EDGAR 10-K Filing

Company CIK: 1089819
Filing Year: 2025
Filename: 1089819_10-K_2025_0001089819-25-000003.json

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ITEM 1. BUSINESS
ITEM 1. BUSINESS
GENERAL
Cleco Holdings is a public utility holding company that holds investments in its principal operating business segment, Cleco Power, and prior to the close of the Cleco Cajun Divestiture, Cleco Cajun. Cleco Holdings, subject to certain limited exceptions, is exempt from regulation as a public utility holding company pursuant to provisions of the Public Utility Holding Company Act of 2005. Cleco Holdings’ predecessor was incorporated on October 30, 1998, under the laws of the state of Louisiana. In 2016, Cleco Holdings became a direct, wholly owned subsidiary of Cleco Group and an indirect, wholly owned subsidiary of Cleco Partners.
Cleco Power is a regulated electric utility engaged principally in the generation, transmission, distribution, and sale of electricity within Louisiana. Cleco Power owns eight generating units with a total rated capacity of 2,676 MW and serves approximately 295,000 customers in Louisiana through its retail business. Additionally, Cleco Power supplies wholesale power in Louisiana. Cleco Power was organized as a limited liability company under the laws of the state of Louisiana on December 12, 2000. Cleco Power’s predecessor was incorporated on January 2, 1935, under the laws of the state of Louisiana.
Cleco Cajun, was an unregulated electric utility that owned 14 generating units with a total rated capacity of 3,379 MW and supplied wholesale power and capacity in Louisiana. In March 2023, Cleco Holdings’ management, with the support of its Board of Managers, committed to a plan of action for the disposition of the Cleco Cajun Sale Group. The results of operations and financial position of the Cleco Cajun Sale Group have been presented as discontinued operations since March 31, 2023. On June 1, 2024, the Cleco Cajun Divestiture closed. For more information, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - “Discontinued Operations.”
Cleco’s and Cleco Power’s mailing address is P.O. Box 5000, Pineville, Louisiana 71361-5000, and its telephone number is (318) 484-7400. Cleco’s website is located at https://www.cleco.com. Cleco’s and Cleco Power’s Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and other filings with the SEC are available, free of charge, through Cleco’s website after those reports or filings are filed electronically with or furnished to the SEC. Cleco’s electronically filed reports can also be obtained on the SEC’s website located at https://www.sec.gov. Cleco’s Governance Guidelines, Code of Conduct for Financial Managers, Ethics Guide, Conflicts of Interest and Related Policies, and the charters of its Boards of Managers’ Audit, Leadership Development and Compensation, Business Planning and Budget Review, Governance and Public Affairs, and Asset Management Committees are available on its website and available in print upon request. Information on Cleco’s website or any other website is not incorporated by reference into this Annual Report on Form 10-K and does not constitute a part of this Annual Report on Form 10-K.
Cleco Power meets the conditions specified in General Instructions I(1)(a) and (b) to Form 10-K and, therefore, is
permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies. Accordingly, Cleco Power has omitted from this Annual Report on Form 10-K the information called for by the following Part II item of Form 10-K: Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations); and the following Part III items of Form 10-K: Item 10 (Directors, Executive Officers, and Corporate Governance of the Registrants), Item 11 (Executive Compensation), Item 12 (Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters), and Item 13 (Certain Relationships and Related Transactions, and Director Independence).
HUMAN CAPITAL
Cleco’s key human capital management objectives are to attract, retain, and develop top talent while providing an inclusive, healthy, and safe workplace. Cleco’s programs are designed to create a high-performing, inclusive workforce; reward and support employees through competitive pay and benefits, as well as safety and wellness programs; enhance culture through efforts aimed at making the workplace more engaging and championing a sense of belonging; facilitate programs that build connections between employees and communities; and evolve and invest in technology, tools, and resources to enable employees at work.
At December 31, 2024, Cleco had 1,158 employees and Cleco Power had 794 employees, all of which were full-time. Currently, one of Cleco’s employees is covered by a collective bargaining agreement. Cleco has not experienced strikes or work stoppages and believes it has good relations with its employees.
Cleco believes that fostering inclusivity is the primary driver of better employee engagement, increased innovation, and higher customer satisfaction. With greater workplace inclusion, Cleco seeks to create the conditions for high performing teams to do their best work. The following are some of Cleco’s inclusion achievements:
•continued empowerment of the Cleco Inclusion Culture Council as a group of leaders to advance Cleco’s inclusion strategy to help make its business stronger,
•continued to increase inclusion communications internally and externally,
•continued to fund the Power of a Promise Scholarship to educate and employ individuals with limited financial resources in the central Louisiana area, and
•implemented employee development programs.
Health, Safety, and Wellness
The success of Cleco’s business is fundamentally connected to the well-being of its employees. Accordingly, Cleco is committed to the health, safety, and well-being of its employees.
Cleco has a strong safety culture and continues to develop programs to ensure its employees are safe at work and away from work. Cleco strives to improve its safety culture
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in an effort to be a world-class safety organization with top decile performance compared to peer companies with the goal of reaching a target of zero for injuries and accidents. To accomplish this goal, Cleco continues to implement several safety initiatives throughout the organization aimed at both leading and lagging indicators in an effort to reduce the number and severity of safety incidents. Cleco utilizes employee-led safety teams throughout the company to drive the safety initiatives and provide feedback to senior management. In addition to Occupational Safety and Health Administration mandated safety training, employees receive human performance and energy wheel (hazard identification) training designed to improve total organization performance.
Cleco continues to provide its employees and their families with access to a variety of health and wellness programs, including programs that provide protection and security so they can have peace of mind concerning events that may require time away from work. Cleco also has programs that support employees’ physical and mental health by providing tools and resources to help them improve or maintain their health and encourage engagement in healthy behaviors. These include paid time off, family leave, flexible work schedules, employee assistance programs, wellness programs, tuition assistance, and on-site services, such as fitness centers, among many others.
Compensation and Benefits
Cleco is committed to offering market-competitive compensation and benefits to its employees. Its incentive plan reinforces and rewards individuals for achievement of specific company goals. Cleco’s benefit offerings are designed to meet the varied and evolving needs of an inclusive workforce and offer choice where possible so employees can customize their benefits to meet their needs and the needs of their families. These offerings include a 401(k) Plan, healthcare benefits, health savings and flexible spending accounts, and a variety of insurance options.
Talent Acquisition and Talent Development
Cleco prioritizes investing in the attraction and development of the talent needed to build a sustainable workforce. Cleco has continued to revamp its recruiting and hiring practices, technologies, and resources as well as expand its focus on continuous learning and development. Cleco utilizes industry-leading methodologies to assess performance and potential, provide coaching and feedback, and develop talent. Cleco provides a series of targeted management workshops to address leadership skills and competency gaps. Additionally, its performance management program provides an ongoing opportunity for employees and managers to engage in continuous dialogue and coaching aligned with its annual performance review process. Cleco provides its employees with a multitude of resources, such as online learning platforms that provide quick access to learning resources, tuition reimbursement, and talent and succession planning. Cleco also encourages employees to engage in external workshops and organizations to address individualized development needs and stay abreast of industry and position-specific best practices.
Employee Engagement
Employee sentiment is important to Cleco. The company measures this throughout the year via employee engagement surveys. One of the key metrics used is the Employee Net
Promoter Score (eNPS), which is an indicator of employees’ likelihood to recommend Cleco as a place of employment to friends and/or family. Cleco strives to consistently receive a strong eNPS score year over year. Other important areas measured on the employee engagement surveys include future outlook, leadership, safety, inclusion, communications, vibrancy, and goals.
Pulse, which is Cleco’s mobile, two-way communication platform for employees, allows for tracking of viewership, enables targeted messaging by employee segments, and offers key performance indicators to measure how internal communication supports Cleco’s business objectives. In support of employee engagement efforts, Pulse is the cornerstone of communication for all Cleco employees.
Communities
Cleco believes that building connections between its employees and its communities creates a more meaningful, fulfilling, and enjoyable workplace. Cleco is committed to being a responsible company in the communities where it does business. Through Cleco’s donation and volunteering programs, employees are able to find and register for volunteer opportunities within their communities and use automated payroll deductions to donate to causes they are passionate about. Cleco continues to match employee donations made to Louisiana qualifying causes dollar for dollar up to $1,000 per year per employee. Employees can also be rewarded with $10 for every hour of volunteer time, up to $500 per year. Organizations are also able to enroll in the platform in order to receive donations faster and connect with corporate giving and volunteering opportunities at Cleco. Cleco also frequently collaborates with organizations on volunteer activities for its employees. Throughout the year, employees make a positive impact in their local communities and have found a multitude of special ways to volunteer.
Oversight and Governance
Cleco’s Leadership Development and Compensation Committee, through its charter, provides oversight of Cleco’s policies, programs, and initiatives focusing on workforce inclusion. Cleco’s Governance and Public Affairs Committee, through its charter, provides oversight of Cleco’s charitable donations, outreach, and economic development funding programs.
OPERATIONS
Cleco Power
Certain Factors Affecting Cleco Power
As an electric utility, Cleco Power is affected by a number of factors influencing the electric utility industry in general. For more information on these factors, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Comparison of the Years Ended December 31, 2024, and 2023 - Cleco Power - Significant Factors Affecting Cleco Power.”
Power Generation
As of December 31, 2024, Cleco Power’s aggregate net electric generating capacity was 2,519 MW. This amount reflects the maximum production capacity these units can
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sustain over a specified period of time under certain conditions.
In January 2024, Cleco Power filed a notice with the LPSC to retire Teche Unit 3, and on June 1, 2024, Teche Unit 3 was retired.
The following table sets forth certain information with respect to Cleco Power’s generating facilities as of December 31, 2024:
GENERATING STATION YEAR OF INITIAL
OPERATION
RATED
CAPACITY (MW)
NET
CAPACITY (MW)
(1)
PRIMARY FUEL USED
FOR GENERATION GENERATION TYPE
Brame Energy Center
Nesbitt Unit 1 1975 440 419 natural gas steam
Rodemacher Unit 2 1982 157 (2)
148 (2)
coal steam
Madison Unit 3 2010 641 603 petroleum coke/coal steam
Acadia Unit 1 2002 580 538 natural gas combined cycle
Coughlin Unit 6 2000 264 250 natural gas combined cycle
Coughlin Unit 7 2000 511 480 natural gas combined cycle
Teche Unit 4 2011 33 34 natural gas combustion
St. Mary Clean Energy Center 2019 50 47 waste heat steam
Total generating capability 2,676 2,519
(1) Values supported by tests performed between September 2023 and August 2024.
(2) Represents Cleco Power’s 30% ownership interest in the capacity of Rodemacher Unit 2, a 523-MW generating unit.
The following table sets forth the amounts of power generated by Cleco Power for the years indicated:
YEAR THOUSAND
MWh PERCENT OF
TOTAL ENERGY
REQUIREMENTS
2024 9,201 89.9 %
2023 10,250 83.3 %
2022 10,842 87.0 %
Cleco Power’s generation dispatch and transmission operations are integrated with MISO. The amount of power generated by Cleco Power is dictated by the availability of Cleco Power’s generating fleet and the manner in which MISO dispatches each generating unit. Depending on how generating units are dispatched by MISO, the amount of power generated may be greater than or less than total energy requirements. Generating units are dispatched by referencing each unit’s economic efficiency as it relates to the overall MISO market. For more information on MISO, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition
and Results of Operations - Financial Condition - Regulatory and Other Matters - Transmission Rates.”
Fuel and Purchased Power
Changes in fuel expenses reflect fluctuations in the amount, type, and pricing of fuel used for electric generation; fuel transportation and delivery costs; and deferral of expenses for recovery from customers through Cleco Power’s FAC in subsequent months. Changes in purchased power expenses are a result of the quantity and price of economic power purchased from the MISO market. These quantity changes can be affected by Cleco plant outages and plant performance. For a discussion of certain risks associated with changes in fuel costs and their impact on utility customers, see Item 1A, “Risk Factors - Financial Risks - Transmission Congestion” and “- Regulatory Risks - LPSC Audits.”
The following table sets forth the percentages of power generated from various fuels at Cleco Power’s electric generating plants, the cost of fuel used per MWh attributable to each such fuel, and the weighted average fuel cost per MWh:
COAL NATURAL GAS PETROLEUM COKE WASTE HEAT
WEIGHTED
AVERAGE COST
PER MWh
YEAR COST PER
MWh PERCENT OF
GENERATION COST PER
MWh PERCENT OF
GENERATION COST PER
MWh PERCENT OF
GENERATION PERCENT OF
GENERATION
2024 $ 41.76 5.3 % $ 21.97 92.1 % $ 106.39 0.4 % 2.2 % $ 23.23
2023 $ 41.27 8.5 % $ 24.96 81.0 % $ 62.48 8.4 % 2.1 % $ 29.18
2022 $ 31.56 14.1 % $ 54.78 66.7 % $ 57.64 17.0 % 2.2 % $ 51.02
Power Purchases
Cleco Power is a participant in the MISO market. MISO makes economic and routine dispatch decisions regarding Cleco Power’s generating units. Power purchases are made at prevailing market prices, also referred to as LMP. LMP includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have higher LMPs. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zones. For information on Cleco Power’s ability to pass on to its customers substantially all of its fuel and purchased power expenses, see “- Regulatory Matters, Industry Developments, and Franchises - Rates.” For information on MISO, see Part II, Item 7,
“Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Regulatory and Other Matters - Transmission Rates.”
Coal and Petroleum Coke Supply
Cleco Power uses coal for generation at Rodemacher Unit 2 and a combination of coal and petroleum coke for generation at Madison Unit 3. Cleco Power had adequate coal and petroleum coke supply to meet its operational needs during 2024. Parties with whom Cleco Power had an existing railcar lease and existing marine transportation delivery agreements were able to satisfy the fuel needs of both generating stations in 2024. During 2024, Cleco Power purchased approximately 222,000 tons of coal and 110,000 tons of petroleum coke. At
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December 31, 2024, coal inventory at Rodemacher Unit 2 was approximately 199,000 tons, which is approximately an 83-day supply. At December 31, 2024, coal inventory at Madison Unit 3 was approximately 424,000 tons and petroleum coke inventory at Madison Unit 3 was approximately 259,000 tons, which collectively totals to an approximate 72-day supply.
Cleco Power is utilizing a short-term, fixed-price coal agreement to meet its coal supply needs at Rodemacher Unit 2 during 2025. Cleco will use its existing rail transportation agreement to transport coal to Rodemacher Unit 2 through December 31, 2025, and will reassess this agreement upon its expiration in March 2027.
As a result of previously executed petroleum coke supply contracts, Cleco Power has sufficient coal and petroleum coke supply for anticipated operations at Madison Unit 3 during 2025. Cleco Power has barge logistics agreements for delivery of petroleum coke and coal at Madison Unit 3 through April 15, 2025. Subsequently, Cleco Power expects to contract marine transportation and logistics for Madison Unit 3 fuel on an as-needed basis. For more information on Cleco Power’s barge logistics agreements, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 4 - Leases - Finance Lease.”
Cleco Power’s continuous supply of coal and petroleum coke may be subject to interruption due to adverse weather conditions or other factors that may disrupt transportation to the plant site. Cleco Power’s continuous supply of petroleum coke may also be interrupted by change in regional and global refining output.
Natural Gas Supply
Cleco Power owns natural gas pipelines and interconnections at all of its natural gas generating facilities that allow it to access various natural gas supply markets and maintain a reliable, economical fuel supply for its customers. Cleco Power also uses underground salt dome gas storage to help mitigate supply disruptions to its generating facilities and to operationally balance gas supply to its units. During 2024, Cleco Power utilized purchases on the spot market through daily, monthly, and seasonal contracts with various natural gas suppliers as well as gas in storage to meet its natural gas requirements. Additionally, during 2024, Cleco Power utilized short-term and long-term natural gas firm transportation contracts with one interstate pipeline and two self-built pipeline laterals directly connected to a storage hub to supply fuel to its power plants. During 2024, Cleco Power purchased approximately 63.7 million MMBtu of natural gas from various suppliers for the generation of electricity. At December 31, 2024, Cleco Power had 1.8 million MMBtu of natural gas in storage.
Cleco Power expects to continue to meet its natural gas requirements with purchases on the spot market through daily, monthly, and seasonal contracts with various natural gas suppliers and firm transportation contracts. Currently, Cleco Power anticipates that its diverse supply options and natural gas storage, combined with its solid-fuel generation resources, are adequate to meet its generation needs during any temporary interruption of natural gas supplies. To the extent natural gas supplies may become disrupted or natural gas prices significantly increase, Cleco Power may in some instances use alternate fuels or rely to a larger extent on coal and purchased power.
Sales
Cleco Power’s 2024 and 2023 system peak demands, which occurred on January 17, 2024, and August 23, 2023, were 2,777 MW and 2,759 MW, respectively. Generally, sales and system peak demand are affected by weather and are typically highest during the summer air-conditioning season; however, peaks may occur during the winter season as well. For information on the effects of future energy sales on Cleco Power’s results of operations, financial condition, and cash flows, see Item 1A, “Risk Factors - Operational Risks - Future Electricity Sales” and “- Weather and Climate Vulnerabilities.”
During both 2024 and 2023, Cleco Power was a net seller of MWs in the MISO capacity auction. For more information on MISO, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Regulatory and Other Matters - Transmission Rates.”
Customers and Competition
During 2023, one wholesale customer accounted for 11.0% and 10.8% of Cleco’s and Cleco Power’s consolidated revenue, respectively. On March 31, 2024, the contract with this significant wholesale customer expired and was not renewed with Cleco Power; therefore, neither Cleco nor Cleco Power had any customer that accounted for 10% or more of consolidated revenue during 2024.
For more information regarding Cleco Power’s sales and revenue, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations.”
Within MISO, competitors are typically comprised of investor-owned utilities, independent power producers, power marketers, and power plant developers. These entities typically compete on the basis of price, reliability, and residual risk to the purchasing customer and its end users. Cleco Power could experience some competition for electric sales to industrial customers in the form of cogeneration and from alternative and distributed energy power sources.
On July 16, 2024, the LPSC adopted minimum physical capacity threshold requirements for load serving entities. The LPSC’s final rule could materially impact Cleco Power’s results of operations, financial condition, or cash flows. Management is unable to determine the effect this rule will have on Cleco Power’s operations at this time.
Capital Investment Projects
For a discussion of certain Cleco Power major capital investment projects, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Overview - Cleco Power.”
Capital Expenditures and Financing
For information on Cleco Power’s capital expenditures, financing, and related matters, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - Cash Generation and Cash Requirements - Capital Expenditures.”
