate gas supply and transportation agreements to support the project fully, it could cause additional costs or delays to the ECA LNG Phase 1 project. Finally, although we have planned measures to not disrupt operations at the ECA Regas Facility with the construction or operation of the ECA LNG Phase 1 project, these measures may not be effective. Moreover, we expect construction of the proposed ECA LNG Phase 2 project to conflict with ECA Regas Facility operations, making the decisions on whether, when and how to pursue the ECA LNG Phase 2 project dependent in part on whether the investment in this project would, over the long term, be more beneficial than continuing to provide regasification services under existing contracts for 100% of the ECA Regas Facility’s capacity through 2028. ▪The PA LNG projects in development are to be located at a greenfield site and therefore are subject to disadvantages relative to projects being developed at brownfield sites, including increased time and costs to develop and construct the project. Development of these or any other LNG export projects will depend on the ability of our existing pipeline interconnections to be expanded or the ability to permit and construct new pipeline facilities, each of which may require us to enter into additional pipeline interconnection agreements with third-party pipelines. We and third parties may not be able to successfully develop and construct such new pipeline facilities, or we may not be able to secure such additional pipeline interconnections on commercially reasonable terms or at all. The capital requirements for LNG export projects that we decide to pursue can be significant, even if we ultimately decide not to make a positive final investment decision. In addition, our proposed facilities may not be completed in accordance with estimated timelines or budgets or at all as a result of the above or other factors, and delays, cost overruns or our inability to complete one or more of these projects could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

The ECA Regas Facility has long-term capacity agreements with a limited number of counterparties, and also may enter into short-term and/or long-term supply agreements to purchase LNG to be received, stored and regasified for sale to other parties. In addition, Cameron LNG JV has long-term liquefaction and regasification tolling agreements with three counterparties that collectively subscribe for the full nameplate capacity of the Cameron LNG Phase 1 facility, and long-term sale and purchase agreements are in place for the expected capacity at the ECA LNG Phase 1 and PA LNG Phase 1 projects under construction. The long-term nature of these agreements and the small number of customers at each of these facilities exposes us to risks, including increased risk if these counterparties fail to meet their contractual obligations on a timely basis, increased credit risks, and risks associated with our relationships with these counterparties, including increased impacts of disputes or other similar issues which we have experienced in the past. Any such issues that arise in the future with respect to our long-term contracts could lead to significant legal and other costs, result in cancelation of certain key contracts or otherwise adversely affect our relationships with long-term customers, suppliers or partners, and could negatively impact the reliability of revenues from the applicable projects and the prospects for any implicated development projects. Any such event could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Sempra Infrastructure’s ability to enter into new or replace existing long-term capacity agreements for its natural gas pipeline operations depends on, among other factors, demand for and supply of LNG and/or natural gas from its transportation customers, which may include our LNG export facilities. A decrease in demand for or supply of LNG or natural gas from such customers or the occurrence of other events that hinder Sempra Infrastructure from maintaining such agreements or establishing new ones could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. The electric generation and wholesale power sales industries are highly competitive. As more plants are built, supplies of energy and related products may exceed demand, competitive pressures may increase and wholesale electricity prices may decline or become more volatile. Without long-term power sales agreements, our revenues may be subject to increased volatility, and we may be unable to sell the power that Sempra Infrastructure’s facilities are capable of producing at favorable prices or at all, any of which could materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

The ECA Regas Facility has long-term capacity agreements with a limited number of counterparties, and also may enter into short-term and/or long-term supply agreements to purchase LNG to be received, stored and regasified for sale to other parties. In addition, Cameron LNG JV has long-term liquefaction and regasification tolling agreements with three counterparties that collectively subscribe for the full nameplate capacity of the Cameron LNG Phase 1 facility. The long-term nature of these agreements and the small number of customers at each of these facilities exposes us to risks, including increased risk if these counterparties fail to meet their contractual obligations on a timely basis, increased credit risks, and risks associated with the long-term nature of our relationships with these counterparties, including increased impacts of disputes or other similar issues which we have experienced in the past. Any such issues that arise in the future with respect to our long-term contracts, including any that may be caused by or related to the war in Ukraine, could lead to significant legal and other costs, result in cancelation of certain key contracts or otherwise adversely affect our relationships with long-term customers, suppliers or partners, and could negatively

Our facilities and the systems that interconnect and/or manage them are subject to risks of, among other things, equipment or process failures due to aging infrastructure or otherwise; human error; shortages of or delays in obtaining equipment, materials, commodities or labor, which have been and may in the future be exacerbated by supply chain constraints or tight labor market conditions, as well as increases to the costs of these items due to inflationary pressures or otherwise, which may not be recoverable in a timely manner or at all; operational restrictions resulting from environmental requirements or governmental interventions; inability to enter into, maintain, extend or replace long-term supply or transportation contracts; and performance below expected levels. Although our businesses undertake capital investment projects to construct, replace, operate, maintain and upgrade facilities and systems, such projects may not be completed or effective at managing these risks and involve significant costs that may not be recoverable. We often rely on third parties, including contractors, to perform work related to these projects and other maintenance activities, which may subject us to liability for safety issues and the quality of work performed by these third parties. Because some of our facilities are interconnected with those of third parties, including third-party natural gas pipelines and power generation facilities that produce most of the power we distribute, the operation of our facilities could also be materially adversely affected by these or similar risks to such third-party systems, which may be unanticipated or uncontrollable by us. Additional risks associated with our ability to safely and reliably construct, replace, operate, maintain and upgrade facilities and systems, which may be beyond our control, include: ▪failure to meet customer demand for electricity and/or natural gas, including electrical blackouts or curtailments or gas outages ▪natural gas surges into homes or other properties ▪the release of hazardous or toxic substances, including gas leaks ▪the failure to respond effectively to catastrophic events The occurrence of any of these events could affect supply and demand for electricity, natural gas or other forms of energy, cause unplanned outages, damage our assets and/or operations or those of third parties on which our businesses rely, damage property owned by customers or others, and cause personal injury or death. In addition, if we are unable to defend and retain title to the properties we own or obtain or retain rights to construct and operate on the properties we do not own in a timely manner, on

Our businesses’ facilities and the information systems that interconnect and/or manage them are subject to risks of, among other things, potential breakdown or failure of equipment or processes due to aging infrastructure and systems; human error; shortages of or delays in obtaining equipment, materials, commodities or labor, which may be exacerbated by current or future supply chain constraints and tight labor market conditions, and increases to the costs of these items due to inflationary pressures or otherwise, which may not be recoverable in a timely manner or at all; operational restrictions resulting from environmental requirements or governmental interventions; inability to enter into, maintain, extend or replace long-term supply or transportation contracts; and performance below expected levels. Even though our businesses undertake capital investment projects to construct, replace, maintain, improve and upgrade facilities and systems, such projects may not be effective at managing the aforementioned risks, and may involve significant costs that may not be recoverable and challenges in achieving completion. We often rely on third parties, including contractors, to perform work related to these projects and other maintenance activities, which may subject us to increased risks because we manage the safety and quality of work performed by third parties and may retain liability for their work. Because our facilities are interconnected with those of third parties, including receiving natural gas supply from third party pipelines and power generation facilities that produce most of the power that we distribute to customers, the operation of our facilities could also be adversely affected by these or similar risks to the systems of such third parties, many of which may be unanticipated or uncontrollable by us. Additional risks associated with our businesses’ ability to safely and reliably construct, replace, operate, maintain, improve and upgrade their respective facilities and systems, many of which are beyond our control, include: ▪failure to meet customer demand for electricity and/or natural gas, including electrical blackouts or curtailments or gas outages ▪natural gas surges into homes or other properties ▪the release of hazardous or toxic substances, including gas leaks ▪inadequate emergency preparedness plans and the failure to respond effectively to catastrophic events The occurrence of any of these events could affect supply and demand for electricity, natural gas or other forms of energy, cause unplanned outages, damage our businesses’ assets and/or operations, damage the assets and/or operations of third parties on which our businesses rely, damage property owned by customers or others, and cause personal injury or death. In addition, if we are unable to defend and retain title to the properties we own or if we are unable to obtain or retain rights to construct and operate on the properties we do not own in a timely manner, on reasonable terms or at all, we could lose our rights to occupy and use these properties and the related facilities, which could result in modification, delay or curtailment of existing or proposed operations or projects, increase our costs, and result in breaches of one or more permits or contracts related to the affected facilities that could lead to legal costs, impairments or fines or penalties. Any such outcome could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Our facilities and infrastructure may be damaged by severe weather, natural disasters, wildfires, accidents, explosions or acts of terrorism, war, or criminality. Because we are in the business of using, storing, transporting and disposing of highly flammable, explosive and radioactive materials and operating highly energized equipment, the risks such incidents pose to our facilities and infrastructure, as well as to the surrounding communities for which we could be liable, are substantially greater than the potential risks to a typical business. Such incidents could result in operational disruptions, power or gas outages, property damage, personal injury or death and could cause secondary incidents that also may have these or other negative effects, such as fires; leaks of natural gas, natural gas odorant, propane, ethane, other GHG emissions or radioactive material; spills or other damage to natural resources; or other nuisances to affected communities. Any of these occurrences could decrease revenues and earnings and/or increase costs, including maintenance costs or restoration expenses, amounts associated with claims against us, and regulatory fines, penalties and disallowances. In some cases, we may be liable for damages even though we are not at fault, such as when the doctrine of inverse condemnation applies, which we discuss below under “Risks Related to Sempra California – Operational Risks.” For our regulated utilities, these costs may not be recoverable in rates. Insurance coverage for these costs may continue to increase or become prohibitively expensive, be disputed by insurers, or become unavailable for certain of these risks or at adequate levels, and any insurance proceeds may be insufficient to cover our losses or liabilities due to limitations, exclusions, high deductibles, failure to comply with procedural requirements or other factors. Such incidents that do not directly affect our facilities may impact our business partners, supply chains and transportation channels, which could negatively affect our ability to operate. Moreover, weather-related incidents have become more prevalent, unpredictable and severe as a result of climate change or other factors. As a result, these incidents could have a greater impact on our businesses than currently anticipated and, for our regulated utilities, rates may not be adequately or timely adjusted to reflect any such increased impact. Any such outcome could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Our facilities and infrastructure, including projects in development and under construction, may be damaged by severe weather, natural disasters, accidents, explosions or acts of terrorism, war or criminality. Because we are in the business of using, storing, transporting and disposing of highly flammable, explosive and radioactive materials and operating highly energized equipment, the risks such incidents may pose to our facilities and infrastructure, as well as the risks to the surrounding communities for which we could be held responsible, are substantially greater than the risks such incidents pose to a typical business. Such incidents could result in business and project development disruptions, power or gas outages, property damage, injuries and loss of life for which we could be liable and could cause secondary incidents that also may have these or other negative effects, such as fires; leaks of natural gas, natural gas odorant, propane, ethane, other GHG emissions or radioactive material; spills or other damage to natural resources; or other nuisances to affected communities. Any of these occurrences could decrease revenues and earnings and/or increase costs, including maintenance costs or restoration expenses, amounts associated with claims against us, and regulatory fines, penalties and disallowances. In some cases, we may be liable for damages even though we are not at fault, such as when the doctrine of inverse condemnation applies, which we discuss below under “Risks Related to Sempra California – Operational Risks.” For our regulated utilities, these costs may not be recoverable in rates. Insurance coverage for these costs may increase or become prohibitively expensive, be disputed by insurers, or become unavailable for certain of these risks or at sufficient levels, and any insurance proceeds may be insufficient to cover our losses or liabilities due to limitations, exclusions, high deductibles, failure to comply with procedural requirements or other factors. Such incidents that do not directly

