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SCANA

SCANA Corporation was a South Carolina-based established in 1984, primarily engaged through its subsidiaries in the , , , and sale of , as well as utility operations and related energy businesses. Headquartered in , it owned key subsidiaries such as South Carolina Electric & Gas Company (SCE&G) and Public Service Company of (PSNC Energy), serving millions of customers across the region. The company achieved scale as a major regional utility provider but encountered its most defining controversy through participation in the expansion of the V.C. Summer Station, a with to construct two new reactors, which suffered from chronic delays, escalating costs exceeding $9 billion, and culminated in project abandonment in July 2017 following the bankruptcy of lead contractor . This failure triggered enforcement actions alleging that SCANA executives misled investors about project viability to sustain stock prices and issue over $1 billion in bonds, resulting in civil penalties, , and customer ratepayer burdens persisting years later through surcharges on electric bills. Facing insolvency risks and shareholder dilution, SCANA pursued and completed an all-stock merger with in January 2019 for approximately $13.4 billion in value, integrating its assets into the larger utility while providing regulatory commitments for customer relief and ceasing independent operations as SCANA became a wholly owned .

Overview

Corporate Structure and Primary Operations

SCANA functioned as a Carolina-based , incorporated in 1984, that owned the capital stock of its subsidiaries either directly or indirectly, conducting substantially all operations through these entities. Its primary business focused on regulated electric and utilities, with additional non-regulated energy-related activities. Key subsidiaries included Electric & Gas Company (SCE&G), the principal operating utility handling electric generation, transmission, distribution, and sales in , as well as distribution there; Public Service Company of , Inc. (PSNC Energy), which managed distribution in ; and others such as South Carolina Generating Company, Inc. (GENCO) for power generation assets and SCANA Energy Marketing, Inc. (SEMI) for gas marketing. SCE&G served approximately 664,000 electric customers and 317,000 customers across 24 counties spanning about 17,000 square miles in as of December 31, 2011, with generation capacity from , , , hydroelectric, and sources. PSNC Energy distributed to roughly 487,000 customers in 28 counties covering 12,000 square miles. Supporting infrastructure included Carolina Gas Transmission Corporation for interstate pipelines in and southeastern , while SEMI's SCANA Energy division marketed to over 455,000 residential and commercial customers in , capturing about 30% of the deregulated market there. Non-regulated segments encompassed marketing and services via SCANA Communications, Inc., though regulated utilities formed the core of operations, with electric and gas distribution benefiting from rate mechanisms for stability and recovery. Following a $13.4 billion all-stock merger completed on January 2, 2019, SCANA became a wholly owned of , Inc., with SCE&G and PSNC Energy integrated into Dominion's operations while retaining their utility functions.

Financial and Regulatory Context

SCANA Corporation functioned as a public utility holding company under the Public Utility Holding Company Act of 2005, with its financial results predominantly derived from regulated subsidiaries, including Electric & Gas Company (SCE&G), which generated revenues through electric and distribution in . The company's emphasized cost-of-service , allowing recovery of operating expenses, , and a return on invested capital, subject to state commission approvals. In the first nine months of 2017, SCANA reported consolidated earnings of $326 million, or $2.28 per share, though full-year results reflected substantial losses tied to nuclear project overruns, with SCE&G alone posting a $172 million net loss. Total levels reached $7.367 billion by early 2017, reflecting from investments. The 2019 merger with , valued at approximately $14.6 billion including assumed debt of $6.9 billion, marked a pivotal financial restructuring, transitioning SCANA's operations into Dominion's portfolio and enabling rate reductions for SCE&G customers, such as a typical residential electric bill drop to $124.91 starting February 2019. This all-stock transaction, approved by regulators, absorbed SCANA's liabilities from the failed V.C. Summer project and shifted oversight to Dominion's framework, though legacy regulatory proceedings continued. Regulatorily, SCANA's subsidiaries operated under a traditional cost-based framework enforced by the Public Service Commission (), which set retail rates, reviewed rate cases, and evaluated the prudence of capital expenditures like generation projects. Federal jurisdiction fell to the () for interstate transmission pricing and wholesale power markets, ensuring non-discriminatory access, while the () governed nuclear plant licensing, operations, and safety compliance for facilities like V.C. Summer. This multi-layered oversight aimed to balance utility recovery with , with 's environment historically rated as constructive for credit stability prior to major project failures.