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REGULATORY MATTERS, INDUSTRY DEVELOPMENTS, AND FRANCHISES
Rates
Cleco Power’s electric operations are subject to the jurisdiction of the LPSC with respect to retail rates, standards of service, accounting, and other matters. Cleco Power is subject to the jurisdiction of FERC with respect to transmission tariffs, accounting, interconnections with other utilities, reliability, and the transmission of power. Periodically, Cleco Power has sought and received from both the LPSC and FERC increases in retail rates and transmission tariffs, respectively, to cover increases in operating costs and costs associated with additions to generation, transmission, and distribution facilities.
For information on Cleco’s wholesale rates, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - Wholesale Rates.”
For information on Cleco Power’s current FRP, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - FRP.” For information on the residential revenue decoupling regulatory liability, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities - Residential Revenue Decoupling.”
Generally, Cleco Power’s cost of fuel used for electric generation and the cost of purchased power are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. For more information on the FAC and the most recent fuel audits, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Fuel Audits.”
Cleco Power has an EAC that is used to recover certain costs of environmental compliance from its customers. These costs are subject to periodic review by the LPSC. For more information on the EAC and the most recent environmental audit, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Environmental Audit.”
For information on the regulatory impacts of the TCJA on Cleco Power, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - TCJA.”
For information on Cleco Power’s transmission rates, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 5 - Revenue Recognition - Transmission Revenue.”
For information on regulatory risks that could have an impact on Cleco, see Item 1A, “Risk Factors - Regulatory Risks.”
Franchises
Cleco Power operates under nonexclusive franchise rights granted by governmental units, such as municipalities and parishes (counties), and enforced by state law. These franchises are for fixed terms that vary in length. Historically,
Cleco Power has been substantially successful in the timely renewal of franchises as each neared the end of its term. Currently, two parish franchise agreements remain expired; however, Cleco continues to serve the customers in those parishes. Cleco Power is continuing to make efforts to renew these franchise agreements.
Industry Developments and Competition
For information on developments and competition within the electric utility industry, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Regulatory and Other Matters - Market Structure.”
Legislative and Regulatory Changes and Matters
Various federal and state legislative and regulatory bodies are considering a number of issues that could shape the future of the electric utility industry. Such issues include, among others:
•the ability of electric utilities to recover stranded costs,
•the role of electric utilities, independent power producers, and competitive bidding in the purchase, construction, and operation of new generating capacity,
•the role of electric utilities and independent transmission providers in competitive bidding in the construction of new transmission facilities,
•the pricing of transmission service on an electric utility’s transmission system, or the cost of transmission services provided by an RTO/ISO,
•FERC’s assessment of market power and a utility’s ability to buy generation assets,
•transmission reliability standards mandates,
•NERC’s imposition of additional reliability and cybersecurity standards,
•the authority of FERC to grant utilities the power of eminent domain,
•increasing requirements for renewable energy sources,
•demand response and energy efficiency standards,
•comprehensive environmental regulation in the areas of air, water, and waste,
•development of additional regulations or changes to existing regulations by the new presidential administration, and
•FERC’s ability to impose financial penalties.
At this time, management is unable to predict the outcome of such issues or the effects thereof on the results of operations, financial condition, or cash flows of the Registrants.
For information on certain regulatory matters and regulatory accounting affecting Cleco, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Regulatory and Other Matters.”
ENVIRONMENTAL MATTERS
Environmental Quality
Cleco is subject to federal, state, and local laws and regulations governing the protection of the environment. Violations of these laws and regulations may result in substantial fines and penalties. Cleco has obtained the environmental permits necessary for its operations and is in compliance in all material respects with these permits, as well as all applicable environmental laws and regulations.
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Environmental requirements affecting electric power facilities are complex, change frequently, and have become more stringent over time as a result of new legislation, administrative actions, and judicial interpretations. Therefore, the capital costs and other expenditures necessary to comply with existing and new environmental requirements are difficult to determine. Cleco Power may request recovery of the costs to comply with certain environmental laws and regulations from its retail customers. If recovery were to be approved by the LPSC, Cleco Power’s retail rates could increase. If the LPSC were to deny Cleco Power’s request to recover all or part of its environmental compliance costs, Cleco Power would bear those costs directly. Such a decision could negatively impact the results of operations, financial condition, or cash flows of the Registrants. For information on Cleco’s expected capital expenditures related to environmental compliance, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - Cash Generation and Cash Requirements - Capital Expenditures.”
Air Quality
Regional Haze SIP
The CAA requires the EPA to implement a regional haze program with the goal of returning Class I Federal areas of the nation to natural visibility conditions by 2064. To attain this goal, states are required to develop a SIP every ten years, which, among other things, must include requirements for making reasonable progress toward the national visibility goal, which could include the installation of costly controls on stationary sources such as EGUs. SIPs for the second regional haze planning period were due to the EPA by July 31, 2021. In August, 2022, the EPA published a finding that Louisiana and fourteen other states failed to submit a regional haze SIP for the second planning period. Such finding requires the EPA to issue a FIP within two years if the LDEQ does not submit a SIP before then. Until the LDEQ determines what the reasonable progress requirements are for Cleco’s units, completes its update of the SIP, and the SIP is approved by the EPA, or the EPA issues a FIP, Cleco is unable to predict if the second phase SIP will have a material impact on the results of operations, financial condition, or cash flows of the Registrants.
CSAPR
Cleco’s units are subject to CSAPR, a cap-and-trade type program requiring EGUs in several states, including Louisiana, to make substantial reductions in NOx emissions, which contribute to ozone to reduce interstate transport of such pollution to meet the CAA’s “good neighbor” provision.
In October 2015, the EPA promulgated the 2015 ozone NAAQS, to lower the level of both the primary and secondary ground-level ozone standards, which prompted Louisiana to develop a “good neighbor” SIP. Louisiana submitted a SIP to the EPA that determined no additional controls on stationary sources such as EGUs were needed to address interstate transport of ozone precursors, including NOx. In February 2023, the EPA issued a disapproval of the “good neighbor” SIP submitted by Louisiana and a number of other states, for the 2015 ozone NAAQS, which was subsequently challenged in regional circuit courts. In May 2023, the U.S. Court of Appeals for the Fifth Circuit temporarily stayed the disapproval of the “good neighbor” SIP for Louisiana pending judicial review.
To address the SIP disapprovals, in June 2023, the EPA published a final “good neighbor” FIP for Louisiana and the other states subject to SIP disapprovals. The final FIP included revision to CSAPR, which resulted in the allocation of fewer NOx emission allowances to Cleco’s units and could cause Cleco to buy additional allowances and/or take other measures to comply. However, the FIP did not take effect in Louisiana due to the Fifth Circuit stay of the Louisiana SIP disapproval. In addition, numerous parties filed petitions for review of the FIP in various circuit courts and, in June 2024, the U.S. Supreme Court issued an order granting emergency applications to stay the FIP.
In November 2024, the EPA issued an interim final rule to put the prior CSAPR NOx allowance allocations back into effect pending the outcome of the challenges to the SIP disapprovals and the FIP. The final effect of these rulemakings on the Registrants’ results of operations, financial condition, or cash flows cannot be determined until the litigation over the rulemakings has been resolved.
NSPS
On May 9, 2024, the EPA issued a final rule under Section 111 of the CAA to regulate GHG emissions from existing fossil-fuel fired electric steam generating units and NSPS for modified coal-fired units and new or reconstructed stationary combustion turbines (Section 111 GHG Rule). For existing units, the state will be required to submit an implementation plan to the EPA by May 11, 2026, while the NSPS are applicable as of the effective date of the rule. The Section 111 GHG rule is currently being challenged by several parties. If upheld, the final rule requires significant reductions in CO2 emissions for existing coal-fired EGUs. Cleco’s compliance with the Section III GHG Rule’s requirements for existing EGUs could have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Cleco does not anticipate a future modification or future reconstruction of its existing units, as defined in the Section 111 GHG Rule, that would trigger the application of the NSPS.
NAAQS
In March 2024, the EPA published a final rule regarding the NAAQS for fine particulate matter (PM2.5), which lowered the prior standard from 12 micrograms/cubic meter to 9 micrograms/cubic meter. The rule is currently in litigation and the EPA has not yet designated any areas as nonattainment for the revised standard. Cleco cannot predict the likelihood or potential impacts of the final rule on its generating units at this time.
Water Quality
In August 2014, the EPA issued final regulations to establish standards for cooling water intake structures at existing power plants and other facilities pursuant to Section 316(b) of the CWA to protect fish and other aquatic wildlife. Portions of the final rule could apply to Cleco’s fossil fuel steam electric generating stations. Until the studies required by the final rule are conducted, including technical and economic evaluations of the control options available, and regulatory agency officials have reviewed the studies and made determinations, Cleco remains uncertain as to which technology options or retrofits will be required to be installed on its affected facilities. The costs of required technology options and retrofits may be significant, particularly if closed cycle cooling is required.
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In November 2015, the EPA released the Effluent Limitations Guidelines and Standards for the Steam Electric Power Generating Point Source Category Rule (ELG Rule), which focused on reducing the discharge of metals in wastewater from generating facilities to surface waters.
In 2020, the EPA revised the effluent limitations guidelines and standards to flue gas desulfurization and bottom ash transport waste waters for the steam electric power generating source category. The 2020 rule allows a unit to come into compliance with the ELG Rule by qualifying as an electric generating unit that will achieve permanent cessation of coal combustion by December 31, 2028. Under this compliance option, Cleco submitted a timely Notice of Planned Participation for the Dolet Hills Power Station and Rodemacher Unit 2.
On May 9, 2024, the EPA issued a final rule that imposes discharge limits on landfill leachate and on the legacy wastewater in retiring impoundments. Cleco is unable to predict at this time if this will have a material impact on the results of operations, financial condition, or cash flow of the Registrants.
Solid Waste Disposal
In August 2020, the EPA published a final rule regulating the disposal and management of CCRs from coal-fired power plants (CCR Rule) that would set deadlines for costly modifications, including retrofitting of clay-lined impoundments with compliant liners or closure of the impoundments. In November 2020, Cleco submitted demonstrations to the EPA specifying its intended course of action for the ash disposal facilities at Rodemacher Unit 2 and Dolet Hills Power Station to comply with the final CCR Rule. Cleco Power withdrew the Dolet Hills demonstration due to the cessation of receiving waste. The demonstration for Rodemacher Unit 2, which was deemed complete by the EPA on January 11, 2022, is still subject to EPA approval based on pending technical reviews.
On May 8, 2024, the EPA published a final rule that would regulate CCR Management Units (MUs), which includes non-containerized accumulations of CCR on the land at facilities otherwise subject to federal CCR regulations. The final regulation mandates the conducting of facility evaluations at such facilities after the effective date of the rule to determine if MUs are present. For any identified MUs of a particular size, the regulation would require evaluating any impacts on groundwater along with planning for closure of any identified CCR MU sites. Cleco does not expect this final rule to have a material financial impact on its generating units and environmental obligations.
As a result of solid waste disposal regulations, Cleco Power has AROs for the retirement of certain ash disposal facilities. All costs of the CCR Rule for Cleco Power are expected to be recovered from its customers in future rates. The actual asset retirement costs related to the CCR Rule requirements may vary substantially from the estimates used to record the increased obligation. For more information on Cleco’s compliance strategies and financial impacts of the CCR Rule, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Other Commitments.” For more information on the regulatory treatment of Cleco Power’s AROs, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities - AROs.”
In October 2023, the LDEQ published a proposed rule, Disposal of Coal Combustion Residuals, to regulate CCR units under a state permit program. Until Louisiana has finalized its CCR permit program rule and such program has been approved by the EPA, Cleco cannot determine if there will be a material impact on the results of operations, financial condition, or cash flows of the Registrants.
Comprehensive Environmental Response, Compensation and Liability Act (CERCLA)
CERCLA imposes strict liability on parties responsible for the presence of hazardous substances at a site. In 2008, the EPA identified Cleco as one of many companies that sent PCB wastes for disposal to the Devil’s Swamp Lake site located northwest of Baton Rouge, Louisiana. In August 2020, the EPA signed a Record of Decision for the Devil’s Swamp Lake site that defines a remediation approach for cleaning up the site and monitoring the natural recovery of certain areas of the lake. Clean Harbors, Inc. and two of its subsidiaries, have reached an over $5.0 million agreement with the Justice Department and the EPA to clean up the contamination at the Devil’s Swamp Lake site. This agreement consists of estimated costs of over $3.0 million for the clean up of the site and $2.0 million for reimbursement to the U.S. for costs incurred in responding to contamination at the site. At this time management is unable to determine how significant Cleco’s share of the costs associated with the response action at the site, if any, may be and whether this will have a material impact on the results of operations, financial condition, or cash flows of the Registrants.
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ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS
The following risk factors could have a material adverse effect on results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, the Registrants.
STRUCTURAL RISKS
Holding Company
Cleco Holdings is a holding company and its ability to meet its debt obligations is dependent on the cash generated by its subsidiaries.
Cleco Holdings is a holding company and conducts its operations primarily through its subsidiaries, mainly Cleco Power. Accordingly, Cleco Holdings’ ability to meet its debt obligations is largely dependent upon the cash generated by these subsidiaries. Cleco Holdings’ subsidiaries are separate and distinct entities and have no obligations to pay any amounts due on Cleco Holdings’ debt or to make any funds available for such payment. In addition, Cleco Holdings’ subsidiaries’ ability to make dividend payments or other distributions to Cleco Holdings may be restricted by their obligations to holders of their outstanding securities and to other general business creditors. Substantially all of Cleco’s consolidated assets are held by Cleco Power. Cleco Holdings’ right to receive any assets of any subsidiary, and therefore the right of its creditors to participate in those assets, will be structurally subordinated to the claims of that subsidiary’s creditors, including trade creditors. In addition, even if Cleco Holdings were a creditor of any subsidiary, its rights as a creditor would be effectively subordinated to any security interest in the assets of that subsidiary and any indebtedness of the subsidiary ranking senior to that held by Cleco Holdings. Cleco Power is subject to regulation by various governmental agencies, including the LPSC. The 2016 Merger Commitments also provide for limitations on the amount of distributions that may be paid from Cleco Power to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit/issuer ratings. As a result, Cleco Power may be prohibited from making distributions to Cleco Holdings.
OPERATIONAL RISKS
Future Electricity Sales
Cleco’s future electricity sales and cash flows could be negatively affected by adverse macroeconomic conditions.
Adverse macroeconomic conditions resulting in low economic growth can negatively impact the businesses of Cleco Power’s residential, commercial, wholesale, and industrial customers. Such resulting decreased power consumption, could cause a corresponding decrease in base revenue for Cleco Power. The reduced production or shutdown of customer facilities could substantially reduce Cleco Power’s base revenue in such cases.
Various factors driving supply and demand for electricity could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Demand for the Registrants’ services can be driven by changing populations within their service territory, significant
changes in commercial or industrial customers, or other changes in consumer habits such as energy conservation and energy efficiency efforts. Increased energy demand or significant accelerated growth in demand due to new data centers, widespread adoption of electric vehicles, or other customer changes could require enhancements to the Registrants’ infrastructure. As discussed below, the ability of the Registrants to construct new facilities is dependent upon factors outside of their control, including obtaining regulatory approvals and environmental and other permits. Any delay in or inability to complete construction of new facilities or expand and/or retrofit existing facilities could have an adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Alternatively, regulatory and legislative bodies have proposed or introduced, and may in the future propose or introduce, requirements and incentives to reduce energy consumption. Future electricity sales could be impacted by customers switching to alternative sources of energy, on-site power generation, and retail customers purchasing less electricity due to increased conservation efforts or expanded energy efficiency measures. Declining usage could result in an under-recovery of fixed costs at Cleco Power. An increase in energy conservation, energy efficiency efforts, and other efforts that reduce energy demand without the ability for Cleco Power to recover lost revenue could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Weather and Climate Vulnerabilities
Cleco’s operations and power generation could be harmed due to the impact of severe weather events, natural disasters, or climate change, which could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Severe weather, including hurricanes, winter storms, tropical storms, and other natural disasters, such as floods, droughts, and wildfires, can affect transportation of fuel to plant sites and can be destructive, causing outages, blackouts or disruptions of interconnected transmission systems, and property damage that can potentially result in additional expenses, lower revenue, and additional capital restoration costs. Extreme drought conditions can impact the availability of cooling water to support the operations of generating plants, which can also result in additional expenses. Extreme weather conditions could also increase commodity prices, including fuel, which could have a material adverse effect on Cleco’s results of operations, financial condition, or cash flows.
Climate change that results in more frequent and more severe weather events or other natural disasters in Cleco’s service territory could result in one or more physical risks that could cause damage to its generation, transmission, and distribution assets. These physical risks include an increase in sea level, wind and storm surge damages, wetland and barrier island erosion, flooding, wildfires, changes in temperature and precipitation patterns, and potential increased impacts of extreme weather conditions, including ice storms and prolonged droughts. The Registrants’ assets are in and serve communities that are at risk from sea level rise, changes in weather conditions, and loss of the protection offered by coastal wetlands. In addition, a significant portion of the nation’s oil and gas infrastructure is located in these areas and
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is susceptible to storm damage that could be aggravated by wetland and barrier island erosion, which could give rise to fuel supply interruptions and price spikes.
Any future severe weather, other natural disaster, or physical changes resulting from climate change could cause damage to, or the loss of, Cleco’s equipment and facilities, which could result in Cleco incurring additional costs, such as the cost to restore service, repair damaged facilities, or obtain replacement power. Any future severe weather, other natural disaster, or physical changes resulting from climate change could also result in changes in demand for and usage of electricity in Cleco’s service territory and the service territories of Cleco’s wholesale customers. The delivery of equipment and supplies necessary to Cleco’s business could also be disrupted. Cleco Power’s recovery of costs associated with these events is subject to LPSC review and approval, and the LPSC could disallow timely and full recovery of the costs incurred. These risks and other possible effects of severe weather, other natural disasters, and climate change could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The operating results of Cleco are affected by weather conditions and may fluctuate on a seasonal basis.
Weather conditions directly influence the demand for electricity, particularly with respect to residential customers. In Cleco’s service territory, demand for power typically peaks during the hot summer months. As a result, Cleco’s financial results typically fluctuate on a seasonal basis. In addition, Cleco has sold less power and, consequently, earned less income when weather conditions were mild. Unusually mild weather in the future could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Workforce
Failure to attract, recruit, retain, and develop an appropriately qualified workforce could have a negative impact on business operations and a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Certain events, such as employee resignations and retirements without appropriate replacements, labor shortages, wage inflation, a lack of equivalent or enhanced skill sets to fulfill future needs, or unavailability of contract resources, may lead to operating challenges and increased costs. The challenges include lack of resources, loss of knowledge, difficulty in finding highly skilled, qualified candidates, specifically due to the location of Cleco’s corporate office and potential employee relocation challenges, and a lengthy time period associated with skill development. Costs may increase as a result of contractors replacing employees, productivity slowdown, and safety incidents. Failure to hire and adequately develop replacement employees, maintain an inclusive work environment, transfer functional knowledge and expertise to the next generation of employees, ensure the availability of skilled new hires, or accept hybrid or remote work options may adversely affect the ability to manage and safely operate the Registrants’ business. If the Registrants are unable to successfully attract, recruit, retain, and develop an appropriately qualified workforce, the results of operations, financial condition, or cash flows of the Registrants could be materially adversely affected.