SDG&E has a 20% ownership interest in SONGS, which we discuss in Note 15 of the Notes to Consolidated Financial Statements. SDG&E and each of the other owners of SONGS is responsible for financing its share of the facility’s expenses and capital expenditures, including those related to decommissioning activities. Although the facility is being decommissioned, SDG&E’s ownership interest in SONGS continues to subject it to risks, including: ▪the potential release of radioactive material ▪the potential harmful effects from the former operation of the facility ▪limitations on the insurance commercially available to cover losses associated with operating and decommissioning the facility

SDG&E has a 20% ownership interest in SONGS, which we discuss in Note 15 of the Notes to Consolidated Financial Statements. SDG&E and each of the other owners of SONGS is responsible for financing its share of the facility’s expenses and capital expenditures, including those related to decommissioning activities. Although the facility is being decommissioned, SDG&E’s ownership interest in SONGS continues to subject it to risks, including: ▪the potential release of radioactive material ▪the potential harmful effects from the former operation of the facility ▪limitations on the insurance commercially available to cover losses associated with operating and decommissioning the facility ▪uncertainties with respect to the technological and financial aspects of decommissioning the facility SDG&E maintains the SONGS NDT to provide funds for nuclear decommissioning. Trust assets have been generally invested in equity and debt securities, which are subject to market fluctuations. A decline in the market value of trust assets, an adverse change in the law regarding funding requirements for decommissioning trusts, or changes in assumptions or forecasts related to decommissioning dates, technology and the cost of labor, materials and equipment due to inflationary pressures or otherwise could increase the funding requirements for these trusts, which costs may not be fully recoverable in rates. In addition, CPUC approval is required to make withdrawals from the NDT, and CPUC approval for certain expenditures may be denied if the CPUC determines the expenditures are unreasonable. In addition, decommissioning may be materially more expensive than we currently anticipate and therefore decommissioning costs may exceed the amounts in the NDT. Rate recovery for overruns would require CPUC approval, which may not occur. The occurrence of any of these events could result in a reduction in our expected recovery and have a material adverse effect on SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents Environmental and Climate Change Regulation We are subject to extensive federal, state, regional, local and foreign statutes, orders, rules and regulations relating to climate change and environmental protection. To comply with these requirements, we must expend significant capital and employee resources on environmental monitoring, surveillance and other measures to track performance; acquisition and installation of pollution control equipment; mitigation efforts; and emissions fees, which could increase as a result of various factors we may not control, including changing laws and regulations, increased enforcement activities, delays in the renewal and issuance of permits, and changes to the mix of energy we transmit and distribute. In addition, we are generally responsible for hazardous substances and other contamination on and the conditions of our projects and properties, regardless of when these conditions arose and whether they are known or unknown. We have been and may be in the future required to pay environmental remediation costs at former facilities and off-site waste disposal sites where any of our businesses is identified as a PRP under federal, state and local environmental laws. For our regulated utilities, some of these costs may not be recoverable in rates. Failure to comply with environmental laws and regulations may subject us to fines and penalties, including criminal penalties in some cases, and/or curtailment of our operations. Any of these outcomes could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. Increasing international, national, regional, state and local environmental concerns and related changes to the legal and regulatory framework, such as requirements for increased monitoring and surveillance, disclosures on environmental performance, pollution monitoring and control equipment, safety practices, emissions fees, taxes, penalties or other obligations or restrictions, may have material negative effects on our operations, costs, corporate planning, and the scope and economics of proposed infrastructure projects or other capital expenditures. Recently enacted California laws requiring expansive disclosures on GHG emissions and other environmental measures, targets and claims subject us to potential liability for these disclosures and could have other consequences that may be difficult to predict, including negative sentiment from current and potential investors, regulators or other groups. Moreover, these new disclosure requirements may use different reporting frameworks and methodologies, including reporting boundaries, which may increase compliance costs and the risk of compliance failures and may create confusion for stakeholders. In addition, legislation and regulation relating to the control and reduction of GHG emissions and mitigating climate change is proliferating. For example, SB 100 (enacted in 2018) and SB 1020 (enacted in 2022) requires each California electric utility, including SDG&E, to procure at least 50% of its annual electric energy requirements from renewable energy sources by 2026, 60% by 2030, 90% by 2035, and 95% by 2040. State law also requires California’s retail electricity supply to be met with a mix of RPS Program-eligible and zero-carbon resources by 2045 without increasing carbon emissions elsewhere in the western grid or allowing resource shuffling, and instructs the CPUC, CEC, CARB and other state agencies to incorporate this requirement into all relevant planning. In addition, the Governor of California signed an executive order establishing a new statewide goal to achieve carbon neutrality as soon as possible, and no later than 2045, and achieve and maintain net negative emissions thereafter. The executive order calls on CARB to address this goal in future scoping plans, which affect several major sectors of California’s economy, including transportation, agriculture, development, industrial and others. California has issued new climate initiatives in line with this statewide goal, including two executive orders requiring sales of all passenger vehicles to be zero-emission by 2035. These or other similar new laws and rules may materially restrict our operations, negatively impact demand for our services and/or the energy we transmit and distribute, limit development opportunities, force costly or otherwise burdensome changes to our operations or otherwise materially adversely affect us. Energy Transition Risks The energy transition in California and elsewhere, including decarbonization goals, has introduced uncertainty in long-term investor support, leading some to reduce investment in or divest from our sector. Maintaining investor confidence and attracting capital at a competitive cost will depend in part on demonstrating our progress on our action plan supporting Sempra’s aim to have net-zero emissions by 2050 and SDG&E’s and SoCalGas’ aim to have net-zero emissions by 2045. Our ability to achieve these aims depends on many factors, some of which we do not control, including supportive energy laws, policies and regulatory decisions; development and adoption of alternative fuels; successful research and development efforts focused on low-carbon technologies that are economically and technically feasible; cooperation from our partners, financing sources and commercial counterparties; customer participation in conservation and energy efficiency programs, our ability to execute our planned investments in our infrastructure and our customers’ decisions and preferences. Although we have developed interim targets and various plans designed to advance California’s GHG emissions and renewable energy mandates and our own energy goals, we may not be successful. We will need to continue to expend capital and employee resources to develop and deploy new technologies and modernize grid systems to meet the demand for lower carbon and reliable energy in California and elsewhere and achieve our climate aspirations and those mandated by applicable authorities, which may not be recoverable in rates or, with respect to our non-regulated-utility

Climate change and the costs associated with its impacts and mitigation may have the potential to adversely affect our businesses, including by increasing the costs we incur to transmit energy and provide other services, impacting the demand for and consumption of the natural gas we distribute and the energy we transmit (due to changes in costs, weather patterns, the type of energy transmitted as a result of increasing customer preference for carbon-neutral and renewable sources of energy, and other factors), and affecting the economic health of the regions in which we operate. Our businesses are subject to extensive federal, state, local and foreign statutes, orders, rules and regulations relating to climate change and environmental protection. To comply with these requirements, we must expend significant capital and employee resources on (i) environmental monitoring, surveillance and other measures to track performance; (ii) acquisitions of pollution control equipment; (iii) mitigation efforts; and (iv) emissions fees, which could increase as a result of various factors we may not control, including changing laws and regulations, increased enforcement activities, delays in the renewal and issuance of permits, and changes to the mix of energy we are required to supply. In addition, we are generally responsible for hazardous substances and other contamination on and the conditions of our projects and properties, regardless of when these conditions arose and whether they are known or unknown. In addition, we could be liable for contamination at our former facilities and off-site waste disposal sites that have been used in our operations. For our regulated utilities, some of these costs may not be recoverable in rates. Failure to comply with environmental laws and regulations may subject our businesses to fines and penalties, including criminal penalties in some cases, and/or curtailment of our operations. Any of these outcomes could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. Increasing international, national, regional, state and local-level environmental concerns and related new or proposed legislation and regulation or changes to existing legislation or regulation, such as increased requirements for monitoring and surveillance, disclosures on environmental performance and targets, pollution monitoring and control equipment, safety practices, emissions fees, taxes, penalties or other obligations or restrictions, may have material negative effects on our operations, operating costs, corporate planning, and the scope and economics of proposed expansions, infrastructure projects or other capital expenditures. In addition, existing and potential new or amended legislation and regulation relating to the control and reduction of GHG emissions and mitigating climate change may materially restrict our operations, negatively impact demand for our services, the natural gas we distribute and/or the energy we transmit, limit development opportunities, force costly or otherwise burdensome changes to our operations or otherwise materially adversely affect us. For example, SB 100 (enacted in 2018) and SB 1020 (enacted in 2022) requires each California electric utility, including SDG&E, to procure at least 50% of its annual electric energy requirements from renewable energy sources by 2026, 60% by 2030, 90% by 2035, and 95% by 2040. State law also creates the policy of meeting all of California’s retail electricity supply with a mix of RPS Program-eligible and zero-carbon resources by 2045. The law also includes stipulations that this policy not increase carbon emissions elsewhere in the western grid and not allow resource shuffling, and requires that the CPUC, CEC, CARB and other state agencies incorporate this policy into all relevant planning. In addition, the Governor of California signed an executive order establishing a new statewide goal to achieve carbon neutrality as soon as possible, and no later than 2045, and achieve and maintain net negative emissions thereafter. The executive order calls on CARB to address this goal in future scoping plans, which affect several major sectors of California’s economy, including transportation, agriculture, development, industrial and others. California has issued new climate initiatives in line with this statewide goal, including two executive orders requiring sales of all passenger vehicles to be zero-emission by 2035. Moreover, the energy transition in California and elsewhere, including decarbonization goals, has introduced uncertainty in investor support over the long term, leading some to reduce investment in or divest from the energy sector. Maintaining investor confidence and attracting capital at a competitive cost will depend in part on successfully demonstrating our ability to reduce emissions associated with our operations and the energy we transmit, consistent with Sempra’s aim to have net-zero emissions by 2050 and SDG&E’s and SoCalGas’ aim to have net-zero emissions by 2045. Our ability to achieve this aim depends on many factors, some of which we do not control, including supportive energy laws and policies, development, availability and adoption of alternative fuels, successful research and development efforts focused on low-carbon technologies that are economically and technically feasible, cooperation from our partners, financing sources and commercial counterparties, customer participation in conservation and energy efficiency programs, and our ability to execute our planned investments in and advancement of our