History

Founding and Early Expansion (1840s–1980s)

The origins of SCANA Corporation trace to the mid-19th century, when independent companies emerged in to support urban growth amid industrialization. In 1846, a group of business leaders established the Charleston Gas Light Company, the earliest predecessor, to provide manufactured gas for street and residential illumination in the port city. This venture capitalized on coal-based gas production techniques imported from , serving approximately 200 customers by the late despite challenges from the era's rudimentary . Six years later, in 1852, the Gas Light Company was founded in the state capital, mirroring Charleston's model and expanding gas services to meet rising demand from commerce and households until disruptions from the . The war (1861–1865) severely impacted operations, with federal occupation in Charleston and destruction in Columbia halting production and requiring postwar reconstruction. By the late , these gas entities began integrating generation as advanced, driven by technological innovations like the . In 1886, the Charleston Electric Light formed as a competitor to the gas firm, introducing arc lighting for streets. Consolidation accelerated: the 1892 creation of the Columbia Electric Street Railway, Light and Power unified electric lighting, power, and trolley services in Columbia, while 1897 saw the merger into the Charleston Consolidated Railway, Gas and Electric , combining gas, electric, and rail operations across five Charleston utilities. A pivotal early occurred in 1894, when the Columbia Water Power 's Saluda powerhouse enabled the world's first long-distance transmission of electricity to drive a mill, demonstrating hydroelectric potential in the region. The early 20th century marked aggressive expansion through acquisitions and hydroelectric development to electrify rural areas and support industrial growth. In 1925, the Broad River Power Company acquired the Railroad, Gas and Electric Company, bolstering its portfolio in electric generation and distribution. The following year, 1926, the Power Company was formed by merging those five Charleston-based utilities, including the Consolidated entity, to pursue broader efforts. scaled significantly; in 1930, the Lexington Power Company (later acquired) completed the world's largest earth-filled dam on the , generating 180 megawatts for regional power needs. By 1937, the Broad River Power Company rebranded as Electric & Gas Company (SCE&G), centralizing electric and gas operations under a unified structure serving central and southwestern . Post-World War II mergers solidified SCE&G's dominance. In 1942, it absorbed the Lexington Water Power Company, expanding hydroelectric assets; this was followed by the 1950 merger with South Carolina Power Company, retaining the SCE&G name and enhancing coastal service territories. In 1946, SCE&G achieved independence and became the first South Carolina firm listed on the New York Stock Exchange, reflecting financial maturity with assets exceeding $100 million by the 1950s. Fuel transitions supported growth: by 1954, full conversion to natural gas from Gulf Coast sources replaced manufactured gas, improving efficiency and reliability for over 200,000 customers. Nuclear ambitions emerged in the late 1950s, with SCE&G joining three utilities in 1959 to construct the Southeast's first commercial nuclear plant at Parr Shoals, operational by 1962 at 17 megawatts. Into the 1970s and early 1980s, SCE&G pursued large-scale generation to meet surging demand from and . Licensing for the Virgil C. Summer Nuclear Station began in 1971 with , followed by construction start in 1973, aiming for 900-megawatt capacity to diversify from fossil fuels amid oil crises. By the early 1980s, SCE&G operated 14 hydroelectric plants, multiple coal-fired stations, and the Parr nuclear unit, serving 500,000 electric and 250,000 gas customers across 21,000 square miles, with annual revenues surpassing $1 billion. These developments positioned the company for the 1984 holding company formation as SCANA, though early expansion emphasized regulated utility integration over diversification.

Diversification and Growth (1990s–2000s)

In the early 1990s, SCANA pursued growth through expansion into and to capitalize on deregulated markets. In 1990, SCANA Resources acquired Texas gas reserves from Tri-C Resources Inc. for $29 million, adding 12 million cubic feet of daily production capacity. This was followed in February 1991 by the purchase of offshore gas reserves from LLOG Co. for $16 million, and in June 1993, the acquisition of NICOR and Co., which increased reserves to 283 billion cubic feet across , , and . However, by October 1997, SCANA divested this unit, selling SCANA Resources to Kelley Oil & Gas Corp. for $110 million, refocusing away from upstream . Amid broader , SCANA diversified into marketing and non-regulated services. In 1998, the company entered the Atlanta, , market, rapidly expanding to serve 300,000 customers by May 1999 with ambitions to reach 700,000 through $3 million in advertising and infrastructure investments. This venture proved profitable, generating $4.4 million in operations by 2000, and culminated in June 2002 when SCANA became the state's official regulated provider for low-income customers. Additionally, in 1999, SCANA sold its retail assets for $86 million to streamline operations. SCANA also ventured into , leveraging for fiber optics and services. By 1994, MPX Systems operated 1,600 miles of with plans for over 33% expansion. In March 1996, SCANA invested $75 million in InterCel to develop a personal communications services () network across the Southeast. This stake grew in June 1998 with an additional $75 million acquisition of shares in Powertel, InterCel's successor, increasing ownership to nearly 30%. By the late , SCANA's fiber optic investments spanned 12 states, supporting communications alongside energy-related businesses. A pivotal expansion occurred in February 2000 when SCANA acquired Public Service Company of (PSNC) for approximately $900 million, effectively doubling its customer base to over one million across the . This transaction, completed on February 10, 2000, enhanced SCANA's regional footprint in gas distribution and , aligning with synergies in the Southeast energy sector. These moves reflected SCANA's strategy to balance regulated utilities with growth in competitive markets, though non-utility ventures like faced varying market challenges.