Technology, Nation-State, and Hacktivist Threats
The operational and information technology systems on which Cleco relies to conduct its business and serve customers could fail to function properly due to technological problems, cyber breaches, physical attacks on Cleco’s assets, acts of terrorism, severe weather, solar events, electromagnetic events, natural disasters, the age and condition of information technology assets, human error, or other reasons that could disrupt Cleco’s operations and cause Cleco to incur unanticipated losses and expense.
The operation of Cleco’s extensive electrical systems relies on evolving operational and information technology systems and network infrastructures that are becoming more complex as new technologies and business needs are implemented to more safely and reliably deliver electric services. Cleco’s business is dependent on its ability to process and monitor, on a real-time basis, a large number of tasks and transactions, many of which are highly complex. Cleco’s flexible working environment makes protecting distributed assets more challenging, and there is a greater opportunity for cyber breaches.
Cleco’s systems, including its financial information, operational, advanced metering, and billing systems, require constant maintenance, monitoring, security patches, modification or configuration of systems, and update and upgrade of systems, which can be costly and increase the risk of errors and malfunction. Any disruptions or deficiencies in existing systems, or disruptions, delays, or deficiencies in the modification, transition to, or implementation of new systems, could result in increased costs, the inability to track or collect revenues and the diversion of management’s and employees’ attention and resources, and could adversely affect the effectiveness of Cleco’s control environment, and/or its ability to accurately or timely file required regulatory reports.
Despite implementation of security and mitigation measures, Cleco’s technology systems and those of Cleco’s suppliers are vulnerable to inoperability, impaired operations, or failures due to physical attacks or cyber breaches on the facilities and equipment needed to operate the technology systems, viruses, human errors, acts of war or terrorism, and other events. If Cleco’s or its supplier’s information technology systems or network infrastructure were to fail, Cleco might be unable to fulfill critical business functions and serve its customers, which could have a material adverse effect on the financial conditions, results of operations, or cash flows of the Registrants. The potential consequences of a future material cyber breach include reputational damage, extortion payments, litigation with third parties, government enforcement actions, penalties, disruption to systems and facilities, unauthorized release of confidential or otherwise protected information, corruption of data and increased cybersecurity protection and remediation costs, which in turn could adversely affect Cleco’s competitiveness, results of operations, and financial condition. Due to the evolving nature of such cyber breach threats, including emerging artificial intelligence technologies that may be used to develop new hacking tools, exploit vulnerabilities, obscure malicious activities, and increase the difficulty in detecting threats, the potential impact of any future incident cannot be predicted. Further, the amount of insurance coverage Cleco maintains may be inadequate to cover claims or liabilities related to a cyber breach.
In addition, in the ordinary course of its business, Cleco collects and retains sensitive information including personally identifiable information about customers and employees,
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customer energy usage, and other confidential information. The theft, damage, or improper disclosure of sensitive electronic data could subject Cleco to both penalties for violation of applicable privacy laws and claims from third parties, or harm Cleco’s reputation. In addition, new laws and regulations governing data privacy and the unauthorized disclosure of confidential information pose increasingly complex compliance challenges and potentially elevate costs, and any failure to comply with these laws and regulations could result in significant penalties and legal liability.
Cleco’s Generation, Transmission, and Distribution Facilities
Cleco’s generation facilities are susceptible to unplanned outages, changes in customer demand, significant maintenance requirements, and interruption of fuel deliveries.
The operation of power generation facilities involves many risks, including breakdown or failure of equipment, fuel supply interruption, and performance below expected levels of output or efficiency. Aging equipment, even if maintained in accordance with good engineering practices, may require significant expenditures to operate at peak efficiency, or to comply with environmental permits. Newer equipment can also be subject to unexpected failures. Additionally, Cleco may face increased customer demand during peak times (including demand related to artificial intelligence, cryptocurrency mining and other computer processing requiring increased power) which may affect Cleco’s ability to meet its MISO delivery obligations. Accordingly, Cleco may incur, as applicable, more frequent unplanned outages, higher than anticipated operating and maintenance expenditures, higher replacement costs of purchased power, increased fuel costs, MISO related costs, and the loss of potential revenue related to competitive opportunities. The costs of such repairs, maintenance, and purchased power may not be fully recoverable in rates and could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Cleco’s generating facilities are currently fueled primarily by natural gas, coal, waste heat, and petroleum coke. The deliverability of these fuel sources may be constrained due to such factors as higher demand, decreased regional supply, production shortages, weather-related disturbances, railroad constraints or disruptions, waterway levels, labor strikes, or lack of transportation capacity. If suppliers are unable to deliver the contracted volume of fuel at the required times and if associated inventories are depleted, Cleco may be unable to operate its generating units which may cause Cleco Power to incur higher costs, which in turn could increase the cost to customers. Cleco Power’s fuel and MISO-procured/settled energy expenses, which are recovered from its customers through the FAC, are subject to refund until either a prudency review or a periodic fuel audit is conducted by the LPSC.
Cleco Power could be indirectly liable for the impacts of other companies’ activities on lands that have been mined and reclaimed by Cleco Power. The liability for impacts on reclaimed lands may not be recoverable in rates and could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The construction of and capital improvements to power generation, transmission, and distribution facilities involve substantial risks. Should construction or capital improvement efforts be unsuccessful or significantly more expensive than planned, the financial condition, results of operations, or liquidity of the Registrants could be materially affected.
Cleco’s ability to complete construction of or capital improvements to power generation, transmission, and distribution facilities in a timely manner and within budget is contingent upon many variables and subject to substantial risks. These variables include engineering and project execution risk and escalating costs for materials, labor, and environmental compliance. Delays in obtaining permits, shortages in materials and qualified labor, suppliers and contractors not performing as set forth under their contracts, changes in the scope and timing of projects, inaccurate cost estimates, the inability to raise capital or secure funding on favorable terms or at all, changes in commodity prices affecting revenue, fuel or material costs, changes in the economy, changes in laws or regulations, including environmental compliance requirements, and other events beyond the control of Cleco may materially affect the schedule and cost of these projects. If these projects are significantly delayed or become subject to cost overruns or cancellation, Cleco could incur additional costs including termination payments, face increased risk of potential write-off of the investment in the project, or be unable to recover such costs in rates. Furthermore, failure to maintain various levels of generating unit availability or transmission and distribution reliability may result in various disallowances of Cleco Power’s investments.
Alternative Generation Technology
Changes in technology may have a material adverse effect on the value of Cleco Power’s generating facilities.
A basic premise of Cleco’s business is that generating electricity at central power plants achieves economies of scale and produces electricity at a relatively low price. There are alternative technologies to produce electricity, most notably wind turbines, photovoltaic cells, and other solar-generated power. As new technologies are developed and become available, the quantity and pattern of electricity purchased by customers could decline, with a corresponding decline in revenues derived by generating assets. In addition, to the extent Cleco is slow to adopt viable alternative generation technologies, employs technology that is problematic to operate, and/or under or over relies on these alternative technologies, the value of Cleco Power’s generating facilities could be reduced.
Litigation
Cleco is subject to litigation and a negative outcome could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The Registrants are parties to various litigation matters arising out of the ordinary operations of their business. The ultimate outcome of these matters cannot presently be determined, nor, in many cases, can the liability that could potentially result from a negative outcome in each case presently be reasonably estimated. The liability that the Registrants may ultimately incur with respect to any of these cases in the event of a negative outcome may be in excess of amounts currently reserved and
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insured against with respect to such matters and, as a result, these matters may have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
REGULATORY RISKS
Regulatory Compliance
Cleco operates in a highly regulated environment and adverse regulatory decisions or changes in applicable regulations could have a material adverse effect on the Registrants’ business or result in significant additional costs.
Cleco’s business is subject to extensive federal, state, and local energy, environmental, and other laws and regulations. Should Cleco be unsuccessful in obtaining necessary licenses or permits or should these regulatory authorities initiate any investigations or enforcement actions or impose penalties or disallowances on Cleco, Cleco’s business could be adversely affected. Existing regulations may be revised or reinterpreted, and new laws and regulations may be adopted or become applicable to Cleco or Cleco’s facilities, including decisions by the U.S. Supreme Court that could affect the operation of federal agencies and changes resulting from the new presidential administration, that may have a material adverse effect on the Registrants’ business or result in significant additional costs. In addition, the overturning of the Chevron doctrine on June 28, 2024, by the U.S. Supreme Court, which had provided for deference in certain cases to the relevant federal agency with regard to the interpretation of federal regulations, has introduced additional uncertainty going forward regarding existing and future federal regulations.
As a result of the 2016 Merger, Cleco Holdings and Cleco Power made the 2016 Merger Commitments to the LPSC including, but not limited to, maintaining employee headcount, salaries, and benefits for ten years, and a limitation from incurring additional long-term debt, excluding non-recourse debt, unless certain financial ratios are achieved.
Cleco Power’s Rates
The LPSC and FERC regulate the retail rates and wholesale transmission tariffs, respectively, that Cleco Power can charge its customers.
Cleco Power’s ongoing financial viability depends on its ability to recover its costs in a timely manner from its LPSC-jurisdictional customers through LPSC-approved rates and its ability to recover its FERC-authorized revenue requirements from its FERC-jurisdictional wholesale transmission customers. Cleco Power’s financial viability also depends on its ability to recover in rates an adequate return on capital, including long-term debt and equity. Generally, historical costs are used by the LPSC in determining Cleco Power’s rates. If Cleco Power is unable to recover any material amount of its costs in rates in a timely manner or recover an adequate return on capital, the results of operations, financial condition, or cash flows of the Registrants could be materially adversely affected. Recovery of these costs could result in rising utility bills threatening the affordability of such costs by Cleco Power’s customers in certain demographic areas, which in turn could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Cleco Power’s revenues and earnings are substantially affected by regulatory proceedings known as rate cases or, in some cases, requests for extensions of an FRP. During those cases, the LPSC determines Cleco Power’s rate base, depreciation rates, operation and maintenance costs, and administrative and general costs that Cleco Power may recover from its retail customers through its rates. These proceedings may examine, among other things, the prudency of Cleco Power’s operation and maintenance practices, level of subject expenditures, allowed rates of return, and previously incurred capital expenditures. The LPSC has the authority to disallow recovery of costs found not to have been prudently incurred. Rate cases generally have timelines of approximately one year, and decisions are typically subject to appeal, potentially leading to additional uncertainty. The transmission tariffs of Cleco Power are regulated by FERC with its own regulatory proceedings. Both the LPSC and FERC regulatory proceedings can involve multiple parties, including governmental bodies and officials, consumer advocacy groups, and various consumers of energy, all of whom have differing concerns but who have the common objective of just and reasonable rates.
Retail Electric Service
Cleco Power’s retail electric rates and business practices are regulated by the LPSC and reviews may result in refunds to customers.
Cleco Power’s retail rates for residential, commercial, and industrial customers and other retail sales are regulated by the LPSC. On June 19, 2024, the LPSC approved Cleco Power’s new retail rate plan. The new retail rate plan became effective on July 1, 2024. If a refund of previously recorded revenue is required as a result of the LPSC’s review, the refund could result in a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. For more information about the current retail rate plan, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements -Note 14 - Regulation and Rates - FRP.”
Cleco Power’s next base rate case is required to be filed with the LPSC on or before June 30, 2026. The outcome of any future base rate case could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Dolet Hills Securitization
Cleco Power may not be able to securitize all costs associated with the retirement of the Dolet Hills Power Station and lignite mine closure.
Cleco Power is seeking securitization financing of stranded and decommissioning costs associated with the retirement of the Dolet Hills Power Station as well as deferred fuel and other mine-related closure costs. On April 19, 2024, the LPSC approved an uncontested settlement containing certain provisions. See Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review” for more information.
On November 27, 2024, the LPSC issued a financing order authorizing the securitization of costs related to the
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settlement, which became final and not subject to appeal on December 13, 2024. Management anticipates the securitization financing to close by the end of March 2025. However, a failure of the securitization financing to be consummated, whether at all or on the timeline anticipated by management, could result in a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
LPSC Audits
The LPSC conducts fuel audits that could result in Cleco Power making substantial refunds of previously recorded revenue.
Generally, Cleco Power’s cost of fuel used for electric generation and cost of purchased power are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC, which are performed at least every other year. For more information about Cleco Power’s current fuel audit, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Fuel Audits.”
Management is unable to predict or give a reasonable estimate of the possible range of the disallowance by the LPSC, if any, related to FAC filings. If a disallowance of fuel costs is ordered resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The LPSC conducts audits of environmental costs that could result in Cleco Power making substantial refunds of previously recorded revenue.
Cleco Power has an EAC that is used to recover from customers certain costs of environmental compliance. The costs eligible for recovery are prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the costs of reagents such as ammonia and limestone that are a part of the fuel mix used to reduce air emissions, among other things. These costs are subject to periodic review by the LPSC. For more information about LPSC audits related to environmental costs, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Environmental Audit.”
Management is unable to predict or give a reasonable estimate of the possible range of disallowance, if any, related to EAC filings. If a disallowance of environmental costs is ordered resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
FERC Audit
FERC conducts audits that could result in Cleco Power making refunds of previously recorded revenue.
Generally, Cleco Power records wholesale transmission revenue through approved formula rates, Attachment O of the MISO tariff, and certain grandfathered agreements. The calculation of the rate formulas, as well as FERC accounting and reporting requirements, are subject to periodic audits by FERC. For more information about FERC audits and reviews, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - FERC Audits and Reviews.” Management is unable to predict the timing of future audits and whether or not the outcome of such future audits will have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
MISO
MISO market operations could have a material adverse effect on the results of operations, generation revenues, energy supply costs, financial condition, or cash flows of the Registrants.
Cleco is a member of the MISO market region referred to as “MISO South,” which encompasses parts of Arkansas, Louisiana, Mississippi, and Texas. Dispatch of generation resources and generation volumes to the market is determined by MISO. Costs in the MISO South region are heavily influenced by commodity fuel prices, transmission congestion, dispatch of the generating assets owned by all market participants in the MISO South region, and the overall demand and generation availability in the region. MISO has issued, and may in the future issue, directives requiring market participants to implement controlled outages as a result of an emergency or reliability issues. Higher demand and the potential volatility thereof related to artificial intelligence, cryptocurrency mining, and other computer processing requiring increased power supply to support these activities may increase the intermittency and decrease the reliability of electric supply in the MISO market.
On June 1, 2023, due to generation resource retirements, increased reliance on intermittent resources, significant weather events with correlated generator outages, and declining excess reserve margins that are expected to profoundly impact future grid reliability, MISO transitioned from a traditional annual unforced capacity value to a seasonal accreditation capacity (“SAC”) value. MISO evaluates SAC values to assess generating unit capacity for Cleco’s planning reserve margin for each season. If Cleco is subject to a significant number of outages during critical instances, Cleco may not possess sufficient planning reserves to serve its needs and could be forced to purchase capacity from the MISO resource adequacy auction. Generally, Cleco Power recovers these costs through its FAC, which is subject to audit by the LPSC. If a disallowance of recovery resulting in a refund is ordered, it could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
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Reliability and CIP Standards Compliance
Cleco is subject to mandatory reliability and CIP standards. Fines and civil penalties are imposed on those who fail to comply with these standards.
NERC serves as the ERO with authority to establish and enforce mandatory reliability and CIP standards, subject to FERC approval, for users of the nation’s transmission system. FERC enforces compliance with these standards. New standards are being developed, and existing standards are continuously being modified.
As these standards continue to be adopted and modified, they may impose additional compliance requirements on Cleco Power, which may result in increased capital expenditures and operating expenses. Failure to comply with these standards can result in the imposition of material fines and civil penalties.
A NERC Reliability Standards Operating and Planning Audit and NERC CIP Audit are conducted at least every three years for Cleco Power. For more information on Cleco Power’s current and future audits, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition - Financial Condition - Regulatory and Other Matters - Market Structure - Wholesale Electric Markets - ERO.”
Management is unable to predict the financial outcome of any future audits or whether any findings will have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Environmental Compliance
Cleco’s costs of compliance with environmental laws and regulations are significant. The costs of compliance with new environmental laws and regulations, as well as the incurrence of incremental environmental liabilities, could be significant to the Registrants.
Cleco is subject to extensive environmental oversight by federal, state, and local authorities and is required to comply with numerous environmental laws and regulations related to air quality, water quality, waste management, natural resources, and health and safety. Cleco also is required to obtain and comply with numerous governmental permits in operating its facilities. Existing environmental laws, regulations, and permits could be revised or reinterpreted, and new laws and regulations could be adopted or become applicable to Cleco. The overturning of the Chevron doctrine on June 28, 2024, by the U.S. Supreme Court, which had provided for deference in certain cases to the relevant federal agency with regard to the interpretation of federal regulations, has introduced additional uncertainty going forward regarding existing and future federal regulations. As a result of any such changes, some of Cleco’s EGUs could be rendered uneconomical to maintain or operate and could prompt early retirement of certain generation units. Any legal obligation that would require Cleco to substantially reduce its emissions beyond present levels could require extensive mitigation efforts and could raise uncertainty about the future viability of some fossil fuels as fuel for new and existing EGUs. Cleco will evaluate potential solutions to comply with such regulations and monitor rulemaking and any legal matters impacting the proposed regulations. Cleco may incur significant capital expenditures or additional operating costs to comply with such revisions, reinterpretations, and new requirements. If Cleco were to fail to comply, it could be subject to civil or criminal liabilities and fines or may be forced to shut down or reduce
production from its facilities. Cleco cannot predict the timing or the outcome of pending or future legislative and rulemaking proposals.
Cleco Power may request from its customers recovery of its costs to comply with new environmental laws and regulations. If the LPSC were to deny Cleco Power’s request to recover all or part of its environmental compliance costs, there could be a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Wholesale Electric Service
Cleco’s business practices are regulated by FERC, and the wholesale rates of Cleco Power are subject to FERC’s triennial market power analysis. Cleco Power could lose the right to sell wholesale generation at market-based rates.