Rates and Other Financial Matters The CPUC regulates SDG&E’s and SoCalGas’ customer rates, except for SDG&E’s electric transmission rates that are regulated by the FERC, and conditions of service. The CPUC also regulates SDG&E’s and SoCalGas’ sales of securities, rates of return, capital structure, rates of depreciation, long-term resource procurement and other financial matters in various ratemaking proceedings. The CPUC periodically approves SDG&E’s and SoCalGas’ customer rates based on authorized capital expenditures, operating costs, including income taxes, and an authorized rate of return on investments while incorporating a risk-based decision-making framework, as well as certain settlements with third parties. The outcome of ratemaking proceedings can be affected by various factors, many of which are not in our control, including the level of opposition by intervening parties; any rejection by the CPUC of settlements with third parties; increasing levels of regulatory review; changes in the political, regulatory, or legislative environments; and the opinions of regulators, customers and other stakeholders. These ratemaking proceedings include decisions about major programs in which SDG&E and SoCalGas make investments under an approved CPUC framework, such as wildfire mitigation and pipeline and storage integrity and safety enhancement programs, but which investments may remain subject to a CPUC filing or reasonableness review based on potentially unclear standards or other factors as described above that may result in the disallowance of incurred costs. SDG&E and SoCalGas also may be required to make investments and incur other costs to comply with proposed legislative and regulatory requirements and initiatives, including those related to California’s climate goals and policies, and the ability to recover these costs and investments may depend on the final form of the legislative or regulatory requirements and the corresponding ratemaking mechanisms. Recovery may be delayed and/or insufficient if the applicable ratemaking mechanism involves a significant time lag between when costs are incurred and when those costs are recovered in rates or if there are material differences between the authorized costs embedded in rates (which are set on a prospective basis) and the actual costs incurred. Delays may also result from the administrative process, or the CPUC may deny recovery altogether on the basis that costs were not reasonably or prudently incurred or for other reasons, such as customer affordability. Even if recoverable, investing to support the regulatory requirements and demand for lower carbon, reliable energy in California and in necessary safety and reliability at the same time may negatively impact the affordability of SDG&E’s and SoCalGas’ customer rates and their and Sempra’s results of operations, financial condition, cash flows and/or prospects. In addition, a CPUC cost of capital proceeding every three years determines a utility’s authorized capital structure and return on rate base, and the CCM applies in the interim years and considers changes in the cost of capital based on changes in interest rates for each 12-month period ending September 30 (the measurement period), subject to regulatory approval. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application to have its cost of capital determined in lieu of the CCM in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. Any such rate change due to a downward trigger of the CCM or the denial by the CPUC of an automatic upward trigger of the CCM could have a material adverse effect on Sempra’s and the applicable utility’s results of operations, financial condition, cash flows and/or prospects. We discuss the CCM in “Part I – Item 1. Business - Ratemaking Mechanisms – Sempra California – Cost of Capital Proceedings,” and in Note 4 of the Notes to Consolidated Financial Statements. The FERC regulates electric transmission rates, the transmission and wholesale sales of electricity in interstate commerce, transmission access, the rates of return on investments in electric transmission assets, and other similar matters involving

Table of Contents Table of Contents factors, many of which are not in our control, including the level of opposition by intervening parties; any rejection by the CPUC of settlements with third parties; potential rate impacts; increasing levels of regulatory review; changes in the political, regulatory, or legislative environments; and the opinions of regulators, consumer and other stakeholder groups and customers. These ratemaking proceedings include decisions about major programs in which SDG&E and SoCalGas make investments under an approved CPUC framework, such as wildfire mitigation and pipeline and storage integrity and safety enhancement programs, but which investments may remain subject to a CPUC filing or reasonableness review with potentially unclear standards or other factors as described above that may result in the disallowance of incurred costs. SDG&E and SoCalGas also may be required to incur costs and make investments to comply with proposed legislative and regulatory requirements and initiatives, including those related to California’s climate goals and policies, and their ability to recover these costs and investments may depend on the final form of the legislative or regulatory requirements and the ratemaking mechanisms associated with them. Recovery can also be affected by the timing and process of the ratemaking mechanism, in which there can be a significant time lag between when costs are incurred and when those costs are recovered in customers’ rates and material differences between the forecasted and authorized costs embedded in rates (which are set on a prospective basis) and the actual costs incurred. The CPUC may also experience delays in its decisions on recovery or may deny recovery altogether on the basis that costs were not reasonably or prudently incurred or for other reasons. Even if recoverable, the cost of investments to support the clean energy transition in California while also investing in necessary safety and reliability may negatively impact the affordability of SDG&E’s and SoCalGas’ customer rates and their and Sempra’s results of operations, financial condition, cash flows and/or prospects. In addition, a CPUC cost of capital proceeding every three years determines a utility’s authorized capital structure and authorized return on rate base, and the CCM applies in the interim years and considers changes in the cost of capital based on changes in interest rates for each 12-month period ending September 30 (the measurement period). Alternatively, each of SDG&E and SoCalGas are permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole to have its cost of capital determined in lieu of the CCM. Any such rate change due to a downward trigger of the CCM could have a material adverse effect on Sempra’s and the applicable utility’s results of operations, financial condition, cash flows and/or prospects. We discuss the CCM in “Part I – Item 1. Business - Ratemaking Mechanisms – Sempra California – Cost of Capital Proceedings,” and in Note 4 of the Notes to Consolidated Financial Statements. The FERC regulates electric transmission rates, the transmission and wholesale sales of electricity in interstate commerce, transmission access, the rates of return on investments in electric transmission assets, and other similar matters involving SDG&E. These ratemaking mechanisms are subject to many risks similar to those described above regarding the CPUC ratemaking proceedings. CPUC Authority Over Operational Matters The CPUC has regulatory authority related to safety standards and practices, competitive conditions, reliability and planning, affiliate relationships and a wide range of other operational matters, including citation programs concerning matters such as safety activity, disconnection and billing practices, resource adequacy and environmental compliance. Many of these standards and citation programs are becoming more stringent and could impose significant penalties, including enforcement programs under which the CPUC staff can issue citations that in some cases can impose substantial fines. The CPUC also continues to explore expansion of its programs to provide additional oversight. The CPUC conducts reviews and audits of the matters under its authority and could launch investigations or open proceedings at any time on any such matter it deems appropriate, the results of which could lead to citations, disallowances, fines and penalties, as well as corrective or mitigation actions required to address any noncompliance that may not be sufficiently funded by customer rates or at all. Any such occurrence could have a material adverse effect on Sempra’s, SDG&E’s and SoCalGas’ results of operations, financial condition, cash flows and/or prospects. We discuss various CPUC proceedings relating to SDG&E and SoCalGas in Notes 4 and 16 of the Notes to Consolidated Financial Statements. Potential Regulatory Changes and Influence of Other Organizations SDG&E, SoCalGas and Sempra may be materially adversely affected by revisions or reinterpretations of existing or new legislation, regulations, decisions, orders or interpretations of the CPUC, the FERC or other regulatory bodies, any of which could change how SDG&E and SoCalGas operate, affect their ability to recover various costs through rates or adjustment mechanisms, require them to incur additional expenses or otherwise materially adversely affect their and Sempra’s results of operations, financial condition, cash flows and/or prospects. SDG&E and SoCalGas are also affected by numerous advocacy groups, including California Public Advocates Office, The Utility Reform Network, Utility Consumers’ Action Network and the Sierra Club. Any success by any of these groups in directly or