Nuclear Ambitions and the V.C. Summer Project (2010s)

In the early , SCANA Corporation, via its principal subsidiary Electric & Gas (SCE&G), pursued expansion as a strategic response to projected electricity demand growth in and a push toward reliable, low-emission baseload generation. The company targeted the existing Virgil C. Summer Nuclear Generating Station near Jenkinsville for two additional units (Units 2 and 3), employing Electric Company's reactor design—a Generation III+ featuring passive safety systems. This initiative represented SCANA's commitment to diversifying its generation portfolio beyond and , with SCE&G holding a 55% ownership stake alongside Santee Cooper's 45%. The U.S. granted a combined and operating license () for Units 2 and 3 in March 2012, following SCE&G's application submitted in 2008 and enabled by the federal Energy Policy Act of 2005's loan guarantees for advanced projects. commenced on March 9, 2013, with the pouring of first for the of Unit 2, initiating site preparation, foundation work, and modular component fabrication. Initial cost projections totaled approximately $14 billion for both units, with SCE&G's share estimated at $6.3 billion as of March 2009, and anticipated commercial operation dates of April 2016 for Unit 2 and January 2019 for Unit 3. Progress through the mid-2010s involved overcoming first-of-a-kind engineering hurdles for the , including NRC-mandated design modifications for seismic and safety compliance, supply chain disruptions for specialized forgings, and extensive workforce training programs in collaboration with local colleges. By , revised estimates pegged total costs at $9.8 billion amid schedule slips of up to two years, driven by these complexities and integration challenges with the existing Unit 1 operations. Further escalations emerged in 2016, with costs climbing toward $14 billion and completion deferred beyond 2020, as cumulative delays compounded from iterative issues and vendor performance shortfalls. The project's trajectory unraveled in 2017 when filed for Chapter 11 bankruptcy on March 29, citing overruns exceeding $6 billion across V.C. Summer and the concurrent Vogtle project in . Lacking a viable and facing projected total costs surpassing $25 billion with units only about 30% complete after $9 billion expended, SCE&G and halted construction on July 31, 2017, abandoning further development. This outcome dashed SCANA's nuclear expansion goals, shifting focus to alternative generation sources amid heightened scrutiny of and cost controls.

Operations and Subsidiaries

Key Utility Divisions

South Carolina Electric & Gas Company (SCE&G), SCANA's principal regulated subsidiary, operated as a vertically integrated responsible for the generation, transmission, , and sale of electricity to approximately 720,000 customers across central, southern, and southwestern as of late 2018. SCE&G also provided services to around 291,000 customers in overlapping territories within the state, leveraging a mix of owned generation assets including , , , and hydroelectric facilities to meet . These operations were subject to rate regulation by the South Carolina Public Service Commission, with SCE&G maintaining a focus on reliability and investments to support growing residential, commercial, and industrial loads. Public Service Company of (PSNC Energy), another core regulated subsidiary acquired by SCANA in 2005, functioned exclusively as a local company serving more than 550,000 customers across 28 counties in north-central as of September 2017. PSNC Energy purchased from interstate pipelines, transported it through its system, and sold it at retail to residential, , and end-users, while also offering services to larger customers. Regulated by the Utilities Commission, PSNC utilized mechanisms such as a cost-of-service adjustment rider to recover fuel costs semi-annually for certain customer classes, emphasizing expansion in underserved areas and upgrades to accommodate annual customer growth exceeding 2 percent. These divisions formed the backbone of SCANA's regulated earnings, contributing the majority of the holding company's through service territories and stable rate bases, distinct from SCANA's smaller non-utility ventures in energy marketing and . Prior to the 2019 acquisition by , SCE&G and PSNC collectively supported over 1.6 million electric and accounts, underscoring SCANA's regional dominance in the Carolinas' utility sector.