FERC requires a utility to pass a screening test as a condition for securing and/or retaining approval to sell electricity in wholesale markets at market-based rates. An updated market power analysis must be filed with FERC every three years or upon the occurrence of a change in status as defined by FERC regulation. Cleco filed its most recent triennial market power analysis in December 2023, and received FERC approval on December 13, 2024. The next triennial market power analysis is expected to be filed in December 2026. In the future, if FERC determines Cleco Power possesses generation market power in excess of certain thresholds, Cleco Power could lose the right to sell wholesale generation at market-based rates, which could result in a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
FINANCIAL RISKS
Commodity and Commercial Transactions
Cleco may enter into fuel supply contracts, energy hedge transactions, and/or commercial transactions with swap dealers, and suppliers. If risks related to these transactions are not managed effectively, they may have a material adverse effect on the liquidity, results of operations, or financial condition of the Registrants.
During its normal course of business, Cleco is exposed to uncertain market prices of electricity, natural gas, coal, and other commodities. Market price volatility can impact costs of fuel supply for generation, generation revenue, customer utility bills, and revenue from customers. To manage the risk of market price volatility, Cleco Power may enter into purchases or sales of certain physical and financial commodity contracts within established risk management guidelines.
The changes in fair value of transactions accounted for as derivatives under authoritative accounting guidance are deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. At settlement, realized gains or losses are included in Cleco Power’s FAC and are reflected on customer’s bills as a component of the fuel charge. Recovery of these costs included in Cleco Power’s FAC is subject to, and may be disallowed as part of, a prudency review or a periodic fuel audit conducted by the LPSC.
Because Cleco is subject to significant fluctuations caused by changes in market prices, Cleco is unable to accurately predict the effect that these transactions could have on its results of operations, financial condition, or cash flows.
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All risks associated with these transactions cannot be fully eliminated. Therefore, the judgements and assumptions made in the underlying decisions related to these transactions could have a material adverse effect on the liquidity, results of operations, financial condition, or cash flows of the Registrants.
Transmission Congestion
Transmission congestion could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Energy prices in the MISO market are based on LMP, which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have a higher LMP. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zones or result in transmission curtailments. Cleco Power is awarded and/or purchases FTRs in auctions facilitated by MISO. However, insufficient FTR allocations or increased FTR costs, due to negative congestion flows, may result in an unexpected increase in energy costs to Cleco Power’s customers. If a disallowance of additional fuel costs associated with congestion is ordered by the LPSC resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Counterparty Risk and Guarantees
Cleco may be required to provide credit support to its counterparties, which could have a material adverse effect on the Registrants’ liquidity.
Cleco may guarantee the performance of all or some of its commercial transaction obligations and may also be required to provide liquid counterparty credit support in the form of cash or cash equivalent collateral to secure all or part of those obligations. Downgrades in Cleco’s credit quality or changes in the market prices of transaction-related energy commodities could increase the collateral or margin required to be on deposit for the counterparty or clearing house. Changes in required credit support, notably increases to Cleco’s requirement to post capital, could have a material adverse effect on the Registrants’ liquidity.
Cleco is exposed to the risk that counterparties may not meet their performance obligations in the expected time frame or at all, which could have a material adverse effect on the operating and financial performance of the Registrants.
Counterparties may fail to fulfill their physical or financial obligations. Currently, Cleco has various relationships whereby amounts are owed to Cleco pursuant to specified terms. Additionally, Cleco expects to receive an additional $113.0 million from the Cleco Cajun Purchasers by June 2026, which is not contingent upon the post-divestiture performance of the divested business. If the counterparties fail to pay amounts due pursuant to these agreements, the Registrants’ financial condition, cash flows, or liquidity could be materially affected.
Cleco also has industry accepted master agreements in place with counterparties that provide credit default assurances. Some master agreements with counterparties contain provisions that require the counterparties to provide liquid credit support in the form of cash or letters of credit to
secure all or part of their obligations to Cleco. If the counterparties to these arrangements fail to perform, Cleco may enforce and recover the proceeds from the credit support provided; however, in the event of a default, credit support may not always be adequate to cover the related obligations. In such event, Cleco may incur losses in excess of amounts already paid from the credit support or due to an adverse replacement cost of the transaction and may be unable to collect liquidated damages.
The credit commitments of Cleco’s lenders under its bank facilities may not be honored for a variety of reasons, including unexpected periods of financial distress affecting such lenders, which could materially affect the adequacy of its liquidity sources.
Global Economic Environment and Uncertainty
Adverse capital market performance could result in reductions in the fair value of benefit plan assets and increase the Registrants’ liabilities related to such plans. Sustained declines in the fair value of the plan’s assets or sustained increases in plan liabilities could result in significant increases in funding requirements, which could adversely affect the Registrants’ liquidity and results of operations.
Performance of the capital markets affects the value of assets that are held in trust to satisfy future obligations under Cleco’s defined benefit pension plan. Sustained adverse market performance could result in lower rates of return for these assets than projected by Cleco and could increase Cleco’s funding requirements related to the pension plan. Additionally, changes in interest rates affect the present value of Cleco’s liabilities under the pension plan. Adverse changes in assumptions or adverse actual events could cause additional minimum contributions.
Cleco Credit Ratings
A downgrade in Cleco Holdings’ or Cleco Power’s credit ratings could result in an increase in their respective borrowing costs, a reduced pool of potential investors and funding sources, and a restriction on Cleco Power making distributions to Cleco Holdings.
Neither Cleco Holdings nor Cleco Power can assure that its current debt ratings will remain in effect for any given period of time or that one or more of its debt ratings will not be lowered or withdrawn entirely by a rating agency. If S&P, Moody’s, or Fitch were to downgrade Cleco Holdings’ or Cleco Power’s long-term ratings, particularly below investment grade, the value of their debt securities could be adversely affected. Downgrades of either Cleco Holdings’ or Cleco Power’s credit ratings could result in additional fees and higher interest rates for borrowings under their respective credit facilities and term loans. In addition, Cleco Holdings or Cleco Power, as the case may be, would likely be required to pay higher interest rates in future debt financings, may be subject to more onerous debt covenants, and their pool of potential investors and funding sources could decrease. In addition, the 2016 Merger Commitments provide for limitations on the amount of distributions that may be paid from Cleco Power to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit/issuer ratings. As a result, Cleco Power may be prohibited from making distributions to Cleco Holdings in the event of a ratings downgrade below investment grade.
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Cleco Power LLC’s Unsecured and Unsubordinated Obligations
Cleco Power LLC’s unsecured and unsubordinated obligations, including, without limitation, its senior notes, will be effectively subordinated to any secured debt of Cleco Power LLC and structurally subordinated to indebtedness and other liabilities and preferred equity of any of Cleco Power LLC’s subsidiaries.
Cleco Power LLC’s senior notes and its obligations under various loan agreements and refunding agreements with the Rapides Finance Authority, the Louisiana Public Facilities Authority, and other issuers of tax-exempt bonds for the benefit of Cleco Power LLC, are unsecured and rank equally with all of Cleco Power LLC’s existing and future unsecured and unsubordinated indebtedness. As of December 31, 2024, Cleco Power LLC had an aggregate of $1.5 billion of unsecured and unsubordinated indebtedness net of debt discount and debt expense. The unsecured and unsubordinated indebtedness of Cleco Power LLC will be effectively subordinated to, and thus have a junior position to, any secured debt that Cleco Power LLC may have outstanding from time to time (including any mortgage bonds) with respect to the assets securing such debt. Certain agreements entered into by Cleco Power LLC with other lenders that are unsecured provide that if Cleco Power LLC issues secured debt, Cleco Power LLC is obligated to grant these lenders the same security interest in certain assets of Cleco Power LLC. If such a security interest were to arise, it would further subordinate Cleco Power LLC’s unsecured and unsubordinated obligations.
As of December 31, 2024, Cleco Power LLC had no secured indebtedness outstanding. Cleco Power LLC may issue mortgage bonds in the future under any future Indenture of Mortgage, and holders of mortgage bonds would have a prior claim on certain Cleco Power LLC material assets upon dissolution, winding up, liquidation, or reorganization. Additionally, neither Cleco Power LLC nor its creditors, including holders of its senior notes, can use the assets of Cleco Securitization I to settle debts of Cleco Power LLC.
GENERAL RISK FACTORS
Presidential Administration
The new Presidential administration may propose substantial changes to environmental, fiscal, and tax policies that could have a material adverse effect on the Registrants’ business.
The new Presidential administration may propose substantial changes to environmental, fiscal, and tax policies, which may include comprehensive tax reform, and other objectives that may impact the results of operations, financial condition, or cash flows of the Registrants. Since taking office in January 2025, the new President has issued several executive orders designed to reduce regulatory burdens and prioritize domestic energy production. These executive orders include the withdrawal from the Paris Agreement, declaring a national emergency on energy, unleashing American energy, streamlining permitting processes, empowering consumer vehicle choice, and ending support for large wind farms, among other things. The executive orders issued by the new Presidential administration may result in the development of additional regulations or changes to existing regulations, and it is possible that these changes could adversely affect Cleco’s business. Until any such changes are enacted, management is
unable to determine the impact of any such changes on the Registrants’ business, results of operations, financial condition, or cash flows.
Taxes
Changes in taxation due to uncertain effects of various tax reform legislation as well as the inherent difficulty in quantifying potential tax effects of business decisions could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The Registrants make judgments regarding the utilization of existing income tax credits and the potential tax effects of various financial transactions and results of operations to estimate their obligations to taxing authorities. Tax obligations include income, franchise, property, sales and use, and employment-related taxes. These judgments may include reserves for potential adverse outcomes regarding tax positions that have been taken. Changes in federal, state, or local tax laws, adverse tax audit results, or adverse tax rulings on positions taken by the Registrants could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
The IRA of 2022 was signed into law on August 16, 2022. Management is still monitoring any potential impact the legislation could have on the Registrants. Cleco will access any changes in tax laws due to the new presidential administration. For more information related to the IRA of 2022’s tax and renewable provisions, see Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations - Overview - Tax Reform.”
Insurance
Cleco’s insurance coverage may not be sufficient and may become more costly to maintain.
Cleco currently has property, casualty, cybersecurity, and liability insurance policies in place to protect its employees, board of managers, and assets in amounts that it considers appropriate. Such policies are subject to certain limits and deductibles. Insurance coverage may not be available in the future at current costs, on commercially reasonable terms, or at all, and the insurance proceeds received for any loss of, or any damage to, any of Cleco’s facilities may not be sufficient to restore the loss or damage without a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Like other utilities that serve coastal regions, Cleco Power does not have insurance covering its transmission and distribution system, other than substations, because it believes such insurance to be cost prohibitive. In the future, Cleco Power may not be able to recover the costs incurred in restoring transmission and distribution properties following hurricanes or other natural disasters through issuance of storm recovery bonds or a change in Cleco Power’s regulated rates or otherwise, or any such recovery may not be timely granted. Therefore, Cleco Power may not be able to restore any loss of, or damage to, any of its transmission and distribution properties without a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
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Global Economic Uncertainty and Access to Capital
Disruptions in the capital and credit markets may adversely affect the Registrants’ cost of capital and ability to meet liquidity needs or access capital to operate and grow the business.
The Registrants’ business is capital intensive and dependent upon the Registrants’ respective abilities to access capital at reasonable rates and other terms. The Registrants’ liquidity needs could significantly increase in the event of a hurricane or other weather-related or unforeseen disaster or when there are spikes in the price of natural gas and other commodities. The occurrence of one or more contingencies could cause the financing needs of the Registrants to increase materially.
Events beyond the Registrants’ control, such as political uncertainty in the U.S. (including the ongoing debates related to the U.S. federal government budget), U.S. federal debt ceiling negotiations and the risk of a U.S. government shutdown (including potential credit rating downgrades as a result thereof), volatility and disruption in global capital and credit markets including those resulting from geopolitical events, increases or decreases in interest rates and uncertainty with regard thereto resulting from changes in the federal funds rate range targeted by the Federal Reserve, or other adverse developments that affect financial institutions may create uncertainty that could increase the cost of capital for the Registrants or impair their ability to access the capital markets, including the ability to draw on their respective bank credit facilities. While the Registrants have recently renewed their respective credit facilities as further discussed herein, the Registrants may be unable to predict the degree of success they will have in renewing or replacing their respective credit facilities in the future as they come up for renewal. Moreover, the size, terms, and covenants of any new credit facilities may not be comparable to, and may be more restrictive than, existing facilities. If the Registrants are unable to access the credit and capital markets on terms that are reasonable, they may have to delay raising capital, issue shorter-term securities, and/or bear an unfavorable cost of capital, which, in turn, could have a material adverse effect on the Registrants’ ability to fund capital expenditures or to service debt, or on the Registrants’ flexibility to react to changing economic and business conditions.
Inflation may negatively impact the results of operations, financial condition, or cash flows of the Registrants.
While the pace of inflation has moderated over the last two years, Cleco has observed that prices for equipment, materials, supplies, employee labor, and contractor services have continued to increase. Long-term inflationary pressures may result in such prices continuing to increase more quickly than expected. Increases in inflation raises costs for labor, materials, and services, and Cleco may be unable to secure these resources on economically acceptable terms or offset such costs with increased revenues, operating efficiencies, or cost savings, which may adversely impact the results of operations, financial condition, or cash flows of the Registrants.
ESG
Increased focus on and changing expectations regarding ESG programs, as well as failure to achieve ESG goals, may adversely impact the Registrants’ access to capital, results of operations, financial condition, or cash flows.
Stakeholder scrutiny of companies’ ESG practices has been increasing across numerous industries. In recent years, certain stakeholders, including an increasing number of investors and lenders, have started placing more importance on ESG criteria when making lending and investment decisions. The increased focus on and activism related to ESG may limit the Registrants’ access to capital or financing and/or increase the cost of capital or financing as some investors or lenders may elect to increase their required returns on capital offered to the Registrants or reallocate or not commit capital based on their assessment of the Registrants’ ESG profile. Furthermore, Cleco could also face the risk of climate-related litigation. Additionally, the Registrants’ failure to address and meet stakeholders’ ESG expectations, which continue to evolve, failure to report progress on ESG initiatives, or failure to achieve the ESG goals may negatively impact the Registrants’ reputation and business and, as a result, could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.
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ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
CLECO POWER
All of Cleco Power’s electric generating stations and electric operating properties are located in Louisiana. Cleco Power considers all of its properties to be well maintained, in good operating condition, and suitable for their intended purposes. For more information on Cleco Power’s generating facilities, see Item 1, “Business - Operations - Cleco Power.”
Electric Generating Stations
As of December 31, 2024, Cleco Power either owned or had an ownership interest in four steam electric generating stations, three combined cycle units, and one gas turbine with a combined rated capacity of 2,676 MW, and a combined electric net generating capacity of 2,519 MW. The net generating capacity is the result of capacity tests and operational tests performed in 2023 and 2024, as required by MISO. This amount reflects the maximum production capacity these units can sustain over a specified period of time. For more information on Cleco Power’s generating facilities, see Item 1, “Business - Operations - Cleco Power.”
Electric Substations
As of December 31, 2024, Cleco Power owned 94 active transmission substations and 251 active distribution substations.
Electric Lines
As of December 31, 2024, Cleco Power’s transmission system consisted of 67 circuit miles of 500-kiloVolt (kV) lines; 609 circuit miles of 230-kV lines; 682 circuit miles of 138-kV lines; and 29 circuit miles of 69-kV lines. Cleco Power’s distribution system consisted of 3,445 circuit miles of 34.5-kV lines and 8,874 circuit miles of other lines.
General Properties
Cleco Power owns various properties throughout Louisiana, which include a headquarters office building, regional offices, service centers, telecommunications equipment, and other general-purpose facilities.
Title
Cleco Power’s electric generating plants and certain other principal properties are owned in fee simple. Electric transmission and distribution lines are located either on private rights-of-way or along streets or highways by public consent.

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
CLECO
For information on legal proceedings affecting Cleco, see Item 1, “Business - Environmental Matters - Air Quality,” Item 1A, “Risk Factors - Operational Risks - Litigation,” and Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation.”
CLECO POWER
For information on legal proceedings affecting Cleco Power, see Item 1, “Business - Environmental Matters - Air Quality” and Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation.”

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
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PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5. MARKET FOR REGISTRANTS’ COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES
CLECO HOLDINGS
There is no established public trading market for Cleco Holdings’ membership interests. All of Cleco Holdings’ outstanding membership interests are owned by Cleco Group.
Cleco Holdings’ credit facility requires a total indebtedness of less than or equal to 65.0% of total capitalization in order to declare dividend payments. Additionally, in accordance with the 2016 Merger Commitments, Cleco Holdings is subject to certain provisions limiting the amount of distributions that may be paid from Cleco Holdings to Cleco Group or Cleco Partners, depending on Cleco Holdings’ debt to EBITDA ratio and its corporate credit ratings.
Cleco Holdings made $145.0 million, $53.5 million, and $219.6 million of distributions to Cleco Group during 2024, 2023, and 2022, respectively.
Cleco Holdings received no equity contributions from Cleco Group during 2024, 2023, and 2022.
CLECO POWER
There is no market for Cleco Power’s membership interests. All of Cleco Power’s outstanding membership interests are owned
by Cleco Holdings. Distributions on Cleco Power’s membership interests are paid when and if declared by Cleco Power’s Board of Managers. Any future distributions also may be restricted by any credit or loan agreements into which Cleco Power may enter.
Some provisions in Cleco Power’s debt instruments restrict the amount of equity available for distribution to Cleco Holdings by Cleco Power by requiring Cleco Power’s total indebtedness to be less than or equal to 65.0% of total capitalization. In addition, the 2016 Merger Commitments provide for limitations on the amount of distributions that may be paid from Cleco Power to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit ratings.
Cleco Power made $95.0 million, $94.8 million, and $105.5 million of distributions to Cleco Holdings in 2024, 2023, and 2022, respectively.
Cleco Power received no equity contributions from Cleco Holdings in 2024, 2023, and 2022.

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. RESERVED

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion is intended to assist in understanding Cleco’s results of operations and Cleco’s present financial condition. Cleco’s historical consolidated financial statements and the accompanying notes included elsewhere in this Annual Report on Form 10-K contain additional information that should be referred to when reviewing this material.
Cleco uses its website, https://www.cleco.com, as a routine channel for distribution of important information, including news releases and financial information. Cleco’s website is the primary source of publicly disclosed news about Cleco. Cleco is providing the address to its website solely for informational purposes and does not intend for the address to be an active link. The contents of the website are not incorporated into this Annual Report on Form 10-K.
OVERVIEW
Cleco is a regional energy company that conducts substantially all of its business operations through its principal operating business segment, Cleco Power. Cleco Power is a regulated electric utility company that owns eight generating units with a total rated capacity of 2,676 MW and serves approximately 295,000 customers in Louisiana through its retail business and supplies wholesale power in Louisiana.