Table of Contents Table of Contents The Wildfire Legislation In July 2019, the Wildfire Legislation was signed into law, which we discuss in Note 1 of the Notes to Consolidated Financial Statements. The Wildfire Legislation’s legal standard for the recovery of wildfire costs may not be implemented effectively or applied consistently, we may not be eligible for the Wildfire Legislation’s cap on wildfire-related liability if SDG&E fails to maintain a valid annual safety certification from the OEIS or meet other requirements, and/or the Wildfire Fund could be exhausted due to claims against the fund by SDG&E or other participating IOUs as a result of fires in their respective service territories, any of which could have a material adverse effect on Sempra’s and SDG&E’s results of operations, financial condition, cash flows and/or prospects. PG&E has indicated it will seek reimbursement from the Wildfire Fund for losses associated with the Dixie fire, which burned from July 2021 through October 2021 and was reported to be the largest single wildfire (measured by acres burned) in California history. In addition, the Wildfire Legislation did not change the doctrine of inverse condemnation, which imposes strict liability (meaning that liability is imposed regardless of fault) on a utility whose equipment is determined to be a cause of a fire. In such an event, the utility would be responsible for the costs of damages, including business interruption losses, interest and attorneys’ fees, even if the utility is not found negligent. In the past, the CPUC has denied recovery of costs incurred as a result of the doctrine of inverse condemnation. The doctrine of inverse condemnation also is not exclusive of other theories of liability, such as negligence, under which additional liabilities, such as fire suppression, clean-up and evacuation costs, medical expenses, and personal injury, punitive and other damages, could be imposed. We are unable to predict the impact of the Wildfire Legislation on SDG&E’s ability to recover costs and expenses if SDG&E’s equipment is determined to be a cause of a fire, and specifically in the context of the application of inverse condemnation. Cost Recovery Through Insurance or Rates As a result of California’s doctrine of inverse condemnation, substantial losses recorded by insurance companies, and increased wildfire risk, obtaining insurance coverage for wildfires that could be caused by SDG&E (or, to a lesser extent, SoCalGas) has become increasingly difficult and costly. If these conditions continue or worsen, insurance for wildfire liabilities may become unavailable or may become prohibitively expensive and we may be denied recovery of insurance cost increases through the regulatory process. In addition, insurance for wildfire liabilities may not be sufficient to cover all losses we may incur, or it may not be available to meet the $1.0 billion of primary insurance required by the Wildfire Legislation. We are unable to predict whether we would be able to recover in rates or from the Wildfire Fund the amount of any uninsured losses. A loss that is not fully insured, is not sufficiently covered by the Wildfire Fund and/or cannot be recovered in customer rates could materially adversely affect Sempra’s and one or both of SDG&E’s and SoCalGas’ results of operations, financial condition, cash flows and/or prospects. Wildfire Mitigation Efforts Although we expend significant resources on measures designed to mitigate wildfire risks, these measures may not be effective in preventing wildfires or reducing our wildfire-related losses and their costs may not be fully recoverable in rates. SDG&E is required by California law to submit wildfire mitigation plans for approval by the OEIS and could be subject to increased risks if these plans are not approved in a timely manner or the measures set forth in the plans are not implemented effectively, as well as fines or penalties for any failure to comply with the approved plans. One of our wildfire mitigation strategies is to de-energize certain circuits for safety when there is elevated weather-related wildfire ignition risk. These “public safety power shutoffs” have been subject to scrutiny by various stakeholders, including customers, regulators and lawmakers, which could increase the risk of liability for damages associated with these events. Such costs may not be recoverable in rates. Unrecoverable costs, adverse legislation or rulemaking, scrutiny by key stakeholders, ineffective wildfire mitigation measures or other negative effects associated with these efforts could materially adversely affect Sempra’s and SDG&E’s results of operations, financial condition, cash flows and/or prospects.

Potential for Increased and More Severe Wildfires Over the past few years, California has been experiencing some of the largest wildfires (measured by acres burned) in its history. Frequent and severe drought conditions, inconsistent and extreme swings in precipitation, changes in vegetation, unseasonably warm temperatures, low humidity, strong winds and other factors have increased the duration of the wildfire season and the intensity, prevalence and difficulty of prevention and containment of wildfires in California, including in SDG&E’s and SoCalGas’ service territories. Changing weather patterns, including as a result of climate change, could cause these conditions to become even more extreme and unpredictable. These wildfires could jeopardize SDG&E’s and SoCalGas’ electric and natural gas infrastructure and third-party property and result in temporary power shortages in SDG&E’s and SoCalGas’ service territories. Certain of California’s local land use policies and forestry management practices have been relaxed to allow for the construction and development of residential and commercial projects in high-risk fire areas, which could lead to increased third-party claims and greater losses in the event of fires in these areas for which SDG&E or SoCalGas may be liable. Any such wildfires in SDG&E’s and SoCalGas’ territories (or outside of these territories in the event the Wildfire Fund described below is materially diminished) could materially adversely affect SDG&E’s, SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects, which we discuss in this risk factor below and above under “Risks Related to All Sempra Businesses – Operational Risks.” The Wildfire Legislation In July 2019, the Wildfire Legislation was signed into law, which we discuss in Note 1 of the Notes to Consolidated Financial Statements. The Wildfire Legislation’s revised legal standard for the recovery of wildfire costs may not be implemented effectively or applied consistently, we may not be eligible for the Wildfire Legislation’s cap on wildfire-related liability if SDG&E fails to maintain a valid annual safety certification from the OEIS or meet other requirements of the legislation, and/or the Wildfire Fund could be exhausted due to claims against the fund by SDG&E or other participating IOUs as a result of fires in their respective service territories, any of which could have a material adverse effect on Sempra’s and SDG&E’s results of operations, financial condition, cash flows and/or prospects. PG&E has indicated that it will seek reimbursement from the Wildfire Fund for losses associated with the Dixie fire, which burned from July 2021 through October 2021 and was reported to be the largest single wildfire (measured by acres burned) in California history. In addition, the Wildfire Legislation did not change the doctrine of inverse condemnation, which imposes strict liability (meaning that liability is imposed regardless of fault) on a utility whose equipment, such as its electric distribution and transmission lines, is determined to be a cause of a fire. In such an event, the utility would be responsible for the costs of damages, including potential business interruption losses, and interest and attorneys’ fees, even if the utility has not been found negligent. The doctrine of inverse condemnation also is not exclusive of other theories of liability, including if the utility were found negligent, in which case additional liabilities, such as fire suppression, clean-up and evacuation costs, medical expenses, and personal injury, punitive and other damages, could be imposed. We are unable to predict the impact of the Wildfire Legislation on SDG&E’s ability to recover costs and expenses in the event that SDG&E’s equipment is determined to be a cause of a fire, and specifically in the context of the application of inverse condemnation. Cost Recovery Through Insurance or Rates As a result of the strict liability standard applied to electric IOU-caused wildfires in California, substantial losses recently recorded by insurance companies, and the risk of an increase in the number and size of wildfires, obtaining insurance coverage for wildfires that could be caused by SDG&E (or, to a lesser extent, SoCalGas) has become increasingly difficult and costly. If these conditions continue or worsen, insurance for wildfire liabilities may become unavailable or may become prohibitively expensive and we may be challenged or unsuccessful when we seek recovery of insurance cost increases through the regulatory process. In addition, insurance for wildfire liabilities may not be sufficient to cover all losses we may incur, or it may not be available in sufficient amounts to meet the $1.0 billion of primary insurance required by the Wildfire Legislation. We are unable to predict whether we would be able to recover in rates or from the Wildfire Fund the amount of any uninsured losses. A loss that is not fully insured, is not sufficiently covered by the Wildfire Fund and/or cannot be recovered in customer rates could materially adversely affect Sempra’s and one or both of SDG&E’s and SoCalGas’ results of operations, financial condition, cash flows and/or prospects.

We have investments in businesses we do not control or manage or in which we share control. In some cases, we engage in arrangements with or for these businesses that could expose us to risks in addition to our investment, including guarantees, indemnities and loans. For businesses we do not control, we are subject to the decisions of others, which may be adverse to our interest. When we share control of a business with other owners, any disagreements among the owners about strategy, financial, operational, transactional or other important matters could hinder the business from moving forward with key initiatives or taking other actions and could negatively affect the relationships among the owners and the efficient functioning of the business. In addition, irrespective of whether we control these businesses, we could be responsible for liabilities or losses related to these businesses or elect to make capital contributions to these businesses. Any such circumstance could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. We discuss these investments in Note 6 of the Notes to Consolidated Financial Statements.

We have investments in businesses we do not control or manage or in which we share control. In some cases, we engage in arrangements with or for these businesses that could expose us to risks in addition to our investment, including guarantees, indemnities and loans. For businesses we do not control, we are subject to the decisions of others, which may not always be in our interest and could negatively affect us. When we share control of a business with other owners, any disagreements among the owners about strategy, financial, operational, transactional or other important matters could hinder the business from moving forward with key initiatives or taking other actions and could negatively affect the relationships among the owners and the efficient functioning of the business. In addition, irrespective of whether or not we control these businesses, we could be responsible for liabilities or losses related to these businesses or elect to make capital contributions to these businesses. Any such circumstance could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. We discuss these investments in Note 6 of the Notes to Consolidated Financial Statements.

We use forward contracts, futures, financial swaps and/or options, among other mechanisms, to hedge a portion of our known or anticipated purchase and sale commitments, inventories of natural gas and LNG, natural gas storage and pipeline capacity and electric generation capacity in an effort to reduce our, and for SDG&E and SoCalGas, customers’ financial exposure related to commodity price fluctuations. The extent of the coverage to these exposures varies over time. In addition, we have used and may continue to use similar financial instruments to hedge against changes in interest rates. Certain derivative instruments we use to hedge are recorded at fair value through earnings to reflect movements in the price of the derivative, which has recently and could in the future create volatility in our earnings. To the extent we have unhedged positions, or if any hedging counterparty fails to fulfill its contractual obligations or if our hedging strategies do not work as intended, fluctuating commodity prices and interest rates could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

We have used and may continue to use forward contracts, futures, financial swaps and/or options, among other mechanisms, to hedge our known or anticipated purchase and sale commitments, inventories of natural gas and LNG, natural gas storage and pipeline capacity and electric generation capacity in an effort to reduce our financial exposure related to commodity price fluctuations. We do not hedge the entire exposure to market price volatility of our assets or our contract positions, and the extent of the coverage to these exposures varies over time. In addition, we have used and may continue to use similar financial instruments to hedge against changes in interest rates. Certain derivative securities we use to hedge are recorded at fair value through earnings to reflect movements in the price of the security, which has in the past and could in the future create volatility in our earnings (such as the significantly higher unrealized losses on commodity derivatives that we recognized in 2022 compared to 2021 as we discuss in “Part II – Item 7. MD&A – Results of Operations”). To the extent we have unhedged positions, or if our hedging strategies do not work as expected, fluctuating commodity prices could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Certain of the contracts we may use for hedging purposes are subject to fair value accounting, which may result in gains or losses in earnings for those contracts that may not reflect the associated gains or losses of the underlying position being hedged and could result in fluctuations of our results from period to period.