Infrastructure and Service Territories

SCANA's electric services were primarily delivered through its subsidiary South Carolina Electric & Gas (SCE&G), which operated a vertically integrated including , , and serving 24 counties across nearly 17,000 square miles in central, southern, and southwestern . This territory supported approximately 620,000 retail electric customers, with facilitating bulk power delivery to local networks. SCE&G's natural gas infrastructure encompassed local distribution pipelines covering more than 23,000 square miles in all or parts of 35 of South Carolina's 46 counties, serving residential, commercial, and industrial users through regulated operations. In , SCANA provided distribution via PSNC Energy, whose franchised service area included 28 counties spanning roughly 12,000 square miles, with pipeline networks designed for stable cash flows under regulatory mechanisms like revenue decoupling. SCANA Energy, focused on natural gas marketing rather than owned distribution infrastructure, operated in Georgia's deregulated market, providing supply services to residential and commercial customers throughout the state via competitive contracts with local distribution companies.

Controversies and Failures

The V.C. Summer Nuclear Expansion Debacle

The V.C. Summer Nuclear Generating Station expansion involved constructing two AP1000 reactors, Units 2 and 3, at the existing facility near Jenkinsville, South Carolina, led by SCANA subsidiary South Carolina Electric & Gas (SCE&G) in partnership with Santee Cooper. Announced in 2008 under state legislation enabling advanced cost recovery for new baseload generation, the project aimed to add over 2,200 megawatts of capacity to meet growing demand and reduce emissions, with initial commercial operation targeted for 2016. Construction contracts were awarded to Westinghouse Electric Company in 2013, but the effort quickly encountered engineering challenges inherent to the unproven AP1000 design, including supply chain disruptions and quality control failures. By 2015, costs had escalated beyond initial projections of $2.2 billion per unit due to repeated delays, workforce inefficiencies, and design revisions mandated by the , prompting SCE&G to seek multiple rate hikes under the Base Load Review Act, which allowed recovery of construction expenses from customers during building. , strained by parallel overruns at Georgia's Vogtle project, faced mounting financial pressure, culminating in its Chapter 11 bankruptcy filing on March 29, 2017, which halted critical equipment deliveries and subcontractor payments at V.C. Summer. Without a viable prime , project completion timelines extended indefinitely, with revised cost estimates reaching $9 billion spent by mid-2017 against uncertain total expenditures potentially exceeding $20 billion. On July 31, 2017, SCE&G and jointly abandoned the expansion, citing prohibitive completion costs, unresolved issues, and the absence of federal loan guarantees to mitigate risks, leaving approximately $9 billion in sunk expenditures—primarily on incomplete foundations and infrastructure—for which ratepayers had already financed over $2 billion through surcharges. The decision triggered immediate regulatory scrutiny from the Public Service Commission, which had approved interim rate recoveries based on optimistic progress reports, and exposed systemic flaws in the state's financing model, including overreliance on untested modular and inadequate provisions. Subsequent investigations revealed that executive assurances of project viability, used to justify ongoing funding, masked deteriorating fundamentals, contributing to SCANA's stock value halving within days of the announcement.

Executive Deception and Regulatory Lapses

SCANA executives overseeing the V.C. Summer expansion project systematically provided false and misleading statements to the () to secure regulatory approval for customer rate increases totaling over $1.4 billion between 2010 and 2017. These increases, which raised residential bills by approximately 25% over several years, were justified by claims of steady project progress and adherence to timelines for federal production tax credits, despite internal knowledge of severe delays, cost overruns exceeding $9 billion total, and a 2015 analysis highlighting fundamental construction flaws that executives withheld from regulators. In January 2019, the PSC formally ruled that SCANA subsidiary South Carolina Electric & Gas (SCE&G) acted "imprudently" through deliberate deception, including omissions about the project's unlikelihood of meeting deadlines for tax incentives and exaggerated assurances of completion. Former CEO Kevin Marsh, who led SCANA from 2012 until the project's abandonment in July 2017 following Westinghouse's bankruptcy, pleaded guilty in February 2021 to conspiracy to commit mail and wire fraud for directing subordinates to submit falsified progress reports and financial projections to the PSC and investors. Marsh was sentenced to two years in federal prison in October 2021, with the court noting his actions defrauded ratepayers to sustain executive bonuses tied to stock performance and project milestones. Other executives faced similar accountability: Stephen Byrne, who managed nuclear operations, pleaded guilty to the same federal charge and received a 15-month sentence in March 2023 for participating in the scheme to misrepresent project viability. Senior Vice President Bruce Hughes was sentenced to 18 months in 2022, and construction executive Benjamin received 24 months in November 2024, both for contributing to false statements that propped up SCANA's stock price and enabled bond issuances exceeding $1 billion. Regulatory lapses compounded the deception, as the approved 17 rate hikes without sufficient independent verification of SCANA's submissions, relying on utility-provided data amid conflicts of interest, including commissioners with ties to the energy sector. In response to the , the House voted 108-1 in February 2018 to remove all seven PSC members over two years, citing failures in oversight that allowed the fiasco to burden ratepayers with costs for an unfinished project. Investigations revealed no PSC-mandated audits or third-party assessments of construction milestones, enabling executives to conceal that Units 2 and 3 were only 30-40% complete at abandonment despite billed progress claims nearing 70%.