Many factors affect Cleco’s primary business of generating, delivering, and selling electricity. These factors include the ability to increase energy sales while containing costs and the ability to successfully perform in MISO while
subject to the related operating challenges and uncertainties. In addition, factors affecting Cleco Power include weather and the presence of a stable regulatory environment, which impacts the ROE and future rate cases, as well as the recovery of costs related to storms, growing energy demand, and volatile fuel prices; the ability to reliably deliver power to its jurisdictional customers; and the ability to comply with increasingly stringent regulatory and environmental standards. Significant events and major initiatives impacting Cleco and Cleco Power are discussed below.
FRP
On June 19, 2024, the LPSC approved Cleco Power’s new retail rate plan. Effective July 1, 2024, under the terms of the new FRP, Cleco Power is allowed to earn a target ROE of 9.7%, while providing the opportunity to earn up to 10.3%. Additionally, 60.0% of retail earnings between 10.3% and 10.9%, and all retail earnings over 10.9%, are required to be refunded to customers. The amount of credits due to customers, if any, is determined by Cleco Power and the LPSC annually. For information on Cleco Power’s new FRP, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - FRP.”
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Cleco Cajun Divestiture
In March 2023, Cleco Holdings’ management, with the support of its Board of Managers, committed to a plan of action for the disposition of the Cleco Cajun Sale Group. The results of operations and financial position of the Cleco Cajun Sale Group have been presented as discontinued operations since March 31, 2023. On June 1, 2024, the Cleco Cajun Divestiture closed. For more information, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
Dolet Hills
Cleco Power is seeking securitization financing of stranded and decommissioning costs associated with the retirement of the Dolet Hills Power Station as well as deferred fuel and other costs associated with the closure of the Oxbow mine. Management anticipates the securitization financing to close by the end of March 2025.
For more information, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
ESG
Cleco is accelerating its efforts to protect the environment, manage social relationships, govern responsibly, and ensure accountability. To protect the environment, Cleco is increasing its renewable and electrification initiatives. Cleco is also aiming to reduce GHG emissions in ways such as incorporating renewable energy resources into its generating fleet, as it replaces coal-fired generation units retired after serving their useful lives. Cleco aims to sustainably reduce its GHG emissions from its generating fleet by approximately 50.0% by 2035 with aspirations of net zero emissions by 2050. Cleco’s ability to meet these targets depends heavily on real-world factors such as policy changes, load growth, and technological advancements. To manage social relationships, Cleco plans to ensure that the electricity that it generates is affordable, reliable, and sustainable. Cleco also continues to support community investment opportunities across its service territory and has created a workforce culture that rewards inclusion, safety, and innovation. To govern responsibly, Cleco plans to continue operating according to policies and practices that support the governance framework. To ensure accountability, Cleco has created an ESG Steering Committee and appointed a Chief Administrative and Sustainability Officer to oversee the continued implementation of ESG initiatives. Currently, management is unable to predict the impact of implementing these ESG initiatives on the Registrants. For more information on these ESG goals, see Part I, Item 1, “Business - Human Capital - Communities” and “- Oversight and Governance.” For more information about Cleco’s environmental initiatives, see “- Renewable and Electrification Initiatives.”
Tax Reform
On August 16, 2022, the IRA of 2022 became law. The IRA of 2022 seeks to lower gasoline and electricity prices, increase energy security, and help consumers afford emissions-cutting technologies. In addition, the IRA of 2022 provides tax credits for clean electricity sources and energy storage, as well as creates programs to enable states and electric utilities to transition to clean power. There are several tax and
renewables provisions in this legislation that could have a material effect on the results of operations, financial condition, or cash flows of the Registrants. These include provisions related to direct pay and credit transferability, enhanced carbon capture and sequestration credits, new technology-neutral clean energy investment credits, and new technology-neutral clean energy production credits. These credits are expected to help fund future renewable and electrification projects. Management continues to monitor any potential impacts the IRA of 2022 could have on the Registrants, including the changes resulting from the new presidential administration.
On December 4, 2024, the Louisiana state corporate income tax rate decreased from 7.5% to 5.5%, effective for the income tax periods beginning on or after January 1, 2025.
Decarbonization Initiatives
In April 2022, Cleco Power announced Project Diamond Vault, a proposed project with the goal of reducing up to 95% of carbon dioxide emissions from Madison Unit 3 through various possible carbon capture and sequestration technologies. Development efforts using an amine-based carbon capture technology began in 2022. Due to increases in the estimated investment required as well as the current economic and financing environment, Cleco Power’s management decided to evaluate other potential carbon capture and sequestration technologies or alternatives to decarbonize Madison Unit 3, including fuel switching technology. For more information on Project Diamond Vault, see, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Property, Plant, and Equipment.”
Management is considering the most economically viable decarbonization strategy and remains committed to addressing Cleco Power’s carbon output of its solid fuel generating unit and ESG goals to sustainably reduce its GHG emissions.
For more information on environmental matters that could affect Madison Unit 3 and Cleco Power’s decarbonization initiatives, see Item 1 ”Business - Environmental Matters.”
Renewable and Electrification Initiatives
In July 2022, Cleco Power entered into a long-term agreement to purchase, among other things, the output, capacity, and current and future environmental resource credits of a 240-MW solar electric generation facility to be constructed in DeSoto Parish, Louisiana and owned by a third party. In September 2024, the LPSC approved the agreement, including the recovery of $2.1 million of incurred development costs. The LPSC also approved Cleco Power’s recovery of future costs to construct, own, operate, and maintain the transmission line necessary to deliver the energy from the solar generation facility to Cleco Power’s transmission grid. Cleco Power expects to begin receiving output from this facility by 2027. For information about the regulatory asset associated with Cleco Power’s solar development costs, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities - Solar Development Costs.”
Cleco Power is seeking to replace or supplement certain existing power supply resources with products identified in Cleco Power’s most recent IRP. The IRP indicated that a portfolio providing up to approximately 500MW of renewable resources and up to 150MW of battery storage would provide
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an effective addition to Cleco Power’s current generation portfolio. On December 30, 2024, Cleco Power filed a draft request for proposal (RFP) that outlines the resources and transaction structures that Cleco Power is seeking from bidders. Market comments on the draft RFP were due on February 28, 2025, and management expects to file and issue the final RFP on April 4, 2025. Bid submissions to the RFP are due on May 26, 2025.
Cleco Power is also pursuing electrification initiatives for its customers such as gas compression, e-trucking, green tariffs, residential heating programs, and increasing the supply of light duty electric vehicles and forklifts, among others.
Cleco Power is seeking available funds from the U.S. government for funding of these electrification initiatives. Cleco Power cannot predict the likelihood that any funding from the U.S. government ultimately will be approved.
DSMART Project
The DSMART project includes modernization of Cleco Power’s distribution system by replacing or upgrading distribution line equipment to utilize new and emerging technologies to facilitate automatic fault isolation, service restoration, and fault location. The project is expected to provide savings through a reduction in outage restoration time and improve operational efficiencies and time to locate faults. The project is also expected to improve safety and reliability of Cleco Power’s distribution assets by minimizing outage patrols and improving situational awareness in the distribution operations center. The total estimated project cost is $105.0 million. The project implementation will be completed in phases, and management expects the total project will be completed by the end of 2028. Cleco Power is currently in the second phase of the project. As of December 31, 2024, Cleco Power had spent $70.8 million on the project.
Grid Resiliency and Hardening
In 2023, the LPSC Staff proposed a final rule for LPSC consideration and adoption setting guidelines and requirements for utilities to develop grid resilience plans in an effort to enhance the state of Louisiana’s collective ability to withstand, adapt to, and recover from risks posed to the electric system. Management is unable to determine the outcome and timing of approval of this proposed rule.
Cleco Power is actively participating in programs to enhance its grid resilience against growing threats of extreme weather and climate change. These may include potential hardening projects aimed at reinforcing or replacing critical infrastructure on Cleco Power’s transmission and distribution systems with materials that can better withstand extreme weather events, avoid or mitigate customer outages from such events, and facilitate faster restoration after such events. The grid resiliency plan is a 10-year plan that identifies an estimated 1,400 projects with a total investment of approximately $510.0 million. In December 2024, Cleco Power filed an application with the LPSC for approval of Phase 1 of the plan which includes recovery of $257.6 million for 781 projects over 5 years.
Data Centers
As a result of the growing demand of data centers, driven by the use of artificial intelligence, the electric industry has opportunity for significant future load growth, and Cleco Power shares in that opportunity. Cleco is pursuing potential long-term agreements to supply power to large load facilities. Such
potential transactions are subject to certain risks and uncertainties, including regulatory review and/or approval and adverse legislative action, which could impact the timing and ability to consummate a transaction.
Other
Cleco Power is working to secure load growth opportunities that include renewing existing franchises, pursuing new franchises, and adding new retail load opportunities with large industrial, commercial, and residential customers. The retail opportunities include sectors such as agriculture, oil and gas, chemicals, metals, national accounts, government, military, wood, paper, health care, information technology, transportation, clean and green fuels, and other manufacturing.
On March 31, 2024, a contract with a significant wholesale customer expired and was not renewed with Cleco Power. The absence of this agreement affected jurisdictional retail rates that were reviewed by the LPSC in conjunction with Cleco Power’s most recent rate case. The LPSC approved Cleco Power’s new rate plan effective July 1, 2024.
RESULTS OF OPERATIONS
Use of Estimates
The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ materially from those estimates.
Comparison of the Years Ended December 31, 2024, and 2023
Cleco
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/(UNFAVORABLE)
(THOUSANDS) 2024 2023 VARIANCE CHANGE
Operating revenue, net
$ 1,147,708 $ 1,238,791 $ (91,083) (7.4) %
Operating expenses 920,229 1,179,323 259,094 22.0 %
Operating income 227,479 59,468 168,011 282.5 %
Interest income
15,067 5,393 9,674 179.4 %
Allowance for equity funds used during construction 2,310 5,747 (3,437) (59.8) %
Equity income from investees, before tax 677 - 677 100.0 %
Other expense, net (13,021) (694) (12,327) *
Interest charges
153,555 164,856 11,301 6.9 %
Federal and state income tax expense (benefit) 14,056 (65,073) (79,129) (121.6) %
Income (loss) from continuing operations, net of income taxes 64,901 (29,869) 94,770 317.3 %
Income from discontinued operations, net of income taxes 45,517 14,642 30,875 210.9 %
Net income (loss) $ 110,418 $ (15,227) $ 125,645 825.1 %
* Not meaningful
CLECO
CLECO POWER 2024 FORM 10-K
The increase in Cleco’s results of operations is primarily attributable to the following:
•lower losses on gas-related derivative contracts at Cleco Cajun of $110.3 million which are included in continuing operations.
•the effects of the presentation of the Cleco Cajun Sale Group as discontinued operations and, as a result, Cleco Cajun no longer being reflected as a reportable segment. For information on discontinued operations, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
•activity of its reportable segment, Cleco Power. For detailed discussions of those impacts, see “- Cleco Power.”
•lower interest expense at Cleco Holdings of $11.1 million primarily due to the repayment of the $66.7 million bank term loan in April 2024, the redemption of $165.0 million floating rate senior notes in June 2024, and the voluntary tender offer for its senior notes due in May 2026 in an aggregate principal amount of $175.0 million. For more information, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 10 - Debt.”
•higher interest earned on temporary investments in 2024 and interest on the receivable from the Cleco Cajun Purchasers due to the close of the Cleco Cajun Divestiture. For information on the receivable from the Cleco Cajun Purchasers, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
These increases were partially offset by changes in federal and state income taxes. For more information on Cleco’s effective income tax rates on continuing operations, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 12 - Income Taxes - Cleco.”
Cleco Power
Significant Factors Affecting Cleco Power
Revenue is primarily affected by the following factors:
As an electric utility, Cleco Power is affected, to varying degrees, by a number of factors influencing the electric utility industry. These factors, among others, include:
•an increasingly competitive business environment,
•the ability to recover costs through rate-setting proceedings,
•the ability to successfully perform in MISO and the related operating challenges,
•the cost of compliance with environmental and reliability regulations,
•conditions in the credit markets and global economy,
•changes in the federal and state regulation of generation, transmission, and the sale of electricity, and
•the increasing uncertainty of future federal and state regulatory and environmental policies.
For a discussion of various regulatory changes and competitive forces affecting Cleco Power and other electric utilities, see “Cautionary Note Regarding Forward-Looking Statements,” Part I, Item 1, “Business - Regulatory Matters, Industry Developments, and Franchises,” and “- Financial
Condition - Regulatory and Other Matters - Market Structure.” For a discussion of risk factors affecting Cleco Power’s business, see Part I, Item 1A, “Risk Factors.”
Cleco Power’s residential customers’ demand for electricity is affected largely by weather. Weather is generally measured in cooling degree-days and heating degree-days. A high number of cooling degree-days may indicate consumers will use more air conditioning, while a high number of heating degree-days may indicate consumers will use more heating. An increase in heating degree-days does not produce the same increase in revenue as an increase in cooling degree-days because alternative heating sources are more readily available, and winter energy is typically priced below the rate charged for energy used in the summer. Normal heating degree-days and cooling degree-days are calculated for a month by separately calculating the average actual heating and cooling degree-days for that month over a period of 30 years.
Over the last five years, Cleco Power’s non-industrial retail sales have been relatively steady; however, there have been fluctuations in industrial retail sales. Cleco Power anticipates moderate growth in retail sales over the next five years. Cleco Power expects to begin providing service to expansions of current customers’ operations, as well as service to new retail customers. Cleco Power’s expectations and projections regarding retail sales are dependent upon factors such as weather conditions, natural gas prices, customer conservation efforts, retail marketing and business development programs, and the economy of Cleco Power’s service area. Cleco Power is pursuing load growth opportunities that include renewal of existing franchises as well as adding new franchises. For more information on other expectations of future energy sales on Cleco Power, see “Cautionary Note Regarding Forward-Looking Statements,” and Part I, Item 1A, “Risk Factors - Operational Risks - Future Electricity Sales.”
Other issues facing the electric utility industry that could affect sales include:
•imposition of federal and/or state renewable portfolio standards,
•imposition of energy efficiency mandates without recovery of lost revenues,
•legislative and regulatory changes, including changes resulting from the new presidential administration.
•increases in environmental regulations and compliance costs,
•cost of power impacted by the price movement of fuels and the addition of new generation capacity,
•transmission congestion costs,
•increases in capital and operations and maintenance costs due to higher construction and labor costs,
•changes in electric rates compared to customers’ ability to pay,
•changes in the credit markets and local and global economies, and
•the LPSC’s consideration of adopting minimum physical capacity threshold requirements for load serving entities.
For more information on energy legislation in regulatory matters that could affect Cleco, see Part I, Item 1, “Business - Regulatory Matters, Industry Developments, and Franchises - Legislative and Regulatory Changes and Matters.”
Cleco Power’s revenues and earnings are substantially affected by regulatory proceedings known as rate cases, or in
CLECO
CLECO POWER 2024 FORM 10-K
some cases, a request for extension of an FRP. During those cases, the LPSC determines Cleco Power’s rate base, depreciation rates, operation and maintenance costs, and administrative and general costs that Cleco Power may recover from its retail customers through its rates. Generally, historical costs are used by the LPSC in determining Cleco Power’s rates. These proceedings may examine, among other things, the prudency of Cleco Power’s operation and maintenance practices, level of expenditures, allowed rates of return, and previously incurred capital expenditures. The LPSC has the authority to disallow costs found not to have been prudently incurred. Rate cases generally have timelines of approximately one year, and decisions are typically subject to appeal, potentially leading to additional uncertainty. Cleco Power’s new FRP became effective on July 1, 2024. Cleco Power’s next base rate case is required to be filed with the LPSC on or before June 30, 2026. The transmission tariffs of Cleco Power are regulated by FERC with its own regulatory proceedings. Both the LPSC and FERC regulatory proceedings can involve multiple parties, including governmental bodies and officials, consumer advocacy groups, and various consumers of energy, all of whom have differing concerns but who have the common objective of limiting rate increases or reducing rates.
For more information on Cleco Power’s FRP see “-Overview - FRP.”
Expenses are primarily affected by the following factors:
The majority of Cleco Power’s non-fuel cost recovery expenses include:
•other operations expenses that are affected by, among other things, the cost of employee benefits, insurance expense, and the costs associated with energy delivery and customer service,
•maintenance expenses for Cleco Power’s generating plants, which generally depend upon the plant’s physical characteristics, maintenance practices, and effectiveness of preventive maintenance programs,
•maintenance expenses of transmission and distribution assets, which are generally affected by the level of repair and rehabilitation of lines to maintain reliability,
•depreciation and amortization expense, which is primarily affected by the cost of the facilities in service, the time the facilities were placed in service, and the estimated useful life of the facilities,
•taxes other than income taxes, which generally include payroll taxes, franchise taxes, and property taxes, and
•interest charges, which are generally affected by interest rates on outstanding debt.
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/(UNFAVORABLE)
(THOUSANDS) 2024 2023 VARIANCE CHANGE
Operating revenue
Base $ 729,273 $ 692,866 $ 36,407 5.3 %
Fuel cost and purchased power recovery
321,980 504,503 (182,523) (36.2) %
Electric customer credits
(3,940) (60,689) 56,749 93.5 %
Other operations 95,137 111,561 (16,424) (14.7) %
Affiliate revenue 12,452 8,904 3,548 39.8 %
Operating revenue, net
1,154,902 1,257,145 (102,243) (8.1) %
Operating expenses
Recoverable fuel and purchased power
321,980 504,512 182,532 36.2 %
Non-recoverable fuel and purchased power
32,752 45,485 12,733 28.0 %
Other operations and maintenance
245,651 233,863 (11,788) (5.0) %
Depreciation and amortization
236,444 191,745 (44,699) (23.3) %
Taxes other than income taxes
57,754 60,676 2,922 4.8 %
Total operating expenses
894,581 1,036,281 141,700 13.7 %
Operating income 260,321 220,864 39,457 17.9 %
Interest income 4,125 5,011 (886) (17.7) %
Allowance for equity funds used during construction
2,310 5,747 (3,437) (59.8) %
Equity income from investees, before tax
677 - 677 100.0 %
Other expense, net (11,151) (28) (11,123) *
Interest charges
98,858 98,879 21 - %
Federal and state income tax expense (benefit) 18,506 (4,434) (22,940) (517.4) %
Net income $ 138,918 $ 137,149 $ 1,769 1.3 %
* Not meaningful
The following table shows the components of Cleco Power’s retail and wholesale customer sales related to base revenue:
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/
(MILLION kWh) 2024 2023 (UNFAVORABLE)
Electric sales
Residential 3,678 3,772 (2.5) %
Commercial 2,701 2,723 (0.8) %
Industrial 2,275 2,229 2.1 %
Other retail 124 124 - %
Total retail 8,778 8,848 (0.8) %
Sales for resale 927 2,980 (68.9) %
Total retail and wholesale customer sales
9,705 11,828 (17.9) %
CLECO
CLECO POWER 2024 FORM 10-K
The following table shows the components of Cleco Power’s base revenue:
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/
(THOUSANDS) 2024 2023 (UNFAVORABLE)
Electric sales
Residential $ 351,309 $ 322,729 8.9 %
Commercial 227,829 201,270 13.2 %
Industrial 116,423 95,707 21.6 %
Other retail 12,874 11,663 10.4 %
Total retail 708,435 631,369 12.2 %
Sales for resale 20,838 61,497 (66.1) %
Total base revenue
$ 729,273 $ 692,866 5.3 %
The following chart shows how cooling and heating degree-days varied from normal conditions and from the prior period. Cleco Power uses weather data provided by the National Oceanic and Atmospheric Administration to determine degree-days.