Our use of complex technologies and systems in our operations, including our increasing deployment of new technologies and virtualization of many business activities, and our collection and retention of personal, sensitive and confidential information, represent large-scale opportunities for attacks on or other failures to protect our information systems, information and energy grid and natural gas infrastructure. We are also vulnerable in the event of attacks on or failures to protect third-party vendors’ technologies and systems, depending on the level of access these vendors have to our information and systems. In particular, ransomware and other forms of cyber-attacks targeting utility systems and other energy infrastructure are continuously increasing in sophistication, magnitude and frequency, may not be recognized until launched against a target and may further escalate during periods of heightened geopolitical tensions. Accordingly, we may be unable to anticipate these techniques or to implement adequate security barriers or other preventative measures, making it impossible for us to entirely eliminate this risk. Additionally, SDG&E and SoCalGas are increasingly required to disclose large amounts of data (including customer personal information and energy use data) to support state initiatives related to grid modernization, customer choice, energy efficiency, demand response and conservation, increasing the risks of inadvertent disclosure or unauthorized access of sensitive information. Moreover, all our businesses operating in California (and in other states and countries that have similar laws) are subject to enhanced state privacy laws, which require companies that collect information about California residents to, among other things, disclose their data collection, use and sharing practices; allow consumers to opt out of certain data sharing with third parties; and assume liability for unauthorized disclosure of certain highly sensitive personal information. Although we make significant investments in risk management and information security measures for the protection of our systems and data, these measures could be insufficient or otherwise fail. The costs and operational consequences of implementing, maintaining and enhancing these measures are significant and expected to increase to address the growing intensity and complexity of cyber risks. We often rely on third-party vendors to deploy new technologies and maintain and update our systems, and these third parties may not have adequate risk management and information security measures with respect to their systems. Although we have not experienced a material breach of our information systems or data, we and some of our vendors have been and will likely continue to be subject to breaches of and attempts to gain unauthorized access to our systems or data or efforts to otherwise disrupt our operations. Any actual or perceived noncompliance with applicable data privacy and security laws or any

Our use of complex technologies and systems in our operations, including deployment of any new technologies, and our collection and retention of sensitive information, represent large-scale opportunities for attacks on or other failures to protect our information systems, confidential information and energy grid and natural gas infrastructure. In particular, cyber-attacks targeting utility systems and other energy infrastructure, as well as the impacts of these attacks on companies and their communities, are increasing in sophistication, magnitude and frequency and may further increase in connection with certain geopolitical events, such as the war in Ukraine. Additionally, SDG&E and SoCalGas are increasingly required to disclose large amounts of data (including customer personal information and energy use data) to support changes to California’s electricity and gas markets related to grid modernization and customer choice as well as energy efficiency, demand response and conservation, increasing the risks of inadvertent disclosure or other unauthorized access of sensitive information. Further, the virtualization of many business activities increases cyber risk, and generally there has been an associated increase in targeted cyber-attacks. Moreover, all our businesses operating in California (and any other states and countries where we do business that adopt similar laws) are subject to enhanced state privacy laws, which require companies that collect information about California residents to, among other things, make disclosures to consumers about their data collection, use and sharing practices; allow consumers to opt out of certain data sharing with third parties; and assume liability under a new cause of action for unauthorized disclosure of certain highly sensitive personal information. Although we invest in risk management and information security measures for the protection of our systems and information, these measures could be insufficient or otherwise fail. The costs and operational consequences of implementing, maintaining and enhancing these protection measures are significant, and they could materially increase to address increasingly intense and complex cyber risks. We often rely on third-party vendors to deploy new business technologies and maintain, modify and update our systems, and these third parties may not have adequate risk management and information security measures with respect to their systems. Any cyber-attack, including ransomware attacks, on our or our vendors’ information systems or the integrity of the energy grid, our pipelines or our distribution, storage and other infrastructure, or unauthorized access, damage or improper disclosure of confidential information, could result in disruptions to our business operations, regulatory compliance failures, inabilities to produce accurate and timely financial statements, energy delivery failures, financial and reputational loss, customer dissatisfaction, litigation, violation of privacy laws and fines or penalties, any of which could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Although Sempra currently maintains cyber liability insurance, this insurance is limited in scope and subject to exceptions, conditions and coverage limitations and may not cover any or even a substantial portion of the costs associated with any compromise of our information systems or confidential information, and there is no guarantee that the insurance we currently maintain will continue to be available at rates we believe are commercially reasonable.

We regularly undertake or become involved in research and development projects and other activities designed to develop new technologies in the energy space, including those related to hydrogen, liquefaction, energy storage, carbon sequestration, grid modernization and others. These activities and projects involve significant employee time, as well as substantial capital resources that may not be recoverable in rates or, with respect to our non-regulated-utility businesses, may not be able to be passed through to customers. We have sought and continue to seek a variety of federal and state funding opportunities for these activities and projects, which can involve significant employee resources and increased compliance requirements with no guarantee that such funding would be received. In addition, the timing to complete these activities and projects is inherently uncertain and may require significantly more time and funding than we initially anticipate. Moreover, many of these technologies are in the early stage of development, and the applicable activities and projects may not be completed or the applicable technologies may not prove economically and technically feasible. If any of these circumstances occurs, we may not receive an adequate or any return on our investment and other resources invested in these activities and our results of operations, financial condition, cash flows and/or prospects could be materially adversely affected.

We regularly undertake or become involved in research and development projects and other activities designed to develop new technologies in the energy space, including those related to hydrogen, energy storage, carbon sequestration, grid modernization and others. These activities and projects can involve significant employee time, as well as substantial capital resources that may

Several of our businesses have in place collective bargaining agreements with different labor unions, which are generally negotiated on a company-by-company basis. SoCalGas has a collective bargaining agreement that expires on September 30, 2024. Any prolonged negotiation or failure to reach an agreement on these labor contracts as they are up for renewal could result in work stoppages or other labor disruptions. Additionally, we have been faced with a shortage of experienced and qualified personnel in certain specialty operational positions and could experience labor disruptions from personnel in those positions. Any such labor disruption or negotiated wage or benefit increases, whether due to union activities, employee turnover, labor shortages or otherwise, could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Several of our businesses have in place collective bargaining agreements with different labor unions, which are generally negotiated on a company-by-company basis. Any failure to negotiate and reach an agreement on these labor contracts as they are up for renewal could result in strikes, boycotts or other labor disruptions. Any such labor disruption or negotiated wage or benefit increases, whether due to union activities, employee turnover or otherwise, could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents approval of its requests in any rate proceeding could adversely impact Oncor, which could adversely impact us, and those impacts could be material. The costs and burdens associated with complying with the various legislative and regulatory requirements to which Oncor is subject at the federal, state, and local levels and adjusting Oncor’s business and operations in response to legislative and regulatory developments, including changes in ERCOT, and any fines or penalties that could result from any noncompliance, may have a material adverse effect on Oncor. In addition, insufficient electric capacity within ERCOT or significant changes within ERCOT or to the ERCOT market structure that impact transmission and distribution utilities, including additional regulatory requirements or oversight, could materially adversely affect Oncor. Moreover, legislative, regulatory, market or industry activities could adversely impact Oncor’s collections and cash flows and jeopardize the predictability of utility earnings. For instance, the PUCT has instituted various projects reviewing the regulatory framework regarding DER and other non-traditional technologies. As DER usage continues to grow, related regulatory decisions, including with respect to ERCOT market rules and transmission and distribution utilities’ ability to invest in non-traditional electricity delivery solutions, could adversely impact Oncor’s revenues and operations. If Oncor does not successfully respond to applicable legislative, regulatory, market or industry developments, Oncor could suffer a deterioration in its results of operations, financial condition, cash flows and/or prospects, which could materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents regulatory developments, including changes in ERCOT, and any fines or penalties that could result from any noncompliance, may have a material adverse effect on Oncor. In addition, any economic weakness in the ERCOT market or slowing growth in Oncor’s service territory could lead to reduced electricity demand, which could materially adversely affect Oncor. Moreover, legislative, regulatory, market or industry activities could adversely impact Oncor’s collections and cash flows and jeopardize the predictability of utility earnings. For instance, the PUCT has instituted various projects reviewing the regulatory framework regarding DER and other non-traditional technologies. As DER usage continues to grow, regulatory decisions made with respect to DER, including with respect to ERCOT market rules and transmission and distribution utilities’ ability to invest in non-traditional electricity delivery solutions, could adversely impact Oncor’s revenues and operations. If Oncor does not successfully respond to any legislative, regulatory, market or industry changes applicable to it, Oncor could suffer a deterioration in its results of operations, financial condition, cash flows and/or prospects, which could materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents compete with incumbent utilities for the construction and operation of transmission facilities. The CPUC is conducting various proceedings regarding DER, including the evaluation of special programs and pilots; changes to the planning and operation of the electric grid to prepare for higher penetration of DER; future grid modernization investments; the deferral of traditional grid investments by DER; and the role of the electric grid operator. These proceedings and the broader changes in California’s electricity industry could result in new regulations, policies and/or operational changes that could materially adversely affect SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects. Most of SDG&E’s customers receive electric procurement service from a load-serving entity other than SDG&E through programs such as CCA and DA. CCA is only available if a customer’s local jurisdiction (city or county) offers such a program, as is the case with the City of San Diego and certain other jurisdictions in SDG&E’s service territory, and DA is currently limited by a cap based on gigawatt hours. As a result of customers electing CCA and DA services, SDG&E’s historical energy procurement commitments for future deliveries exceed the needs of its remaining bundled customers. To help achieve the goal of ratepayer indifference (as to whether customers’ energy is procured by SDG&E or by CCA or DA), the CPUC revised the Power Charge Indifference Adjustment framework. The purpose of the framework is to help ensure SDG&E’s procurement cost obligations are more equitably shared among customers served by SDG&E and customers now served by CCA and DA. If the framework or other mechanisms designed to achieve ratepayer indifference do not perform as intended, if the law changes, or if the law is not interpreted or enforced as expected, SDG&E’s remaining bundled customers could experience large increases in rates for commodity costs under commitments made on behalf of CCA and DA customers prior to their departure or, if all such costs are not recoverable in rates, SDG&E could experience material increases in its unrecoverable commodity costs. Any of these outcomes could have a material adverse effect on SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Electric utilities in California are experiencing increasing deployment of DER, such as solar generation, energy storage and energy efficiency and demand management technologies, and California’s environmental policy objectives are accelerating the pace and scope of these changes. This growth of DER and demand management will require further modernization of the electric distribution grid to, among other things, accommodate increasing two-way flows of electricity and increase the grid’s capacity to interconnect these resources. In addition, enabling California’s clean energy goals will require sustained investments in grid modernization, renewable integration projects, energy efficiency programs, energy storage options, operational and data management systems, and electric vehicle infrastructure. The growth of third-party energy storage alternatives and other technologies also may increasingly compete with SDG&E’s traditional transmission and distribution infrastructure in delivering electricity to consumers. The CPUC is conducting several proceedings regarding DER and demand management, including the evaluation of various projects and pilots; changes to the planning and operation of the electric distribution grid to prepare for higher penetration of DER; future grid modernization and grid investments; the deferral of traditional grid investments by DER; and the role of the electric distribution grid operator. These proceedings and the broader changes in California’s electricity industry could result in new regulations, policies and/or operational changes that could materially adversely affect SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects. SDG&E provides bundled electric procurement service through various resources that are typically procured on a long-term basis. Although SDG&E currently provides such procurement service for a portion of its customer load, most customers receive procurement service from a load-serving entity other than SDG&E through programs such as CCA and DA, in which case SDG&E no longer procures energy for this departing load. CCA is only available if a customer’s local jurisdiction (city or county) offers such a program and DA is currently limited by a cap based on gigawatt hours. Several jurisdictions in SDG&E’s territory, including the City of San Diego, have implemented CCA, and additional jurisdictions are in the process of implementing or considering CCA. SDG&E’s historical energy procurement for future deliveries exceeds the needs of its remaining bundled customers as customers have elected CCA and DA services. To help achieve the goal of ratepayer indifference (as to whether or not customers’ energy is procured by SDG&E or by CCA or DA), the CPUC revised the Power Charge Indifference Adjustment framework. The purpose of the framework is to help ensure SDG&E’s procurement cost obligations are more equitably shared among customers served by SDG&E and customers now served by CCA and DA. SDG&E implemented the framework on January 1, 2019. If the framework or other mechanisms designed to achieve ratepayer indifference do not perform as intended, if the law changes, or if the law is not interpreted or enforced as expected, SDG&E’s remaining bundled customers could experience large increases in rates for commodity costs under commitments made on behalf of CCA and DA customers prior to their departure or, if all such costs are not recoverable in rates, SDG&E could experience material increases in its unrecoverable commodity costs. Any of these outcomes could have a material adverse effect on SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Certain California legislators and other stakeholders have expressed a desire to limit or eliminate reliance on natural gas as an energy source by advocating increased use of renewable electricity and electrification. Reducing methane emissions also has become a major focus of certain local, state and federal agencies, resulting in passed or proposed legislation, regulation, policies and ordinances to prohibit or restrict the use of natural gas in new buildings, appliances and other applications. These actions could have the effect of reducing natural gas use over time. CARB, California’s primary regulator for GHG emissions reduction programs, has proposed to reduce natural gas demand through building decarbonization measures (such as zero-emission standards for space and water heaters) or legislation requiring increased renewable electricity generation. Additionally, the CEC’s Title 24 requirements mandate that new construction include electric-ready buildings and heat pump technologies beginning in 2023. The CPUC has an ongoing proceeding that seeks to establish a state-wide process to help utilities plan appropriate gas infrastructure portfolios as natural gas usage in the state is expected to change with overall consumption expected to decline. This includes a General Order requiring site-specific approvals for certain gas infrastructure projects. The CPUC may continue to enact measures to reduce natural gas demand (such as more aggressive energy efficiency programs), promote fuel substitution (such as replacement of natural gas appliances with electric appliances), and order other changes (such as its decision to eliminate gas line extension allowances for new applications submitted on or after July 1, 2023). A substantial reduction in or the elimination of natural gas use in California without adequate recovery of investments could result in impairment of some or all of SoCalGas’ and SDG&E’s natural gas infrastructure assets if they were not permitted to be repurposed for alternative fuels, were required to be depreciated on an accelerated basis or were to become stranded, which could have a material adverse effect on SoCalGas’, SDG&E’s and Sempra’s results of operations, financial conditions, cash flows and/or prospects.