Customer and Investor Impacts

The failure of the V.C. Summer nuclear expansion project imposed substantial financial burdens on Electric & Gas (SCE&G) customers, primarily through rate increases enabled by the state's 2007 Energy Freedom Act, which authorized upfront recovery of construction costs via the Charge mechanism starting in 2010. SCE&G, holding a % in the project, passed ongoing expenses to ratepayers as costs escalated from initial estimates, with customers collectively funding billions in expenditures before the July 31, 2017, abandonment announcement. Following the halt, the Public Service Commission initially permitted recovery of some abandonment costs, prompting legislative intervention; on February 28, 2018, the state House voted 119-1 to suspend $37 million in monthly customer payments to SCANA pending further review. Customer relief materialized through settlements mitigating the passed-through costs. In November 2018, SCANA agreed to a $2 billion class-action settlement with SCE&G ratepayers, structured as bill credits and rate reductions to offset charges for the uncompleted reactors. A state judge finalized an expanded $2.2 billion agreement in June 2019, distributing up to $146 million in direct cash refunds to eligible current and former customers, the largest such recovery in state history, while additional rate base adjustments provided ongoing savings estimated at over $1 billion through 2023. Despite these measures, legacy obligations persisted post-merger with , with some ratepayers facing elevated bills into 2024 to service remaining debt tied to the project's $9 billion total spend, though per-customer impacts varied by usage and timing of service. Investors suffered acute losses as project mismanagement and delayed disclosures eroded SCANA's . The , trading above $70 per share in early , plummeted following revelations of severe delays and overruns, closing the class-action period at $37.39 per share after the abandonment disclosure triggered a multi-day sell-off. SCANA reported a $445 million net loss for the fourth quarter of —versus $124 million earnings the prior year—reflecting writedowns and regulatory uncertainties that halved the company's within months. Shareholder lawsuits alleged executives misled investors on project viability to sustain stock prices and secure financing, leading to a $192.5 million class-action approved by the U.S. for the of on July 9, 2020, compensating affected investors for securities violations. The SEC separately charged SCANA with fraud for false progress reports, resulting in a $137.5 million civil in 2020, including and penalties, underscoring how inflated disclosures had artificially propped up investor confidence until the bankruptcy exposed the $6 billion-plus overruns. These events culminated in Dominion Energy's $14.6 billion acquisition of SCANA, announced January 3, 2018, which included $1.3 billion in customer refunds but marked the end of SCANA as an independent entity amid sustained shareholder value destruction.

Merger and Acquisition by Dominion Energy

Deal Negotiations and Regulatory Hurdles

Following the cancellation of the V.C. Summer expansion in July 2017, SCANA faced severe financial distress, lawsuits, and regulatory scrutiny over cost overruns and rate hikes imposed on customers, prompting to initiate acquisition discussions as a means to stabilize the utility and provide ratepayer relief. On January 3, 2018, and SCANA announced an all-stock merger agreement valued at approximately $14.6 billion, under which SCANA s would receive 0.6690 shares of per SCANA share, representing a 28% premium over SCANA's closing price on January 2, 2018. The deal included 's commitment to fund $1.3 billion in cash refunds to Electric & Gas (SCE&G) customers within 90 days of closing—equivalent to about $1,000 for the average residential electric customer—as partial mitigation for the project's fallout, alongside promises of rate freezes and reductions totaling up to $6.7 billion in customer savings over a decade. The merger required approvals from multiple regulatory bodies, including the (FERC), the South Carolina Commission (PSC), the North Carolina Utilities Commission, the Georgia Commission, and SCANA shareholders, with hurdles centered on ensuring adequate protection for ratepayers burdened by SCANA's mismanagement of the V.C. Summer project. Early approvals included Georgia PSC clearance on March 21, 2018, which found no adverse impact on or rates in that state. FERC authorized the transaction on July 13, 2018, determining it would not harm wholesale , rates, or regulation, though it noted potential vertical concerns were mitigated by conditions. The North Carolina Utilities Commission approved the deal on November 20, 2018, as the sixth of seven major hurdles, with minimal conditions given limited direct impacts in that jurisdiction. The most significant regulatory obstacle was the South Carolina PSC, where public hearings revealed intense opposition from consumer advocates, legislators, and ratepayers demanding greater refunds and accountability for the nuclear debacle's $9 billion in sunk costs passed to customers via base rate adjustments. Dominion resisted calls for deeper rate cuts, warning during negotiations and hearings that excessive demands—such as full project cost absorption without federal tax benefits—could lead to deal termination, as the merger's value to Dominion hinged on utilizing SCANA's net operating loss carryforwards and avoiding unlimited liability for the failed project. After evidentiary hearings and over an hour of debate on December 14, 2018, the PSC approved the merger on December 17, 2018, by a 6-1 vote, imposing conditions for phased rate reductions (e.g., a 6.4% cut in 2019) and bill credits but rejecting broader demands to preserve the deal's viability. SCANA shareholders approved the transaction in October 2018, clearing the final prerequisite. These negotiations and approvals were shaped by SCANA's weakened position post-scandal, with leveraging its financial strength to extract favorable terms while offering sufficient customer concessions to gain regulatory buy-in, though critics argued the deal shielded SCANA executives from fuller accountability amid ongoing federal investigations. The process highlighted tensions between stabilizing utility operations and addressing ratepayer grievances, ultimately enabling closure on January 2, 2019, with SCANA operating as a subsidiary headquartered in .