FOR THE YEAR ENDED DEC. 31,
2024 CHANGE
2024 2023 NORMAL PRIOR YEAR NORMAL
Cooling degree-days 3,377 3,707 2,920 (8.9) % 15.7 %
Heating degree-days 1,152 1,057 1,477 9.0 % (22.0) %
Base
Base revenue increased $36.4 million primarily due to $72.7 million of higher rates largely resulting from the implementation of Cleco Power’s new retail rate plan. Also contributing to the increase was $6.4 million of higher demand charges from new industrial customers in the third quarter of 2023, and $4.7 million relating to the recognition of the allowed carrying charge on the related Dolet Hills regulatory asset. These increases were partially offset by $34.7 million of lower wholesale revenue due to the expiration of a wholesale contract in March 2024 and $12.8 million of lower usage from milder summer weather compared to 2023. For more information on the Dolet Hills carrying charge, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities - Dolet Hills Carrying Charge.”
For more information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see “- Significant Factors Affecting Cleco Power,” “Cautionary Note Regarding Forward-Looking Statements,” and Part I, Item 1A, “Risk Factors - Operational Risks - Future Electricity Sales.”
Fuel Cost and Purchased Power Recovery/Recoverable Fuel and Purchased Power
Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such expenses. Approximately 89% of Cleco Power’s total fuel cost during 2024 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating
facilities by MISO. Cleco Power’s incremental recoverable fuel and purchased power expenses for the year ended December 31, 2024, were impacted primarily by lower natural gas costs as compared to the year ended December 31, 2023. For more information on the accounting for MISO transactions, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Accounting for MISO Transactions.” For more information on Cleco Power’s most current fuel audits, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Fuel Audits.”
Electric Customer Credits
Electric customer credits decreased $56.7 million primarily due to the absence of the partial disallowance associated with the Dolet Hills prudency review. For information on the Dolet Hills prudency review, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
Other Operations Revenue
Other operations revenue decreased $16.4 million primarily due to lower transmission revenue resulting from the expiration of a wholesale contract in March 2024.
Non-Recoverable Fuel and Purchased Power
Non-recoverable fuel and purchased power decreased $12.7 million primarily due to lower transmission costs resulting from the expiration of a wholesale contract in March 2024.
Other Operations and Maintenance
Other operations and maintenance increased $11.8 million primarily due to $9.6 million of higher employee-related expenses largely resulting from the transfer of employees from Support Group and Cleco Cajun to Cleco Power and $1.9 million of higher outside service costs primarily related to legal fees.
Depreciation and Amortization
Depreciation and amortization increased $44.7 million primarily due to a $40.0 million reduction in the regulatory asset associated with the Dolet Hills Power Station as a result of the settlement of the Dolet Hills prudency review. The increase was also due to $3.8 million for higher normal recurring additions to fixed assets and $2.9 million for changes in estimated useful lives of internal software. For more information on the reduction in the regulatory asset associated with the Dolet Hills Power Station and the settlement of the Dolet Hills prudency review, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities” - “Deferred Lignite and Mine Closure Costs and Dolet Hills Power Station Closure Costs” and - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
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CLECO POWER 2024 FORM 10-K
Other Expense, Net
Other expense, net increased $11.1 million primarily due to expenses relating to Project Diamond Vault. For more information, see “- Overview - Decarbonization Initiatives.”
Income Taxes
For information on Cleco Power’s effective income tax rates, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 12 - Income Taxes - Cleco Power.”
Comparison of the Years Ended December 31, 2023, and 2022
Cleco
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/(UNFAVORABLE)
(THOUSANDS) 2023 2022 VARIANCE CHANGE
Operating revenue, net $ 1,238,791 $ 1,604,480 $ (365,689) (22.8) %
Operating expenses 1,179,323 1,205,091 25,768 2.1 %
Operating income 59,468 399,389 (339,921) (85.1) %
Interest income
5,393 5,250 143 2.7 %
Allowance for equity funds used during construction 5,747 3,740 2,007 53.7 %
Other expense, net (694) (11,240) 10,546 93.8 %
Interest charges
164,856 143,956 (20,900) (14.5) %
Federal and state income tax (benefit) expense (65,073) 20,035 85,108 424.8 %
(Loss) income from continuing operations, net of income taxes (29,869) 233,148 (263,017) (112.8) %
Income (loss) from discontinued operations, net of income taxes 14,642 (44,337) 58,979 133.0 %
Net (loss) income $ (15,227) $ 188,811 $ (204,038) (108.1) %
The decrease in Cleco’s results of operations is primarily attributable to the following:
•lower gains on gas-related derivative contracts, net of income taxes, at Cleco Cajun of $217.3 million included in continuing operations.
•activity of its reportable segment, Cleco Power. For detailed discussions of those impacts, see “- Cleco Power.”
These decreases were partially offset by the effects of the presentation of the Cleco Cajun Sale Group as discontinued operations and, as a result, Cleco Cajun no longer being reflected as a reportable segment. For information on discontinued operations, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
For information on Cleco’s effective income tax rates, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 12 - Income Taxes - Cleco.”
Cleco Power
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/(UNFAVORABLE)
(THOUSANDS) 2023 2022 VARIANCE CHANGE
Operating revenue
Base $ 692,866 $ 685,419 $ 7,447 1.1 %
Fuel cost and purchased power recovery
504,503 837,647 (333,144) (39.8) %
Electric customer credits
(60,689) (7,674) (53,015) (690.8) %
Other operations 111,561 98,759 12,802 13.0 %
Affiliate revenue 8,904 6,377 2,527 39.6 %
Operating revenue, net
1,257,145 1,620,528 (363,383) (22.4) %
Operating expenses
Recoverable fuel and purchased power
504,512 837,647 333,135 39.8 %
Non-recoverable fuel and purchased power
45,485 59,846 14,361 24.0 %
Other operations and maintenance
233,863 216,851 (17,012) (7.8) %
Depreciation and amortization
191,745 178,231 (13,514) (7.6) %
Taxes other than income taxes
60,676 55,075 (5,601) (10.2) %
Regulatory disallowance - 13,841 13,841 100.0 %
Total operating expenses
1,036,281 1,361,491 325,210 23.9 %
Operating income 220,864 259,037 (38,173) (14.7) %
Interest income 5,011 5,082 (71) (1.4) %
Allowance for equity funds used during construction
5,747 3,740 2,007 53.7 %
Other expense, net (28) (7,081) 7,053 99.6 %
Interest charges 98,879 88,218 (10,661) (12.1) %
Federal and state income tax (benefit) expense (4,434) 2,503 6,937 277.1 %
Net income $ 137,149 $ 170,057 $ (32,908) (19.4) %
The following table shows the components of Cleco Power’s retail and wholesale customer sales related to base revenue:
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/
(MILLION kWh) 2023 2022 (UNFAVORABLE)
Electric sales
Residential 3,772 3,787 (0.4) %
Commercial 2,723 2,674 1.8 %
Industrial 2,229 2,282 (2.3) %
Other retail 124 121 2.5 %
Total retail 8,848 8,864 (0.2) %
Sales for resale 2,980 3,061 (2.6) %
Total retail and wholesale customer sales
11,828 11,925 (0.8) %
CLECO
CLECO POWER 2024 FORM 10-K
The following table shows the components of Cleco Power’s base revenue:
FOR THE YEAR ENDED DEC. 31,
FAVORABLE/
(THOUSANDS) 2023 2022 (UNFAVORABLE)
Electric sales
Residential $ 322,729 $ 322,545 0.1 %
Commercial 201,270 200,031 0.6 %
Industrial 95,707 90,243 6.1 %
Other retail 11,663 11,032 5.7 %
Total retail 631,369 623,851 1.2 %
Sales for resale 61,497 61,568 (0.1) %
Total base revenue
$ 692,866 $ 685,419 1.1 %
The following chart shows how cooling and heating degree-days varied from normal conditions and from the prior period. Cleco Power uses weather data provided by the National Oceanic and Atmospheric Administration to determine cooling and heating degree-days.
FOR THE YEAR ENDED DEC. 31,
2023 CHANGE
2023 2022 NORMAL PRIOR YEAR NORMAL
Cooling degree-days 3,707 3,095 2,920 19.8 % 27.0 %
Heating degree-days 1,057 1,650 1,477 (35.9) % (28.4) %
Base
Base revenue increased $7.4 million primarily due to $4.9 million of higher industrial demand. Industrial demand increased primarily due to new industrial customers in 2023. Also contributing to the increase was $1.4 million of higher rates, largely related to the infrastructure and incremental cost recovery rider. Although higher than normal temperatures were experienced during the summer of 2023 which contributed to an increase in base revenue, the lower usage from milder winter weather during 2023 offset this increase resulting in no meaningful impact to the overall base revenue variance for 2023.
For more information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see “- Significant Factors Affecting Cleco Power,” “Cautionary Note Regarding Forward-Looking Statements,” and Part I, Item 1A, “Risk Factors - Operational Risks - Future Electricity Sales.”
Fuel Cost and Purchased Power Recovery/Recoverable Fuel and Purchased Power
Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such expenses. Approximately 77% of Cleco Power’s total fuel cost during 2023 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating facilities by MISO. Cleco Power’s incremental recoverable fuel and purchased power expenses for the year ended December 31, 2023, were impacted primarily by lower natural gas costs as compared to the year ended December 31, 2022. For more
information on the accounting for MISO transactions, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Accounting for MISO Transactions.” For more information on Cleco Power’s most current fuel audits, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Fuel Audits.”
Electric Customer Credits
Electric customer credits increased $53.0 million primarily due to $58.7 million for the accrual of an estimated contingency loss related to the probability of a partial disallowance of the recovery of incurred fuel costs associated with the Dolet Hills prudency review. This increase was partially offset by $5.7 million for the absence of a 2022 refund to Cleco Power’s retail customers related to the St. Mary Clean Energy Center for costs recovered in periods prior to September 30, 2022. For information, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
Other Operations Revenue
Other operations revenue increased $12.8 million primarily due to $20.8 million for a full year of storm recovery collection in 2023 compared to four months of storm recovery collection in 2022, partially offset by $6.7 million of lower MISO transmission revenue from lower usage.
Non-Recoverable Fuel and Purchased Power
Non-recoverable fuel and purchased power decreased $14.4 million primarily due to $8.6 million for the timing of recovery of transmission costs and $4.7 million of lower fuel expense primarily due to the expiration of wholesale contracts in December 2022 and May 2023.
Other Operations and Maintenance
Other operations and maintenance increased $17.0 million primarily due to $14.7 million of higher employee-related expenses largely related to employee benefits. Also contributing to the increase was $3.1 million of higher routine distribution maintenance expenses, $2.8 million of higher outside service costs primarily related to information technology support and consulting, $2.2 million of higher distribution operations expenses, and $2.1 million of higher reserve for credit losses. These increases were partially offset by $8.2 million of lower generating outage maintenance expenses and $1.4 million of lower generating routine maintenance expenses.
Depreciation and Amortization
Depreciation and amortization increased $13.5 million primarily due to $11.6 million for the amortization of the securitized intangible asset that began in November 2022, $6.5 million related to changes in the estimated useful lives of internal software, and $4.2 million for higher normal recurring additions to fixed assets. These increases were partially offset by $7.4 million for the absence of amortization of regulatory assets relating to Hurricanes Laura, Delta, and Zeta and $2.1 million
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CLECO POWER 2024 FORM 10-K
for the absence of amortization related to costs associated with lignite mining.
Taxes Other Than Income Taxes
Taxes other than income taxes increased $5.6 million primarily due to the amortization of the Madison Unit 3 property tax regulatory asset that began in July 2022. For more information, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 6 - Regulatory Assets and Liabilities - Madison Unit 3 Property Taxes.”
Regulatory Disallowance
Regulatory disallowance decreased $13.8 million due to the absence of the impairment charge resulting from the LPSC approved settlement disallowing the recovery of a portion of planning and construction costs incurred for the St. Mary Clean Energy Center.
Other Expense, Net
Other expense, net decreased $7.1 million primarily due to the absence of non-service pension costs amortization as a result of an increase in the discount rate which caused actuarial gains.
Interest Charges
Interest charges increased $10.7 million primarily due to $8.8 million for interest on storm recovery bonds issued in June 2022 by Cleco Securitization I and $4.3 million for higher rates on variable rate debt. These increases were partially offset by $2.8 million for the absence of interest on floating rate senior notes that were redeemed at par in June 2022.
Income Taxes
For information on Cleco Power’s effective income tax rates, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 12 - Income Taxes - Cleco Power.”
Non-GAAP Measure
The financial results in the following table is presented on an accrual basis. EBITDA is a key non-GAAP financial measure used by the CEO to assess the operating performance of Cleco’s segment; however, it is not indicative of future performance. Management evaluates the performance of Cleco’s segment and allocates resources to it based on segment profit and the requirements to implement strategic initiatives and projects to meet current business objectives. EBITDA is defined as net income adjusted for interest, income taxes, depreciation, and amortization.
Cleco’s segment structure and its allocation of corporate expenses were updated to reflect how management makes financial decisions and allocates resources.
The following table sets forth a reconciliation of net income, the nearest comparable GAAP financial performance measure, to EBITDA for the Cleco Power reportable segment for the years ended December 31, 2024, 2023, and 2022:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Net income $ 138,918 $ 137,149 $ 170,057
Add: Depreciation and amortization 236,444 191,745 178,231
Less: Interest income 4,125 5,011 5,082
Add: Interest charges 98,858 98,879 88,218
Add: Federal and state income tax expense (benefit)
18,506 (4,434) 2,503
EBITDA $ 488,601 $ 418,328 $ 433,927
Selected Financial Data
The information set forth in the following table should be read in conjunction with Cleco’s Consolidated Financial Statements and the related Notes in Item 8, “Financial Statements and Supplementary Data.”
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS, EXCEPT PER SHARE AND PERCENTAGES) 2024 2023 2022
Operating revenue, net (excluding intercompany revenue)
Cleco Power (1)
$ 1,142,450 $ 1,248,241 $ 1,614,151
Other 5,258 (9,450) (9,671)
Total $ 1,147,708 $ 1,238,791 $ 1,604,480
Income (loss) from continuing operations before income taxes $ 78,957 $ (94,942) $ 253,183
Income (loss) from discontinued operations, net of income taxes
$ 45,517 $ 14,642 $ (44,337)
Net income (loss)
$ 110,418 $ (15,227) $ 188,811
Capitalization
Member’s equity 51.79 % 47.77 % 48.42 %
Long-term debt and finance leases (2)
48.21 % 52.23 % 51.58 %
Member’s equity $ 2,841,014 $ 2,873,173 $ 2,947,067
Long-term debt and finance leases (2)
$ 2,645,043 $ 3,141,924 $ 3,139,094
Total assets $ 7,369,606 $ 8,100,393 $ 8,253,749
(1) Includes revenue for transmission services provided to Cleco Cajun that are no longer eliminated on Cleco’s Consolidated Statements of Income as a result of discontinued operations presentation. For more information on discontinued operations and the closing of the Cleco Cajun Divestiture, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
(2) Excludes long-term debt and finance leases due within one year.
CLECO POWER - NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS
For a narrative analysis of the results of operations explaining the revenue and expense items of Cleco Power for the years ended December 31, 2024, and 2023, see “- Results of
Operations - Comparison of the Years Ended December 31, 2024, and 2023 - Cleco Power.”
For a narrative analysis of the results of operations explaining the revenue and expense items of Cleco Power for the years ended December 31, 2023, and 2022, see “-
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Results of Operations - Comparison of the Years Ended December 31, 2023, and 2022 - Cleco Power.”
The narrative analysis referenced above should be read in combination with Cleco Power’s Financial Statements and the Notes contained in this Annual Report on Form 10-K.
CRITICAL ACCOUNTING ESTIMATES
The preparation of Cleco’s and Cleco Power’s Consolidated Financial Statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that could have a material impact on the results of operations, financial condition, or cash flows of the Registrants. For more information on Cleco’s accounting policies, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies.”
Cleco believes that the following accounting estimates are the most significant in understanding reported financial results:
•Regulatory Accounting: A significant portion of Cleco’s businesses are subject to regulation. This results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses. Cleco Power is allowed to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of Cleco’s businesses. Cleco’s management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current rate environment. For more information on regulatory assets and liabilities, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Regulation,” “Note 6 - Regulatory Assets and Liabilities,” and “Note 14 - Regulation and Rates.”
•Goodwill: On April 13, 2016, in connection with the completion of the 2016 Merger, Cleco recognized goodwill of $1.49 billion, all of which was assigned to the Cleco Power reporting unit. Goodwill is required to be tested for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. Application of the goodwill impairment test requires management to make significant assumptions and estimates, including the identification of reporting units, assignments of assets and liabilities to reporting units, assignment of goodwill to reporting units, and the determination of the fair value of the reporting units, in which independent valuation experts are often used. Changes in management’s assumptions and estimates could materially affect the determination of fair value and goodwill impairment. For more information on goodwill recorded in connection with the 2016 Merger, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 18 - Intangible Assets and Goodwill - Goodwill.”
•Pension and Other Postretirement Benefits: To determine assets, liabilities, and expenses relating to pension and other postretirement benefits, management must make assumptions about future trends. Assumptions and estimates include, but are not limited to, discount rates, expected return on plan assets, mortality rates, future rate of compensation increases, and medical inflation trend rates. These assumptions are reviewed and updated on an annual basis. Changes in the rates from year-to-year and newly-enacted laws could have a material effect on Cleco’s financial condition and results of operations by changing the recorded assets, liabilities, expense, or required funding of the pension plan obligation. One component of pension expense is the expected return on plan assets. It is an assumed percentage return on the market-related value of plan assets. The market-related value of plan assets differs from the fair value of plan assets by the amount of deferred asset gains or losses. Actual asset returns that differ from the expected return on plan assets are deferred and recognized in the market-related value of assets on a straight-line basis over a five-year period.