Certain California legislators, as well as stakeholder, advocacy and activist groups, have expressed a desire to limit or eliminate reliance on natural gas as an energy source by advocating increased use of renewable electricity and electrification in lieu of the use of natural gas. Reducing methane emissions also has become a major focus of certain local and state agencies and the U.S. Administration, as well as the CPUC, resulting in passed or proposed legislation, regulation, policies and ordinances to prohibit or restrict the use and consumption of natural gas in new buildings, appliances and other applications. These actions could have the effect of reducing natural gas use over time.

Our businesses depend on the performance of business partners, customers, suppliers and other counterparties under contractual and other arrangements to provide, among other things, services, equipment, or commodities and who may have significant unpaid financial obligations to us under these arrangements. If they fail to perform their obligations in accordance with these arrangements, we may be unable to meet our obligations and we may be required to enter into alternative arrangements or honor our underlying commitments at then-current market prices, which may result in losses to us or delays or other disruptions to our operations. Any efforts to enforce the terms of these arrangements through legal or other means could involve significant time and costs and would be unpredictable and subject to failure. In addition, many of these arrangements, including our relationships with the applicable counterparties, are important for the conduct and growth of our businesses. We also may not be able to secure replacement agreements with other counterparties on favorable terms, in a timely manner or at all if any of these arrangements terminate. Further, we often extend credit to customers and other counterparties and, although we perform credit analyses prior to extending credit, we may not be able to collect the amounts owed to us, which could be significant and present an increased risk

Our businesses depend on the performance of business partners, customers, suppliers and other counterparties who owe money or commodities as a result of market transactions or other long-term arrangements. If they fail to perform their obligations in accordance with these arrangements, we may need to enter into alternative arrangements or honor our underlying commitments at then-current market prices, which may result in additional losses to us to the extent of amounts already paid to such counterparties. Any efforts to enforce the terms of these arrangements through legal or other means could involve significant time and costs and would be unpredictable and may not be successful. In addition, many of these arrangements, including our relationships with the applicable counterparties, are important for the conduct and growth of our businesses. We also may not be able to secure replacement agreements with other counterparties on favorable terms, in a timely manner or at all if any of these arrangements terminate. Further, we often extend credit to customers and other counterparties and, although we perform credit analyses prior to extending credit, we may not be able to collect the amounts owed to us, which presents an increased risk for our long-term supply, sales and capacity contracts. The failure of any of our counterparties to perform in accordance with their arrangements with us could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. Sempra Infrastructure’s obligations and those of its LNG suppliers are contractually subject to suspension or termination for force majeure events, which generally are beyond the control of the parties, and limitations of remedies for other failures to perform, including limitations on damages that may prohibit recovery of costs incurred for any breach of an agreement. Any such occurrence could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Sempra Infrastructure engages in JVs and invests in companies in which other equity partners may have or share with us control over the applicable project or investment. Sempra Texas Utilities also invests in companies that it does not control or manage. We discuss the risks related to these arrangements above under “Risks Related to Sempra – Operational and Structural Risks.”

Oncor operates in the electric utility industry and, as a result, it is subject to many of the same or similar risks as Sempra California as we describe above under “Risks Related to Sempra California,” particularly with respect to regulation by federal, state, and local legislative and regulatory authorities regarding rates and other financial matters as well as operational matters. Oncor operates in the ERCOT market. In ERCOT, rates are set by the PUCT based on a historical test year, and as a result, the rates Oncor is allowed to charge generally will not exactly match its costs at any given point in time and there is no assurance that it will be able to timely or fully recover its actual costs and/or earn its full return on invested capital. Further, the approved levels of recovery could be significantly less than the requested levels, and the approved timing for recovery could differ from proposed timelines. In addition to requests to recover its costs, Oncor’s rate proceedings may contain other requests. Failure to receive

Oncor operates in the electric utility industry and, as a result, it is subject to many of the same or similar risks as Sempra California as we describe above under “Risks Related to Sempra California,” particularly with respect to regulation by federal, state, and local legislative and regulatory authorities regarding rates and other financial matters as well as operational matters. Oncor operates in the ERCOT market. In ERCOT, rates are set by the PUCT based on a historical test year, and as a result, the rates Oncor is allowed to charge generally will not exactly match its costs at any given point in time and there is no assurance that it will be able to earn its full return on invested capital. Further, the PUCT may not approve all items requested by Oncor in any rate proceeding, such as Oncor’s base rate review currently pending with the PUCT, including, among other things, recovery of all costs in rates, capital structure and authorized ROE. Failure to receive approval of its requests in any rate proceeding could adversely impact Oncor, which could adversely impact us, and those impacts could potentially be material. The costs and burdens associated with complying with the various legislative and regulatory requirements to which Oncor is subject at the federal, state, and local levels and adjusting Oncor’s business and operations in response to legislative and

The industries in which we operate are subject to numerous governmental regulations, and our business requires numerous permits, licenses, rights-of-way, franchises, certificates and other approvals from federal, state, local and foreign governmental agencies. For example, SoCalGas’ franchise agreement with Los Angeles County initially expired in June 2023 and the subsequent extension expired in December 2023. SoCalGas is operating and expects to continue to operate under the terms and provisions of the expired franchise until a new agreement is reached. Additionally, the City of San Diego is studying the feasibility of municipalization as a potential alternative to SDG&E’s existing electric franchise agreement, and various aspects of the natural gas and electric franchise agreements granted by the City of San Diego to SDG&E have also been challenged in two lawsuits that we discuss in Note 16 of the Notes to the Consolidated Financial Statements. These approvals may not be granted in a timely manner or at all or may be modified, rescinded or fail to be extended for a variety of reasons, including due to legal or regulatory changes. Obtaining or maintaining these approvals could result in higher costs or the imposition of conditions or restrictions on our operations. Further, noncompliance by us or certain of our customers with the terms of these approvals could result in their modification, suspension or rescission and subject us to lost revenue, fines and penalties. If any of these approvals are suspended, rescinded or otherwise terminated or modified in a manner that makes our continued operation of the applicable business prohibitively expensive or otherwise impracticable, we may be required to adjust or temporarily or permanently cease certain of our operations, sell the associated assets or remove them from service and/or construct new assets intended to bypass the impacted area, in which case we may lose some of our rate base or revenue-generating assets, our development projects may be negatively affected and we may incur impairment charges or other costs that may not be recoverable. The occurrence of any of these events could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. From time to time, we invest funds in capital projects prior to receiving all regulatory approvals. If there is a delay in obtaining these approvals; if any approval is conditioned on changes or other requirements that increase costs or impose restrictions on our existing or planned operations; if we fail to obtain or maintain these approvals or comply with them or other applicable laws or regulations; if we are involved in litigation that adversely impacts any approval or rights to the applicable property or assets; or if management decides not to proceed with a project, we may be unable to recover any or all amounts invested in that project. Any such occurrence could materially increase our costs, result in material impairments, and otherwise materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Our businesses require numerous permits, licenses, rights-of-way, franchises, certificates and other approvals from federal, state, local and foreign governmental agencies. These approvals may not be granted in a timely manner or at all or may be modified, rescinded or fail to be extended for a variety of reasons. Obtaining or maintaining these approvals could result in higher costs or the imposition of conditions or restrictions on our operations. For example, SoCalGas’ franchise agreement with Los Angeles County is scheduled to expire in June 2023. Further, these approvals require compliance by us and may require compliance by our customers, which could result in modification, suspension or rescission and subject us to fines and penalties in the event of noncompliance. If one or more of these approvals were to be suspended, rescinded or otherwise terminated, including due to expiration or legal or regulatory changes, or modified in a manner that makes our continued operation of the applicable business prohibitively expensive or otherwise undesirable or impossible, we may be required to adjust or temporarily or permanently cease certain of our operations, sell the associated assets or remove them from service and/or construct new assets intended to bypass the impacted area, in which case we may lose some of our rate base or revenue-generating assets, our development projects may be negatively affected and we may incur impairment charges or other costs that may not be recoverable. The occurrence of any of these events could materially adversely affect our results of operations, financial condition, cash flows and/or prospects. We may invest funds in capital projects prior to receiving all regulatory approvals. If there is a delay in obtaining these approvals; if any approval is conditioned on changes or other requirements that increase costs or impose restrictions on our existing or