Completion and Immediate Aftermath

The merger between and SCANA Corporation was completed on January 2, 2019, following regulatory approvals from the Public Service Commission on December 14, 2018, and other bodies. Dominion Energy acquired SCANA in an all-stock transaction valued at approximately $7.9 billion, issuing 95.6 million shares to SCANA shareholders, with SCANA operating thereafter as a wholly owned while retaining local management and community presence in . Although the merger agreement had initially proposed a $1.3 billion cash payment to Electric & Gas (SCE&G) customers—equivalent to about $1,000 for the average residential electric customer—within 90 days of closing, this direct refund was not implemented following the final regulatory conditions. Instead, immediate post-merger benefits materialized through bill reductions: SCE&G electric customers received lower rates starting with February 2019 bills, including a 6.8% decrease, followed by further adjustments in May 2019 for fuel costs and demand-side management riders, resulting in cumulative savings of approximately 15% on average bills. customers of Company of South Carolina (PSNC), another SCANA subsidiary, were allocated $2.45 million in total bill credits over three years, averaging $1.07 per residential customer annually. Dominion Energy assumed financial responsibility for the abandoned V.C. Summer nuclear project costs, forgoing recovery of about $105 million in certain assets and committing support for $2 billion in refunds and restitution over 20 years through SCE&G, as mandated by regulators. The acquisition expanded 's footprint into and the , integrating SCANA's 1.5 million electric and 400,000 into its operations without immediate service disruptions. Shareholder reactions were mixed, with SCANA's stock having declined prior to closing amid the , but the deal provided tax-deferred exchange benefits for SCANA investors receiving shares.

Legal Proceedings and Settlements

Criminal Charges Against Executives

In the wake of the V.C. Summer project's abandonment on July 31, 2017, federal and state prosecutors charged SCANA executives with for deliberately misleading the Public Service Commission (PSC), ratepayers, and investors about construction progress to secure ongoing rate increases through Base Load Construction Work in Progress (BLW CWIP) approvals, which ultimately extracted over $1 billion from customers for a failed endeavor. Kevin , SCANA's president and CEO from 2010 to 2017, pleaded guilty on February 24, 2021, in U.S. District Court to one count of to commit , admitting he orchestrated deceptions—including false assurances on project milestones and timelines—to sustain rate hikes benefiting SCANA financially while concealing escalating delays and cost overruns. On the same date, Marsh entered a guilty in state court to one count of obtaining goods or services by for similar nondisclosures to the . U.S. District Judge Terry L. Wooten sentenced him on October 7, 2021, to two years in , followed by three years of supervised release and $1.218 million in restitution; the state sentence of two years ran concurrently. Marsh cooperated with investigators post-plea, providing that implicated others in the scheme. Stephen , SCANA's executive vice president of new nuclear development from 2013 to 2017, pleaded guilty on July 28, 2020, to one count of conspiracy to commit wire fraud for his role in fabricating progress reports and withholding critical information from regulators to perpetuate BLW CWIP . Wooten initially sentenced Byrne on , 2023, to 15 months in , three years supervised release, and $500,000 restitution, emphasizing the betrayal of . However, in January 2025, following a successful appeal citing sentencing guideline errors, Byrne's term was vacated, resulting in and home detention instead. These convictions stemmed from a joint FBI-state investigation revealing systemic efforts by executives to prioritize corporate gains over transparency, with prosecutors arguing the enabled SCANA to bill ratepayers prematurely for unviable amid known failures at the Westinghouse-led site. No additional SCANA executives faced federal charges, though the cases highlighted regulatory oversight gaps that allowed prolonged deception.