Management uses a theoretical bond portfolio in order to calculate the discount rate for the measurement of liabilities. A change in the assumed discount rate creates a deferred actuarial gain or loss. Generally, when the assumed discount rate increases or decreases compared to the prior measurement date, an actuarial gain or loss occurs, respectively. Actuarial gains and losses also are created when actual results, such as compensation increases, differ from assumptions. Historically, Cleco Power has been allowed to recover pension plan expenses; therefore, deferred actuarial gains and losses are recorded as a regulatory asset or liability. The net of the deferred gains and losses is amortized to pension expense over the average service life of the remaining plan participants when it exceeds certain thresholds. This approach of amortizing gains and losses has the effect of reducing the volatility of pension expense. Over time, it is not expected to reduce or increase the pension expense relative to an approach that immediately recognizes losses and gains.
The following table shows the impact of a 0.5% change in Cleco’s pension plan discount rate, salary scale, and rate of return on plan assets:
ACTUARIAL ASSUMPTION
(THOUSANDS) CHANGE IN ASSUMPTION CHANGE IN PROJECTED BENEFIT OBLIGATION CHANGE IN ESTIMATED BENEFIT COST
Discount rate 0.5% increase $ (25,319) $ 530
0.5% decrease $ 27,797 $ (617)
Salary scale 0.5% increase $ 2,631 $ 266
0.5% decrease $ (2,477) $ (250)
Expected return on assets 0.5% increase $ - $ (2,346)
0.5% decrease $ - $ 2,346
Based on funding assumptions at December 31, 2024, management estimates that $76.1 million of pension contributions will be required through 2029 of which $16.5 million is required in 2025. Future discretionary contributions may be made depending on changes in assumptions, the ability to utilize the contribution as a tax deduction, and requirements concerning recognizing a minimum pension liability. Future required contributions are driven by liability funding target percentages set by law which could cause the required contributions to change from
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year-to-year. The ultimate amount and timing of the contributions will be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Adverse changes in assumptions or adverse actual events could cause additional minimum contributions.
For more information on pension and other postretirement benefits, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 11 - Pension Plan and Employee Benefits.”
•Income Taxes: For more information on income taxes, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Income Taxes” and Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 12 - Income Taxes.”
•Loss Contingencies: Cleco is currently involved in certain legal and regulatory proceedings and management has estimated the probable costs for the resolution of these matters. These estimates are based on an analysis of potential results, assuming a combination of litigation and settlement assumptions. For more information on legal and regulatory proceedings affecting Cleco, see Part I, Item 1, “Business - Environmental Matters - Air Quality,” Item 1A, “Risk Factors - Operational Risks - Litigation,” and Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees.”
•Discontinued Operations: Cleco calculated an estimated impairment on the disposition of its Cleco Cajun Sale Group as of December 31, 2023. Cleco determined that the estimated fair value less the estimated cost to sell the Cleco Cajun Sale Group was less than the carrying value of the Cleco Cajun Sale Group at December 31, 2023. The fair value estimates involved a number of judgements and assumptions including the future performance of the Cleco Cajun Sale Group through the expected divestiture date, the expected net working capital adjustment to the sale proceeds from the Cleco Cajun Divestiture Purchase and Sale Agreement, and the weighted average cost of capital or discount rate. The estimated fair value was determined using the income approach. During 2024, changes occurred in the fair value less cost to sell the Cleco Cajun Sale Group and the actual impairment on the disposition of the Cleco Cajun Sale Group was different compared to the estimated loss recorded at December 31, 2023. For more on discontinued operations, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 3 - Discontinued Operations.”
Cleco Power
Cleco Power’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC, while rates for wholesale power sales are based on market-based rates and ultimately reviewed by FERC. Cleco Power must evaluate its various transactions related to regulatory orders and accounting guidance to ensure the appropriate timing of revenue recognition, the evaluation of cost deferral and the recoverability and refund of certain assets. Future rate changes could have a material impact on the results of
operations, financial condition, or cash flows of Cleco Power. Areas that could be materially impacted by future actions of regulators are described below:
•The LPSC allows Cleco Power to recover prudent costs incurred in developing long-lived assets. If the LPSC were to rule that the cost of current or future long-lived assets was imprudent and not recoverable, Cleco Power could be required to write down the asset and incur a corresponding impairment loss.
•The LPSC determines the amount and type of fuel and purchased power expenses that Cleco Power can charge customers through the FAC. Changes in the determination of allowable costs already incurred by Cleco Power could cause material changes in fuel revenue. Recovery of FAC costs is subject to periodic fuel audits by the LPSC, which are performed at least every other year. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, by the LPSC related to these filings. For more information on current LPSC fuel audits, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees -Litigation - LPSC Audits and Reviews - Fuel Audits.” For information on fuel revenue, see “- Results of Operations - Comparison of the Years Ended December 31, 2024, and 2023 - Cleco Power - Significant Factors Affecting Cleco Power - Fuel Cost and Purchased Power Recovery/Recoverable Fuel and Power Purchased.”
FINANCIAL CONDITION
Liquidity and Capital Resources
General Considerations and Credit-Related Risks
Credit Ratings and Counterparties
Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain or expand its businesses. Access to funds is dependent upon factors such as general economic and capital market conditions, regulatory authorizations and policies, Cleco Holdings’ and Cleco Power’s credit ratings, cash flows from routine operations, and credit ratings of project counterparties. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. The following table presents the credit ratings of Cleco Holdings and Cleco Power at December 31, 2024:
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SENIOR UNSECURED DEBT CORPORATE/LONG-TERM ISSUER
S&P MOODY’S FITCH S&P MOODY’S FITCH
Cleco Holdings BBB- Baa3 BBB- BBB
Baa3 BBB-
Cleco Power A-
A3 BBB+ A-
A3 BBB
Credit ratings are not recommendations to buy, sell, or hold securities, and may be subject to revision or withdrawal at any time by the assigning rating agency. Each rating should be evaluated independently of any other rating.
On June 7, 2024, and following the closing of the Cleco Cajun Divestiture, S&P upgraded its ratings for Cleco Holdings from BBB- to BBB at the issuer level and Cleco Power from BBB+ to A- at both the issuer and issue level. S&P revised its ratings due to the expected improvement in business risk from having a fully regulated utility business after the closing of the Cleco Cajun Divestiture.
Cleco Holdings and Cleco Power pay fees and interest under their bank credit agreements based on the highest rating held. If Cleco Holdings’ or Cleco Power’s credit ratings were to be downgraded, Cleco Holdings or Cleco Power, respectively, could be required to pay additional fees and incur higher interest rates for borrowings under their respective revolving credit facilities.
Cleco Holdings and Cleco Power may be required to provide credit support with respect to bilateral transactions and contracts that they have entered into or may enter into in the future. The amount of credit support required may change based on margining formulas, changes in credit agency ratings, or liquidity ratios.
Cleco Power participates in the MISO market. MISO requires participants to provide credit support which may increase or decrease due to the timing of the settlement schedules and MISO margining formulas. For more information about MISO, see “- Regulatory and Other Matters - Transmission Rates.” For more information about credit support, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Off-Balance Sheet Commitments and Guarantees.”
Global and U.S. Economic Environment
Global and domestic economic conditions may have an impact on Cleco’s business and financial condition. Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. During periods of capital market volatility, the availability of capital could be limited and the costs of capital may increase for many companies. Although the Registrants have not experienced restrictions in the financial markets, their ability to access the capital markets may be restricted at a time when the Registrants would like, or need, to do so. Any restrictions could have a material impact on the Registrants’ ability to fund capital expenditures or debt service, or on their flexibility to react to changing economic and business conditions. Credit constraints could have a material, negative impact on the Registrants’ lenders or customers, causing them to fail to meet their obligations to the Registrants or to delay payment of such obligations.
In recent years, inflationary pressures have increased substantially. Under established regulatory practice, historical costs have traditionally formed the basis for recovery from customers. As a result, Cleco Power’s future cash flows designed to provide recovery of historical plant costs may not be adequate to replace property, plant, and equipment in
future years. For information on the impacts of inflation and market price volatility of natural gas on credit loss reserves related to customer accounts receivable, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Reserves for Credit Losses” and Part I, Item 1A, “Risk Factors - General Risk Factors - Global Economic Uncertainty and Access to Capital.”
TCJA
The provisions of the TCJA reduced the top federal statutory corporate income tax rate from 35% to 21%. At June 13, 2024, all amounts for the TCJA unprotected excess ADIT had been returned to Cleco Power’s retail customers. Cleco Power’s retail customers will continue receiving bill credits for the TCJA protected excess ADIT until the full amount has been returned. For more information on the regulatory impact of the TCJA, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - TCJA.”
Fair Value Measurements
Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. For more information about fair value instruments, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 8 - Fair Value Accounting Instruments.”
Cash Generation and Cash Requirements
Restricted Cash and Cash Equivalents
For information on Cleco’s and Cleco Power’s restricted cash and cash equivalents, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Restricted Cash and Cash Equivalents.”
Working Capital and Debt
Cleco
At December 31, 2024, and 2023, Cleco had $120.0 million and $110.0 million, respectively, of short-term debt for outstanding borrowings under its aggregate $475.0 million revolving credit facilities. For more information on Cleco’s credit facilities, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 10 - Debt - Credit Facilities.”
At December 31, 2024, Cleco’s long-term debt and finance leases outstanding, excluding fair value adjustments resulting from the 2016 merger, was $2.82 billion, of which $264.9 million was due within one year. The long-term debt and finance leases due within one year at December 31, 2024, primarily represents Cleco Power’s $125.0 million bank term loan due in May 2025; $75.0 million of Cleco Power’s senior notes due in November 2025; $50.0 million of Cleco Power’s GO-Zone bonds with a mandatory tender in April 2025; and $15.1 million of Cleco Securitization I storm recovery bond principal payments scheduled to be paid in 2025.
In February 2019 in connection with the approval of the Cleco Cajun Acquisition, Cleco made commitments to the LPSC that included the repayment of $400.0 million of Cleco Holdings’ debt by December 31, 2024. On April 26, 2024, Cleco Holdings paid the remaining $66.7 million satisfying this LPSC commitment. In addition, on June 4, 2024, Cleco
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Holdings redeemed its $165.0 million floating rate senior notes due in May 2025.
On November 27, 2024, Cleco Holdings completed a voluntary tender offer for its 3.743% senior notes due in May 2026 in an aggregate principal amount of $175.0 million.
Cash and cash equivalents available at December 31, 2024, were $30.5 million combined with $355.0 million available revolving credit facility capacity ($165.0 million from Cleco Holdings and $190.0 million from Cleco Power) for total liquidity of $385.5 million.
At December 31, 2024, and 2023, Cleco had a working capital surplus of $77.8 million and working capital deficit of $17.5 million, respectively. The $95.3 million increase in the working capital surplus is primarily due to:
•a $260.8 million increase in regulatory assets primarily due to the reclassification of the Dolet Hills and mine-related regulatory assets to short-term as a result of Cleco Power expecting the securitization of those amounts to be completed by the end of March 2025,
•a $40.3 million decrease in provision for rate refund primarily due to the reclassification of the long-term portion of refunds to be made to Cleco Power’s retail customers and the third quarter 2024 refund issued to Cleco Power’s retail customers resulting from the settlement of the Dolet Hills prudency review. For more information about the settlement, see Item 8, “Financial Statements and Supplementary Data - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review,”
•a $27.4 million increase in fuel inventory primarily due to higher coal volume with higher transportation costs driven by lower usage from a decrease in market gas prices,
•a $17.3 million increase in materials and supplies inventory primarily due to higher purchases of transmission and distribution inventory in order to support future needs and mitigate future supply chain uncertainty,
•a $15.0 million decrease in energy risk management liabilities primarily due to lower mark-to-market losses on gas related derivative contracts,
•a $13.6 million decrease in regulatory liabilities primarily due to the amortization of the TCJA regulatory liability,
•an $11.2 million increase in affiliate accounts receivable due to estimated income taxes paid by Cleco Holdings on behalf of Cleco Group, and
•a $9.1 million decrease in the current portion of postretirement benefit obligations primarily due to pension plan contributions expected to be made in 2025.
These increases in the working capital surplus were partially offset by:
•a $120.5 million decrease in the net assets and liabilities held for sale as a result of the closing of the Cleco Cajun Divestiture. For more information about assets and liabilities held for sale, see Item 8, “Financial Statements and Supplementary Data - Note 3 - Discontinued Operations,”
•a $92.1 million decrease in cash and cash equivalents,
•a $39.7 million increase in taxes payable primarily due to higher provisions for federal and state income taxes,
•a $10.7 million increase in affiliate accounts payable primarily due to an increase in the amounts payable to Cleco
Group for income taxes and higher corporate franchise taxes,
•a $10.5 million decrease in accumulated deferred fuel, excluding FTRs, primarily due to lower mark-to-market losses on gas-related derivative contracts and the expiration of a significant wholesale customer contract, partially offset by the timing of fuel revenue collections,
•a $10.0 million increase in short-term debt primarily due to draws on Cleco Holdings’ and Cleco Power’s revolving credit facilities, and
•an $8.1 million increase in long-term debt and finance leases due within one year primarily due to $75.0 million of Cleco Power’s senior notes due in November 2025, $50.0 million of Cleco Power’s GO-Zone bonds with a mandatory tender in April 2025, partially offset by the repayment of Cleco Holdings’ $66.7 million bank term loan, and the repayment of $50.0 million of Cleco Power’s senior notes in December 2024.
At December 31, 2024, Cleco’s Consolidated Balance Sheets reflected $4.53 billion of total liabilities compared to $5.23 billion at December 31, 2023. The $698.6 million decrease in total liabilities during 2024 was primarily due to:
•a $488.8 million decrease in long-term debt and finance leases, net primarily due to the completion of a voluntary tender offer of Cleco Holdings’ $175.0 million senior notes, the redemption of Cleco Holdings’ $165.0 million senior notes, the repayment of Cleco Holdings’ $66.7 million bank term loan, the repayment of $50.0 million of Cleco Power’s senior notes, $15.1 million of Cleco Securitization I storm recovery bond principal payments, and Cleco Power’s $12.1 payment on the barge finance lease,
•a $115.0 million decrease in the net liabilities held for sale primarily as a result of the closing of the Cleco Cajun Divestiture. For more information about assets and liabilities held for sale, see Item 8, “Financial Statements and Supplementary Data - Note 3 - Discontinued Operations,”
•a $53.2 million decrease in accumulated deferred federal and state income taxes primarily due to a reduction in the state income tax rate,
•a $38.7 million decrease in postretirement benefit obligations, as previously discussed, and
•a $35.3 million decrease in restricted storm reserve primarily due to costs recorded for multiple severe weather events that are netted against the storm reserve.
These decreases in total liabilities were partially offset by a $39.7 million increase in taxes payable, as previously discussed.
Cleco Holdings
At December 31, 2024 and 2023, Cleco Holdings had $10.0 million and $110.0 million, respectively, of short-term debt outstanding under its $175.0 million revolving credit facility. For more information on Cleco Holdings’ credit facility, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 10 - Debt - Credit Facilities.”
On April 26, 2024, Cleco Holdings repaid its $66.7 million bank term loan that was due on May 21, 2024. In addition, on June 4, 2024, Cleco Holdings redeemed its $165.0 million floating rate senior notes due in May 2025.
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On September 20, 2024, Cleco Holdings’ individual $10.0 million uncommitted line of credit expired. Previously, this line of credit was being renewed on an annual basis.
On November 27, 2024, Cleco Holdings completed a voluntary tender offer for its 3.743% senior notes due in May 2026 in an aggregate principal amount of $175.0 million.
At December 31, 2024, Cleco Holdings’ long-term debt outstanding, excluding fair value adjustments resulting from the 2016 merger, was $1.00 billion, none of which was due within one year. For Cleco Holdings, long-term debt and finance leases, net decreased $405.1 million primarily due to the completion of a voluntary tender offer of $175.0 million senior notes, the redemption of $165.0 million senior notes, and the repayment of the $66.7 million bank term loan.
Cash and cash equivalents available at Cleco Holdings at December 31, 2024, were $6.8 million, combined with $165.0 million available revolving credit facility capacity for a total liquidity of $171.8 million.
Cleco Power
At December 31, 2024, Cleco Power had $110.0 million outstanding borrowings of short-term debt under its $300.0 million revolving credit facility. At December 31, 2023, Cleco Power had no short-term debt. For more information on Cleco Power’s credit facility, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 10 - Debt - Credit Facilities.”
At December 31, 2024, Cleco Power’s long-term debt and finance leases outstanding was $1.81 billion, of which $264.9 million was due within one year. The long-term debt and finance leases due within one year at December 31, 2024, primarily represents the $125.0 million bank term loan due in May 2025; $75.0 million senior notes due in November 2025; $50.0 million GO-Zone bonds with a mandatory tender in April 2025; and $15.1 million of Cleco Securitization I storm recovery bond principal payments scheduled to be paid in 2025.
On May 17, 2024, Cleco Power entered into a $125.0 million bank term loan. This term loan replaced Cleco Power’s existing term loan credit agreement. The current term loan has an interest rate of SOFR plus 1.35% or ABR plus 0.25% and a maturity date of May 17, 2025. In addition, on December 16, 2024, Cleco Power repaid its $50.0 million 3.17% senior notes that matured in December 2024.
On September 20, 2024, Cleco Power’s individual $10.0 million uncommitted line of credit expired. Previously, this line of credit was being renewed on an annual basis.
Cash and cash equivalents available at December 31, 2024, were $23.7 million combined with $190.0 million available revolving credit facility capacity for total liquidity of $213.7 million.
At December 31, 2024, and 2023, Cleco Power had a working capital surplus of $96.0 million and a working capital deficit of $66.2 million, respectively. The $162.2 million increase in the working capital surplus is primarily due to:
•a $260.8 million increase in regulatory assets primarily due to the reclassification of the Dolet Hills and mine-related regulatory assets to short-term as a result of Cleco Power expecting the securitization of those amounts to be completed by the end of March 2025,
•a $40.3 million decrease in provision for rate refund primarily due to the reclassification of the long-term portion of refunds to be made to Cleco Power’s retail customers and the third quarter 2024 refund issued to Cleco Power’s retail
customers resulting from the settlement of the Dolet Hills prudency review. For more information about the settlement, see Item 8, “Financial Statements and Supplementary Data - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review,”
•a $27.4 million increase in fuel inventory primarily due to higher coal volume with higher transportation costs driven by lower usage from a decrease in market gas prices,
•a $17.3 million increase in materials and supplies inventory primarily due to higher purchases of transmission and distribution inventory in order to support future needs and mitigate future supply chain uncertainty,
•a $14.3 million decrease in energy risk management liabilities primarily due to lower mark-to-market losses on gas-related derivative contracts,
•a $13.6 million decrease in regulatory liabilities primarily due to the reclassification of the short-term portion of the TCJA regulatory liability,
•a $10.3 million decrease in taxes payable primarily due to lower provisions for income taxes, and
•a $9.1 million decrease in the current portion of postretirement benefit obligations primarily due to pension plan contributions expected to be made in 2025.