Table of Contents Table of Contents businesses, may not be able to be passed through to customers. Even if such costs are recoverable, these costs, coupled with necessary safety and reliability investments, may negatively impact the affordability of SDG&E’s and SoCalGas’ customer rates and, for our non-regulated-utility businesses, may cause costs to increase to levels that reduce customer demand and growth. SDG&E and SoCalGas, as well as any of our other businesses affected by GHG emissions mandates, may also be subject to fines and penalties if mandated renewable energy goals are not met, and all our businesses could suffer difficulties attracting investors and business partners, reputational harm and other negative effects if we do not meet or if we scale back our GHG emissions goals or there are negative views about our environmental disclosures or practices generally. The occurrence of any of these risks could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents infrastructure. Although we have developed interim targets and various plans designed to support California in reaching its GHG emissions and renewable energy mandates and our own energy goals, we may not be successful. We will need to continue to expend capital and employee resources to develop and deploy new technologies and modernize grid systems in our efforts to support the clean energy transition in California and elsewhere and achieve our climate targets and those mandated by applicable authorities, which may not be recoverable in rates or, with respect to our non-regulated utility businesses, may not be able to be passed through to customers. Even if such costs are recoverable, the costs of these efforts and complying with these mandates, coupled with the necessary costs of investing for safety and reliability, may negatively impact the affordability of SDG&E’s and SoCalGas’ customer rates and, for our non-regulated utility businesses, may cause costs to increase to levels that reduce customer demand and growth. SDG&E and SoCalGas, as well as any of our other businesses affected by GHG emissions mandates, may also be subject to fines and penalties if mandated renewable energy goals are not met, and all our businesses could suffer difficulties attracting investors and business partners, reputational harm and other negative effects if we do not meet or if we scale back our GHG emissions goals or there are negative views about our environmental disclosures or practices generally. Any of these outcomes could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

From October 23, 2015 through February 11, 2016, SoCalGas experienced the Leak, which we describe in Note 16 of the Notes to Consolidated Financial Statements. Litigation In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) then pending against SoCalGas and Sempra related to the Leak for a payment of up to $1.8 billion. Over 99% of the Individual Plaintiffs participated and submitted valid releases, and SoCalGas paid $1.79 billion in 2022 under the agreement. The Individual Plaintiffs who did not participate in the settlement (the Non-Settling Individual Plaintiffs) are able to continue to pursue their claims. As of February 20, 2024, there are approximately 100 Non-Settling Individual Plaintiffs remaining. In addition, as of February 20, 2024, new lawsuits related to the Leak on behalf of approximately 413 new plaintiffs have been filed against SoCalGas and Sempra since the September 2021 settlement. This litigation seeks compensatory and punitive damages, property damage and diminution in property value, injunctive relief and civil penalties. Additional litigation may be filed against us related to the Leak or our responses to it. The costs of defending against, settling or otherwise resolving the pending lawsuits or any new litigation could materially adversely affect SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. We discuss the risks associated with litigation above under “Risks Related to All Sempra Businesses – Legal and Regulatory Risks” and in this risk factor below under “Accounting and Other Impacts.”

From October 23, 2015 through February 11, 2016, SoCalGas experienced the Leak, which we describe in Note 16 of the Notes to Consolidated Financial Statements. Litigation In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve lawsuits filed by approximately 36,000 plaintiffs (the Individual Plaintiffs) against SoCalGas and Sempra related to the Leak resulting in a payment of approximately $1.8 billion. The Individual Plaintiffs who do not participate in that settlement (the Remaining Individual Plaintiffs) will be able to continue to pursue their claims. As of February 21, 2023, lawsuits filed by the Remaining Individual Plaintiffs and several shareholder derivative actions are pending against SoCalGas related to the Leak, some of which have also named Sempra and/or certain officers and directors of SoCalGas and Sempra. Additional litigation may be filed against us related to the Leak or our responses to it. The costs of defending against, settling or otherwise resolving the pending lawsuits or any new litigation could materially adversely affect SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. We discuss these risks above under “Risks Related to All Sempra Businesses – Legal and Regulatory Risks” and in this risk factor below under “Estimated Costs, Insurance and Accounting and Other Impacts.” Regulatory Proceedings SoCalGas has been subject to an OII to investigate and consider, among other things, what damages, fines or other penalties, if any, should be imposed against SoCalGas in connection with the Leak (the Leak OII). In October 2022, SoCalGas executed a settlement agreement with SED and the Public Advocates Office at the CPUC to resolve all aspects of the Leak OII, which is subject to CPUC approval. The settlement agreement provides for financial penalties, certain costs that SoCalGas will reimburse, a violation of California Public Utilities Code section 451, and costs previously incurred by SoCalGas for which it will not seek recovery from ratepayers, among other provisions. Other investigations related to the Leak could result in additional findings of violations of laws, orders, rules or regulations as well as fines and penalties, any of which could involve substantial costs and cause reputational damage. In addition, SoCalGas may incur higher operating costs and additional capital expenditures as a result of new investigations or new laws, orders, rules and regulations arising out of this incident, or our responses thereto, which may not be recoverable through insurance or in customer rates. The occurrence of any of these risks could materially adversely affect SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. Natural Gas Storage Operations and Reliability In February 2017, the CPUC opened a proceeding pursuant to SB 380 OII to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility while still maintaining energy and electric reliability for the region, including analyzing alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated. If the Aliso Canyon natural gas storage facility were to be permanently closed or if future cash flows from its operation were otherwise insufficient to recover its carrying value, we may record an impairment of the facility, which could be material, incur materially higher than expected operating costs and/or be required to make material additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Any such outcome could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. Cost Estimate, Insurance and Accounting and Other Impacts At December 31, 2022, SoCalGas estimates certain costs related to the Leak are $3,486 million (the cost estimate), including $1,279 million of costs recovered from insurance. Other than insurance for directors’ and officers’ liability, we have exhausted all of our insurance for this matter. We continue to pursue other sources of insurance coverage for costs related to this matter, but we may not be successful in obtaining additional insurance recovery for any of these costs. At December 31, 2022, $129 million of the cost estimate is accrued in Reserve for Aliso Canyon Costs and $4 million of the cost estimate is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Consolidated Balance Sheets. The civil litigation that remains pending against us related to the Leak seeks compensatory, statutory and punitive damages, restitution, and civil and administrative fines, penalties and other costs. We also could be subject to damages, fines or other penalties as a result of the pending regulatory investigation related to the Leak. Except for the amounts paid or estimated to settle