Civil Lawsuits and Financial Penalties

In February 2020, the U.S. Securities and Exchange Commission filed a civil enforcement action against SCANA Corporation and Electric & Gas (SCE&G), alleging that the companies violated antifraud provisions of the and the by issuing false and misleading statements about the construction progress, cost overruns, and regulatory approval risks of the V.C. Summer nuclear expansion project between 2014 and 2017. These disclosures allegedly concealed delays, escalating costs exceeding $1 billion beyond initial estimates, and internal assessments questioning project viability, leading investors to overvalue SCANA stock. On December 2, 2020, SCANA settled the case without admitting or denying the findings, agreeing to a permanent against future violations and paying a $25 million ; SCANA and SCE&G also disgorged $112.5 million in ill-gotten gains plus prejudgment interest, with the disgorgement offset by funds distributed in parallel shareholder litigation. Multiple shareholder class actions were consolidated in the U.S. District Court for the District of as In re SCANA Corporation Securities Litigation, accusing SCANA executives of by overstating project milestones and understating risks during the class period from October 27, 2015, to December 20, 2017, which artificially inflated the company's stock price before its sharp decline following project abandonment. The suits targeted misrepresentations to the Commission of regarding completion timelines and cost recovery assurances. In July 2020, the court approved a $192.5 million all-cash settlement funded primarily by insurance carriers and (SCANA's successor post-merger), providing recovery to affected investors without admission of liability by defendants. Ratepayer class actions, including one initiated by residents and supported by the , challenged SCANA and SCE&G's recovery of over $2 billion in V.C. Summer construction costs through elevated rates approved by regulators prior to the 2017 abandonment. In November 2018, the parties reached a preliminarily approved by the Richland County Court of Common Pleas, delivering approximately $2 billion in total benefits to SCE&G customers via direct bill credits, rate base reductions, and refunds, averting further litigation while denying defendants' liability for or . This agreement complemented regulatory rate adjustments but did not include .

Ongoing Ratepayer Obligations

Following the 2019 acquisition of by , customers of —previously served by SCANA subsidiary Electric & Gas (SCE&G)—continue to bear a portion of the financial burden from the abandoned V.C. Summer Units 2 and 3 expansion through rate structures approved by the Public Service Commission (PSC). These obligations arise from the state's Base Load Review Act, which permitted utilities to recover costs incrementally from ratepayers during the , embedding charges into monthly bills even after the 2017 abandonment. As of April 2024, this included repayment of approximately $2.3 billion in debt tied to the failed expansion, financed through non-itemized fees within electricity rates rather than explicit line items on bills. Regulatory settlements and PSC orders post-failure mitigated but did not eliminate these costs; for instance, funded a $575 million rate refund as part of merger conditions, yet allowed recovery of certain "prudent" expenditures incurred before project risks became evident. Overall, SCE&G ratepayers had already financed roughly $5 billion of the joint venture's $9 billion total spend by abandonment, with ongoing amortization extending the impact over decades via long-term debt service. Critics, including consumer advocates, argue that these persistent charges represent an inequitable transfer of corporate mismanagement risks to customers, as the PSC's 2018 rulings permitted recovery of about 25-40% of sunk costs despite evidence of delayed disclosures on project delays and overruns. No full refund of the embedded debt has materialized, and as of late 2025, Dominion's South Carolina operations show no announced cessation of these rate recoveries, sustaining elevated bills averaging 10-15% above pre-project levels for affected customers. Recent proposals to restart Units 2 and 3 under Santee Cooper (the joint owner with SCE&G) do not directly involve Dominion's ratepayers but underscore unresolved legacy debts from the original partnership.

Legacy and Current Status

Achievements in Energy Provision

SCANA's subsidiaries, particularly South Carolina Electric & Gas (SCE&G), maintained a record of reliable electricity and natural gas service in the Carolinas prior to the V.C. Summer nuclear project challenges. SCE&G's electric operations served approximately 700,000 customers across central, southern, and southwestern South Carolina, while PSNC Energy provided natural gas to over 370,000 customers in North and South Carolina, contributing to regional economic stability through consistent energy access. In metrics, SCE&G achieved notable recognition for . In 2001, it ranked highest nationally for electric service satisfaction among large industrial customers according to TQS Research, reflecting strong performance in reliability and responsiveness. By 2006, and Associates again highlighted SCE&G's high scores, particularly in areas like service reliability and tree-trimming programs that minimized outages. Infrastructure expansions underscored SCANA's growth in energy delivery. In the late and early , SCANA pursued aggressive expansions to enhance supply reliability and support industrial demand, aligning efficiency and operational goals with regional needs. SCE&G's electric grid investments, including ongoing maintenance and upgrades, sustained low outage durations historically, with documented improvements in reliability indices like SAIDI (System Average Interruption Duration Index) and (System Average Interruption Frequency Index) through vegetation management and system hardening. SCANA advanced renewable integration modestly amid a and -heavy portfolio. SCE&G developed the 2.03 MW Otarre solar facility in , completed to generate clean energy equivalent to powering over 300 homes annually as part of broader clean energy initiatives. Additional projects included the 5.44 MW Barnwell Solar , operational by 2017 and supplying power under long-term agreements. In 2014, SCE&G announced plans for a 3-4 MW array at its headquarters, marking an early corporate push toward on-site renewables. These efforts, though limited in scale relative to total generation capacity, demonstrated proactive diversification ahead of the 2017 nuclear abandonment.