Table of Contents Table of Contents ▪adverse changes in social, political, economic or market conditions or the stability of foreign governments ▪adverse rulings by foreign courts or tribunals; challenges obtaining, maintaining and complying with permits or approvals; difficulty enforcing contractual and property rights; and differing legal standards ▪expropriation or theft of assets ▪demand for hydrocarbon fuels, such as natural gas imported from the U.S., may be impacted by geopolitical factors ▪with respect to our non-utility international business activities, changes in the priorities and budgets of international customers, which may be driven by many of the factors listed above, among others Mexican Government Influence on Economic and Energy Matters The Mexican government exercises significant and increasing influence over the Mexican energy sector and has adopted or proposed additional changes that, in each case, could impact private investment in this sector. Mexican governmental actions in the past several years in the electricity market include resolutions, orders, decrees, regulations and proposed and adopted amendments to Mexican law that could, among other things, threaten the prospects for private-party renewable energy generation in the country, limit the ability to dispatch renewable energy and receive or maintain operational permits, and increase costs of electricity for legacy renewables and cogeneration energy contract holders. We discuss some of these actions in Note 16 of the Notes to Consolidated Financial Statements. Moreover, reforms to centralize and de-privatize the electricity market in Mexico have been proposed previously and could be reintroduced in the future. With respect to midstream and downstream activities, Mexico’s Hydrocarbons Law gives SENER and the CRE significant powers to suspend permits when a danger to national security, energy security, or the national economy is foreseen and to revoke permits under certain other circumstances, including for a failure to comply with certain minimum storage and other requirements or for violations of certain provisions established by SENER or the Hydrocarbons Law, as applicable. If future governmental actions are proposed and passed or otherwise become effective, if efforts to enjoin enforcement or suspend or overturn adopted governmental actions fail, or if other similar actions by the Mexican government are taken to curb private-party participation in the energy sector, including through further amendments to Mexican laws, rules or the constitution or increased investigative and enforcement activities, it may impact our ability to operate our facilities at existing levels or at all, result in increased costs for Sempra Infrastructure and its customers, adversely affect our ability to develop new projects, result in decreased revenues and cash flows, and negatively impact our ability to recover the carrying values of our investments in Mexico, any of which may have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects. U.S. and Mexican Laws and Foreign Policy Our international business activities are subject to U.S. and Mexican laws and regulations related to foreign operations or doing business internationally, including the U.S. Foreign Corrupt Practices Act, the Mexican Federal Anticorruption Law in Public Contracting (Ley Federal Anticorrupción en Contrataciones Públicas) and similar laws, and are sensitive to U.S. and Mexican foreign policy, trade policy and other geopolitical factors. The current and the last U.S. Administrations have taken different stances with respect to international trade agreements, tariffs, immigration policy and other matters of foreign policy that impact trade and foreign relations. Shifts in foreign policy could create uncertainty and result in or increase adverse effects on our businesses. Violations or alleged violations of the laws referred to above, as well as foreign policy positions that adversely affect imports and exports between the U.S., Mexican and other foreign companies with which we conduct business, could materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Overview We own or have interests in a variety of energy infrastructure assets in Mexico, and we do business with companies based in foreign markets, including particularly our LNG export operations. Conducting these activities in foreign jurisdictions subjects us to complex management, security, political, legal, economic and financial risks that vary by country, many of which may differ from and potentially be greater than those associated with our wholly domestic businesses, and the occurrence of any of these risks could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. These risks include the following and the other risks discussed in this risk factor below: ▪compliance with tax, trade, environmental and other foreign laws and regulations, including legal limitations on ownership in some foreign countries and inadequate or inconsistent enforcement of regulations ▪actions by local regulatory bodies, including setting rates and tariffs that may be earned by or charged to our businesses ▪adverse changes in social, political, economic or market conditions or the stability of foreign governments ▪adverse rulings by foreign courts or tribunals; challenges to or difficulty obtaining, maintaining and complying with permits or approvals; difficulty enforcing contractual and property rights; differing legal standards for lawsuits or other proceedings; and unsettled property rights and titles in Mexico ▪expropriation or theft of assets ▪with respect to our non-utility international business activities, changes in the priorities and budgets of international customers, which may be driven by many of the factors listed above, among others Mexican Government Influence on Economic and Energy Matters The Mexican government exercises significant and increasing influence over the Mexican economy and energy sector and has adopted or proposed additional changes that, in each case, could fundamentally impact private investment in this sector. Mexican governmental actions in the past several years in the electricity market include resolutions, orders, decrees, regulations and proposed and adopted amendments to Mexican law that could, among other things, threaten the prospects for private-party renewable energy generation in the country, limit the ability to dispatch renewable energy and receive or maintain operational permits, and increase costs of electricity for legacy renewables and cogeneration energy contract holders. The President of Mexico also proposed constitutional reform in September 2021 that would have eliminated the wholesale electricity market in Mexico and significantly limited the ability of private parties to participate in electricity generation. Although the proposed constitutional reform did not reach the two-third majority required for its approval and was therefore rejected by Mexico’s Chamber of Deputies, other similar reforms to centralize and de-privatize the electricity market in Mexico could be proposed in the future. With respect to midstream and downstream activities, amendments to Mexico’s Hydrocarbons Law that give SENER and the CRE additional powers to suspend and revoke permits became effective in May 2021. The amendments provide that suspension of permits will be determined by SENER or the CRE when a danger to national security, energy security, or the national economy is foreseen, and also provide new grounds for the revocation of permits under certain other circumstances related to a permit holder’s use of illegally imported products, failure to comply with provisions applicable to quantity, quality and measurement of products, or unauthorized modification of the technical condition of its infrastructure. Additionally, the amendments direct authorities to revoke permits that fail to comply with certain minimum storage and other requirements or violate provisions established by SENER or the amended Hydrocarbons Law, as applicable. We discuss these Mexican governmental actions in Note 16 of the Notes to Consolidated Financial Statements. We cannot predict whether proposed governmental actions will ultimately be passed or otherwise become effective in their current forms, nor can we predict the nature or level of their impact on the various segments of the energy sector in which we participate. We also cannot predict whether pending actions to enjoin enforcement or suspend or overturn existing laws and other governmental actions will be successful. More generally, we cannot predict the impact that the political, social and judicial landscape in Mexico will have on that country’s economy and energy sector and our business in Mexico. If any of the proposed governmental actions are passed or otherwise become effective, if efforts to enjoin enforcement or suspend or overturn adopted governmental actions fail, or if other similar moves by the Mexican government are taken to curb private-party participation in the energy sector, including through further amendments to Mexican laws, rules or the constitution or increased investigative and enforcement activities, it may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, may result in decreased revenues and cash flows, and may

The markets in which we operate are characterized by numerous capable competitors, many of which have extensive and diversified development and/or operating experience domestically and internationally and financial resources similar to or greater than ours. In particular, the natural gas pipeline, storage and LNG market segments recently have been characterized by strong and increasing competition for winning new development projects and acquiring existing assets. These competitive factors could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

The markets in which we operate are characterized by numerous strong and capable competitors, many of which have extensive and diversified development and/or operating experience domestically and internationally and financial resources similar to or greater than ours. In particular, the natural gas pipeline, storage and LNG market segments recently have been characterized by strong and increasing competition for winning new development projects and acquiring existing assets. In addition, our Mexican natural gas distribution business faces increased competition now that its former exclusivity period with respect to its distribution zones has expired and other distributors are legally permitted to build and operate natural gas distribution systems and compete to attract customers in the locations where it operates. These competitive factors could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

We are subject to complex tax and accounting requirements. These requirements may undergo changes at the federal, state, local and foreign levels, including in response to economic or political conditions. Compliance with these requirements, including in the event of changes to them or how they are implemented, interpreted or enforced, could increase our operating costs and materially adversely affect how we conduct our business. New tax legislation, regulations or interpretations or changes in tax policies in the U.S., Mexico or other countries in which we operate or do business could negatively affect our tax expense and/or tax balances and our businesses generally. Any failure to comply with these requirements could subject us to fines and penalties, including criminal penalties in some cases. The occurrence of any of these risks could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

The electric power and natural gas industries are subject to numerous governmental regulations, and our businesses are also subject to complex tax and accounting requirements. These regulations and requirements may undergo changes at the federal, state, local and foreign levels, including in response to economic or political conditions. Compliance with these regulations and requirements, including in the event of changes to them or how they are implemented, interpreted or enforced, could increase our operating costs and materially adversely affect how we conduct our business. New tax legislation, regulations or interpretations or changes in tax policies in the U.S. or other countries in which we operate or do business could negatively affect our tax expense and/or tax balances and our businesses generally. Any failure to comply with these regulations and requirements could subject us to fines and penalties, including criminal penalties in some cases, and result in the temporary or permanent shutdown of certain facilities or operations. The occurrence of any of these risks could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Our operations are subject to rules relating to transactions among SDG&E, SoCalGas and other Sempra businesses. These rules are commonly referred to as “affiliate rules,” and they primarily impact transmission supply, capacity and marketing activities, including restricting our ability to sell natural gas or electricity to, or trade with, SDG&E and SoCalGas and their ability to complete these transactions with each other. These rules, as well as any changes to these rules or their interpretations or additional more restrictive CPUC or FERC rules related to transactions with affiliates, could materially adversely affect our operations and, in turn, our results of operations, financial condition, cash flows and/or prospects.

We are engaged in disputes regarding our title to the property in Mexico where our ECA Regas Facility is situated and our ECA LNG projects are expected to be situated, which we discuss in Note 16 of the Notes to Consolidated Financial Statements. In addition, we may have or seek to obtain long-term leases or rights-of-way from governmental agencies or other third parties to operate our energy infrastructure on land we do not own. In addition to the risks associated with such property ownership and use that we describe above under “Risks Related to All Sempra Businesses – Operational Risks,” disputes regarding ownership or rights to any of these properties could lead to difficulties finding or maintaining suitable partners, customers and project financing arrangements and could hinder or halt our ability to construct and, if completed, operate the affected facilities or proposed projects. Any of these outcomes could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

We are engaged in disputes regarding our title to the property in Mexico where our ECA Regas Facility is situated and our ECA LNG projects under construction and in development are expected to be situated, which we discuss in Note 16 of the Notes to Consolidated Financial Statements. In addition, we may have or seek to obtain long-term leases or rights-of-way from governmental agencies or other third parties to operate our energy infrastructure on land we do not own. In addition to the risks associated with such property ownership and use that we describe above under “Risks Related to All Sempra Businesses – Operational Risks,” disputes regarding any of these properties could lead to difficulties finding or maintaining suitable partners, customers and project financing arrangements and could hinder or halt our ability to construct and, if completed, operate the affected facilities or proposed projects. Any of these outcomes could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Sempra Infrastructure’s energy infrastructure assets may be considered by the Mexican government to be a public service or essential for the provision of a public service, in which case these assets and the related businesses could be subject to expropriation or nationalization, loss of concessions, renegotiation or annulment of existing contracts, and other similar risks. Any such occurrence could materially adversely affect our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents Any actual or perceived instability in our future direction, inability to execute our strategies, or changes in our board of directors or management team arising from activist shareholder campaigns could be exploited by our competitors and/or other activist shareholders, result in the loss of business opportunities, and make it more difficult to pursue our strategic initiatives or attract and retain qualified personnel and business partners, any of which could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents incur legal and advisory fees, proxy solicitation expenses and administrative and associated costs and require time and attention by our board of directors and management, diverting their attention from the pursuit of our business strategies. Any perceived uncertainties about our future direction or control, our ability to execute our strategies, or the composition of our board of directors or management team arising from activist shareholder attention or other action could lead to a perception of instability or a change in the direction of our business, which could be exploited by our competitors and/or other activist shareholders, result in the loss of business opportunities, and make it more difficult to pursue our strategic initiatives or attract and retain qualified personnel and business partners, any of which could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Further, any such actions could cause fluctuations in the trading prices of our securities based on temporary or speculative market perceptions or other factors.

Table of Contents Table of Contents The capital requirements for our LNG export projects can be significant, even if we ultimately decide not to make a positive final investment decision. In addition, our proposed facilities may not be completed in accordance with estimated timelines or budgets or at all as a result of the above or other factors, and delays, cost overruns or our inability to complete one or more of these projects could have a material adverse effect on our results of operations, financial condition, cash flows and/or prospects. Financing Arrangements We are and may continue to become involved in various financing arrangements with respect to our energy infrastructure projects, including guarantees, indemnities and loans. These arrangements could expose us to additional risks, including exposure to losses upon the occurrence of certain events related to the development, construction, operation or financing of the applicable projects, which could have a material adverse effect on our future results of operations, financial condition, cash flows and/or prospects.

Table of Contents Table of Contents Financing Arrangements We may become involved in various financing arrangements with respect to any of our energy infrastructure projects, such as guarantees, indemnities or loans. These arrangements could expose us to additional risks, including exposure to losses upon the occurrence of certain events related to the development, construction, operation or financing of the applicable projects that could have a material adverse effect on our future results of operations, financial condition, cash flows and/or prospects.