Criticisms of Management and Policy Influences

SCANA executives faced substantial criticism for imprudent decision-making and misleading stakeholders during the V.C. Summer expansion , which ballooned from an estimated $2.2 billion in to over $9 billion by abandonment in 2017. A February 2016 Corporation report commissioned by SCANA and highlighted Westinghouse's construction failures but also faulted the utilities for inadequate oversight, including failure to enforce schedules and quality controls. Former SCANA employees testified in November 2018 that executives committed by overstating project progress to secure regulatory approval for ongoing rate increases, with one high-level manager stating that leaders concealed critical delays and cost overruns from the Public Service Commission (). In January 2019, the formally determined that SCANA executives acted imprudently by deliberately misleading regulators about the project's viability, including withholding adverse audit findings such as a deleted section from a 2016 engineering assessment that warned of severe delays. This led to criminal prosecutions; by November 2024, four executives, including former CFO Jeffrey Benjamin, had been convicted of wire fraud and sentenced to terms ranging from one year to five years for schemes that defrauded investors and ratepayers to sustain executive bonuses tied to capital spending. A September 2017 report commissioned by Governor further attributed project flaws to inadequate management, faulty designs, and low worker morale under SCANA's subsidiary South Carolina Electric & Gas (SCE&G). Policy influences exacerbated these management failures through 's regulatory framework, particularly the 2007 Energy Freedom Act, which enabled "advanced " cost recovery via pre-construction rate hikes without tying approvals to completion milestones. Critics argued this structure shifted financial risks entirely to ratepayers—resulting in $2.4 billion in surcharges collected by SCANA before abandonment—while insulating utilities from market discipline. The PSC's oversight was lambasted for lax enforcement; in February 2018, the South Carolina House voted 108-1 to remove all seven commissioners over two years, citing their failure to scrutinize SCANA's filings adequately amid the scandal. Lawmakers, including those pushing H.4939 in 2017, contended that shareholders rather than customers should bear abandonment costs, highlighting how politically connected utilities influenced legislation to favor expansion without robust accountability. This environment, combined with limited federal intervention despite awareness of issues, contributed to the 's unchecked escalation until filings by Westinghouse in March 2017 forced suspension.

Post-Merger Operations Under Dominion

Following the merger's completion on , 2019, SCANA Corporation operated as a wholly owned of , Inc., with its primary assets integrated into Dominion's newly formed Southeast Energy Group to enhance regional operations across the and . This structure preserved SCANA's local management and community engagement while leveraging Dominion's broader resources for infrastructure and service delivery. South Carolina Electric & Gas Company (SCE&G), SCANA's flagship electric and gas utility serving about 730,000 electric customers and 360,000 gas customers primarily in , underwent rebranding to South Carolina effective April 29, 2019, appearing on customer bills and correspondence thereafter. Customers experienced immediate rate relief as merger conditions, with typical residential electric bills reduced by $0.36 per month starting February 2019, alongside Dominion's commitment to $2.0 billion in refunds and restitution over 20 years, funded partly by Dominion's capital. Operational enhancements included environmental gains, with South Carolina's carbon emissions declining 26.3% from 2019 to 2021 through efficiency measures and fuel adjustments. also divested non-core assets acquired via SCANA, notably selling Public Service Company of (PSNC Energy), which served 600,000 customers, to for $3.1 billion in a deal announced September 2023 and closed October 1, 2024. By 2025, core operations centered on Dominion Energy South Carolina's electric generation, transmission, and distribution, supplemented by natural gas services, with Generation Company (GENCO)—a SCANA subsidiary—providing contracted capacity and output to support reliability. The utility earned recognition for its small business energy efficiency program, offering incentives to manage costs and integrate renewables with storage for grid stability. These efforts emphasized sustained service provision amid Dominion's broader portfolio realignments, including nuclear fleet integration under unified benefit plans.

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