These increases in the working capital surplus were partially offset by:
•a $110.0 million increase in short-term debt due to outstanding borrowings of short-term debt under its $300.0 million revolving credit facility,
•a $74.6 million increase in long-term debt and finance leases due within one year primarily due to $75.0 million of senior notes due in November 2025, $50.0 million of GO-Zone bonds with a mandatory tender in April 2025, partially offset by the repayment of $50.0 million of senior notes in December 2024,
•a $25.5 million decrease in cash and cash equivalents,
•a $15.9 million increase in accounts payable primarily due to storm accruals related to the restoration efforts for Hurricane Francine and short-term incentive plan accruals,
•a $10.5 million decrease in accumulated deferred fuel, excluding FTRs, primarily due to lower mark-to-market losses on gas-related derivative contracts and the expiration of a significant wholesale customer contract, partially offset by the timing of fuel revenue collections.
At December 31, 2024, Cleco Power’s Consolidated Balance Sheets reflected $3.28 billion of total liabilities compared to $3.37 billion at December 31, 2023. The $84.9 million decrease in total liabilities during 2024 was primarily due to:
•a $75.9 million decrease in long-term debt and finance leases, net primarily due the repayment of $50.0 million senior notes, $15.1 million of Cleco Securitization I storm recovery bond principal payments, and a $12.1 million payment on the barge finance lease,
•a $35.3 million decrease in restricted storm reserve, as previously discussed,
•a $31.9 million decrease in postretirement benefit obligations, as previously discussed, and
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•an $18.5 million decrease in accumulated deferred federal and state income taxes primarily due to a reduction in the state income tax rate, partially offset by the utilization of the loss carryforward.
These decreases in total liabilities were partially offset by a $110.0 million increase in short-term debt, as previously discussed.
Concentrations of Credit Risk
At December 31, 2024 and 2023, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. For more information on the concentration of credit risk through short-term investments classified as cash equivalents, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 8 - Fair Value Accounting Instruments.”
Debt and Distribution Limitations
The 2016 Merger Commitments include provisions for limiting the amount of distributions that can be made from Cleco Holdings to Cleco Group, depending on Cleco Holdings’ debt to EBITDA ratio and its corporate credit ratings. Cleco Holdings may not make any distribution unless, after giving effect to such distribution, Cleco Holdings’ debt to EBITDA
ratio is equal to or less than 6.50 to 1.00 and Cleco Holdings’ corporate credit rating is investment grade with one or more of the three credit rating agencies. At December 31, 2024, Cleco Holdings was in compliance with the provisions of the 2016 Merger Commitments that would restrict the amount of distributions available. Additionally, in accordance with the 2016 Merger Commitments, Cleco Power is subject to certain provisions limiting the amount of distributions that may be paid to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit ratings. Cleco Power may not make any distribution unless, after giving effect to such distribution, Cleco Power’s common equity ratio would not be less than 48% and Cleco Power’s corporate credit rating is investment grade with two of the three credit rating agencies. At December 31, 2024, Cleco Power was in compliance with the provisions of the 2016 Merger Commitments that would restrict the amount of distributions available. The 2016 Merger Commitments also prohibit Cleco from incurring additional long-term debt, excluding non-recourse debt, unless certain financial ratios are achieved. For more information on the 2016 Merger Commitments, see Part I, Item 1A, “Risk Factors - Structural Risks - Holding Company” and “- Regulatory Risks - Regulatory Compliance.”
Cash Flows Comparison for the Years Ended December 31, 2024, and 2023
Cleco’s and Cleco Power’s net cash activities for operating, investing, and financing cash flows are as follows for December 31, 2024, and 2023:
CLECO CLECO POWER
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 VARIANCE 2024 2023 VARIANCE
Net cash provided by operating activities $ 296,805 $ 421,192 $ (124,387) $ 270,585 $ 399,943 $ (129,358)
Net cash provided by (used in) investing activities
$ 217,239 $ (227,816) $ 445,055 $ (242,341) $ (218,657) $ (23,684)
Net cash used in financing activities
$ (607,228) $ (128,881) $ (478,347) $ (50,721) $ (150,352) $ 99,631
Cleco - Net Operating Cash Flow
Cash generated from operating activities consists of net income, adjusted for non-cash expenses, non-cash income, and changes in operating assets and liabilities. Non-cash adjustments include items such as depreciation and amortization, gain or loss on risk management assets and liabilities, regulatory disallowance, deferred income taxes, and allowance for equity funds used during construction.
Net cash provided by operating activities during 2024 decreased $124.4 million from 2023 primarily due to:
•$59.2 million of lower recoveries of fuel and purchased power costs primarily due to the timing of collections at a lower fuel rate,
•$36.2 million of higher payments for non-capital severe weather events at Cleco Power,
•$25.3 million of higher minimum required contributions made for the pension plan at Cleco Power,
•$17.6 million of lower collections from Cleco Power’s customers, and
•$11.0 million of higher payments for natural gas derivatives at Cleco Power.
These decreases were partially offset by
•$15.0 million of lower interest paid on debt,
•$11.3 million of lower affiliate settlements to Cleco Group, primarily for income taxes payable, and
•the absence of $6.5 million of cash collateral remitted to counterparties for Cleco Cajun’s natural gas derivatives.
Cleco - Net Investing Cash Flow
Net cash provided by investing activities increased $445.1 million, which includes discontinued operations of $5.5 million, primarily due to $463.8 million of net proceeds from the Cleco Cajun Divestiture.
This increase was partially offset by higher additions to property, plant, and equipment, excluding AFUDC, of $29.3 million.
Cleco - Net Financing Cash Flow
Net cash used in financing activities increased $478.3 million during 2024 primarily due to:
•$296.0 million of higher repayments on long-term debt,
•the absence of $100.0 million of proceeds from the refinancing of Cleco Power’s senior notes,
•$91.5 million of higher distributions to Cleco Group, and
•$8.0 million of higher payments on credit facilities.
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CLECO POWER 2024 FORM 10-K
These increases were partially offset by $17.0 million of higher draws on credit facilities.
Cleco Power - Net Operating Cash Flow
Cash generated from operating activities consists of net income, adjusted for non-cash expenses, non-cash income, and changes in operating assets and liabilities. Non-cash adjustments include items such as depreciation and amortization, regulatory disallowance, deferred income taxes, and allowance for equity funds used during construction.
Net cash provided by operating activities during 2024 decreased $129.4 million from 2023 primarily due to:
•$59.2 million of lower recoveries of fuel and purchased power costs primarily due to the timing of collections at a lower fuel rate,
•$36.2 million of higher payments for non-capital severe weather events,
•$25.3 million of higher minimum required contributions made for the pension plan,
•$17.6 million of lower collections from customers, and
•$11.0 million of higher payments for natural gas derivatives.
These decreases were partially offset by:
•$9.1 million of higher collections from joint owners primarily due to the timing of receipts for generating station expenses and
•$6.6 million of lower purchased power costs from MISO.
Cleco Power - Net Investing Cash Flow
Net cash used in investing activities during 2024 increased $23.7 million from 2023 primarily due to higher additions to property, plant, and equipment, excluding AFUDC, of $34.4 million.
This increase was partially offset by higher payments received on note receivables of $11.1 million.
Cleco Power - Net Financing Cash Flow
Net cash used in financing activities during 2024 decreased $99.6 million from 2023 primarily due to:
•$85.0 million of higher draws on revolving credit facilities,
•$70.0 million of lower payments on the credit facility, and
•$45.1 million of lower repayments on long-term debt.
These decreases were partially offset by the absence of $100.0 million of proceeds from the refinancing of Cleco Power’s senior notes.
Cash Flows Comparison for the Years Ended December 31, 2023, and 2022
Cleco’s and Cleco Power’s net cash activities for operating, investing, and financing cash flows are as follows for December 31, 2023, and 2022:
CLECO CLECO POWER
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2023 2022 VARIANCE 2023 2022 VARIANCE
Net cash provided by operating activities $ 421,192 $ 344,912 $ 76,280 $ 399,943 $ 274,265 $ 125,678
Net cash used in investing activities $ (227,816) $ (193,257) $ (34,559) $ (218,657) $ (220,693) $ 2,036
Net cash (used in) provided by financing activities $ (128,881) $ (111,065) $ (17,816) $ (150,352) $ 6,731 $ (157,083)
Cleco - Net Operating Cash Flow
Cash generated from operating activities consists of net income, adjusted for non-cash expenses, non-cash income, and changes in operating assets and liabilities. Non-cash adjustments include items such as depreciation and amortization, gain or loss on risk management assets and liabilities, regulatory disallowance, deferred income taxes, and allowance for equity funds used during construction.
Net cash provided by operating activities during 2023 increased $76.3 million from 2022 primarily due to:
•$53.8 million of higher collections from Cleco Power and Cleco Cajun’s customers,
•$45.3 million of higher recoveries of fuel and purchased power costs primarily due to the timing of collections at a higher fuel rate, and
•$21.0 million of higher collections from joint owners primarily due to the timing of receipts for their portions of generating station expenses.
These increases were partially offset by $37.1 million of higher purchased power costs from MISO at Cleco Power and Cleco Cajun.
Cleco - Net Investing Cash Flow
Net cash used in investing activities increased $34.6 million primarily due to lower life insurance proceeds of $41.3 million.
This increase was partially offset by lower additions to property, plant, and equipment, excluding AFUDC, of $6.5 million.
Cleco - Net Financing Cash Flow
Net cash used in financing activities increased $17.8 million during 2023 primarily due to:
•the absence of proceeds of $424.9 million, net of discount, from the issuance of Cleco Securitization I storm recovery bonds and
•$101.0 million of lower draws on credit facilities.
These increases were partially offset by:
•$242.5 million of lower repayments on long-term debt,
•$166.1 million of lower distributions to Cleco Group, and
•$100.0 million of proceeds from the refinancing of Cleco Power’s senior notes due in 2023.
Cleco Power - Net Operating Cash Flow
Cash generated from operating activities consists of net income, adjusted for non-cash expenses, non-cash income,
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and changes in operating assets and liabilities. Non-cash adjustments include items such as depreciation and amortization, regulatory disallowance, deferred income taxes, and allowance for equity funds used during construction.
Net cash provided by operating activities during 2023 increased $125.7 million from 2022 primarily due to:
•$50.6 million of higher collections from customers,
•$45.8 million of higher receipts for affiliate settlements,
•$45.3 million of higher recoveries of fuel and purchased power costs primarily due to the timing of collections at a higher fuel rate, and
•$16.7 million of higher collections from joint owners primarily due to the timing of receipts for their portions of generating station expenses.
These increases were partially offset by:
•$18.9 million of higher fuel inventory costs due to purchases at a higher price per unit for petroleum coke and natural gas and
•$9.8 million of higher purchased power costs from MISO.
Cleco Power - Net Investing Cash Flow
Net cash used in investing activities during 2023 decreased $2.0 million from 2022 primarily due to lower additions to property, plant, and equipment, excluding $8.0 million of AFUDC, and
These decreases were partially offset by lower life insurance proceeds received of $6.5 million.
Cleco Power - Net Financing Cash Flow
Net cash used in financing activities during 2023 increased $157.1 million from 2022 primarily due to:
•the absence of proceeds of $424.9 million, net of discount, from the issuance of Cleco Securitization I senior secured storm recovery bonds and
•$137.0 million of lower draws on revolving credit facilities.
These increases were partially offset by:
•$240.4 million of lower repayments on long-term debt,
•$100.0 million of proceeds from the refinancing of senior notes due in 2023,
•$47.0 million of lower payments on the credit facility,
•$10.7 million of lower distributions to Cleco Holdings, and
•$6.9 million of lower payments for debt financing costs.
Capital Expenditures
Cleco’s capital expenditures are primarily incurred at Cleco Power. Cleco Power’s capital expenditures relate primarily to assets that may be included in Cleco Power’s rate base and, if considered prudent by the LPSC, can be recovered from its customers. Those assets also earn a rate of return authorized by the LPSC and are subject to the FRP. Such assets primarily consist of improvements to Cleco Power’s distribution system, transmission system, and generating stations as well as hardware and software upgrades.
During the years ended December 31, 2024, 2023, and 2022, Cleco Power had capital expenditures, excluding AFUDC, of $255.3 million, $221.0 million, and $228.9 million, respectively. Cleco Power funded its capital expenditures for
2024, 2023, and 2022 from internally generated funds and funds obtained through debt issuances.
During the years ended December 31, 2024, 2023, and 2022, Cleco’s other subsidiaries had capital expenditures of $0.9 million, $0.5 million, and $1.0 million, respectively.
During 2025 and for the five-year period ending 2029, Cleco and Cleco Power expect to materially fund their capital expenditure requirements with internally generated funds. However, Cleco Power may choose to issue debt in order to supplement its funding sources and achieve its stipulated regulatory capital structure. All computations of internally funded capital expenditures exclude AFUDC and capitalized interest.
Cleco’s and Cleco Power’s estimated capital expenditures and debt maturities for 2025 and for the five-year period ending December 31, 2029, are presented in the following tables. All amounts exclude AFUDC and capitalized interest.
Cleco
PROJECT (THOUSANDS) 2025 % 2025-2029 %
Environmental $ 8,000 2 % $ 20,000 1 %
New business 29,000 8 % 141,000 6 %
Renewables and electrification 39,000 11 % 194,000 8 %
Transmission reliability 2,000 1 % 12,000 - %
General (1)
274,000 78 % 2,171,000 85 %
Total capital expenditures
$ 352,000 100 % $ 2,538,000 (2)
100 %
Debt payments 215,000 1,422,000
Total capital expenditures and debt payments
$ 567,000 $ 3,960,000
(1) Primarily consists of rehabilitation projects of older transmission, distribution, and generation assets and hardware and software upgrades at Cleco Power.
(2) Does not include investment related to potential larger load customers; if contracts are executed, Cleco estimates $1.89 billion of additional capital expenditures.
Cleco Power
PROJECT (THOUSANDS) 2025 % 2025-2029 %
Environmental $ 8,000 2 % $ 20,000 1 %
New business 29,000 8 % 141,000 6 %
Renewables and electrification 39,000 11 % 194,000 8 %
Transmission reliability 2,000 1 % 12,000 - %
General (1)
272,000 78 % 2,159,000 85 %
Total capital expenditures
$ 350,000 100 % $ 2,526,000 (2)
100 %
Debt payments 215,000 762,000
Total capital expenditures and debt payments
$ 565,000 $ 3,288,000
(1) Primarily consists of rehabilitation projects of older transmission, distribution, and generation assets and hardware and software upgrades.
(2) Does not include investment related to potential larger load customers; if contracts are executed, Cleco Power estimates $1.89 billion of additional capital expenditures.
Capital expenditures for Cleco’s other subsidiaries in 2025 are estimated to total $2.0 million. For the five-year period ending December 31, 2029, capital expenditures for Cleco’s other subsidiaries are estimated to total $12.0 million. Cleco expects cash and cash equivalents on hand, in addition to cash generated from operations, borrowings from credit facilities, and the net proceeds of any issuances of debt securities, to be adequate to fund normal ongoing capital expenditures, working capital, and debt service requirements for the foreseeable future. For more information on future debt payments, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 10 - Debt.”
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Other Cash Requirements
Cleco Power’s regulated operations are Cleco’s primary sources of internally generated funds. These funds, along with issuances of additional debt received in future years, will be used for general company purposes, capital expenditures, debt service, human capital expenditures, contractual obligations, and off-balance sheet arrangements, if required.
Cleco also anticipates funding future cash requirements for renewable, electrification, and decarbonization projects, through one or more sources including tax credits, U.S. Department of Energy grants or loans, debt financing, private equity investment, and partnership interests. For more information on renewable and electrification initiatives, see “- Overview - Renewable and Electrification Initiatives.” For more information on decarbonization initiatives, see “- Overview - Decarbonization Initiatives.”
Contractual Obligations
Cleco, in the normal course of business activities, enters into a variety of contractual obligations. Some of these result in direct
obligations that are reflected in Cleco’s Consolidated Balance Sheets while others are commitments, some firm and some based on uncertainties, that are not reflected in the consolidated financial statements. These obligations do not
include amounts for ongoing needs for which no contractual obligation existed as of December 31, 2024.
For contractual obligations related to leases, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 4 - Leases.” For information on amounts expected to be contributed to the employee pension plan and the projected benefit payments for Other Benefits and SERP, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 11 - Pension Plan and Employee Benefits.”
PAYMENTS DUE BY PERIOD
CONTRACTUAL OBLIGATIONS (THOUSANDS) TOTAL UP TO 12 MONTHS BEYOND 12
MONTHS
Cleco
Long-term debt (1)
$ 4,119,566 $ 342,089 $ 3,777,477
Purchase obligations
$ 263,139 $ 178,588 $ 84,551
Other long-term liabilities (2)
$ 18,973 $ 2,970 $ 16,003
Cleco Power
Long-term debt (1)
$ 2,664,510 $ 301,083 $ 2,363,427
Purchase obligations $ 227,376 $ 144,661 $ 82,715
Other long-term liabilities (2)
$ 1,895 $ 1,875 $ 20
(1) For Cleco, the amount above excludes the fair value adjustments related to the 2016 Merger. Cleco’s and Cleco Power’s anticipated interest payments related to long-term debt also are included in this category and do not reflect anticipated future refinancing, early redemption, or debt issuance.
(2) Other long-term liabilities primarily consist of obligations for deferred compensation and various operating and maintenance agreements.
For purposes of this table, it is assumed that all terms and rates related to the above obligations will remain the same and all franchises will be renewed according to the rates used in the table.
Off-Balance Sheet Commitments and Guarantees
Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments in the form of guarantees and standby letters of credit in order to facilitate its activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees. For more information about off-balance sheet commitments and guarantees, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Off-Balance Sheet Commitments and Guarantees.”
Regulatory and Other Matters
Environmental Matters
For information on environmental matters, see Part I, Item 1, “Business - Environmental Matters.”
Retail and Wholesale Rates
For 2024 and 2023, retail rates, which includes the retail portion of FAC and EAC revenue, regulated by the LPSC
accounted for approximately 95% and 86%, respectively, of Cleco Power’s total base, FAC, and EAC revenue.
For information on Cleco Power’s base rates, fuel rates, and environmental rates, see Part I, item 1, “Regulatory Matters, Industry Developments, and Franchises - Rates.”
For information on Cleco Power’s wholesale rates, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 14 - Regulation and Rates - Wholesale Rates.”
Transmission Rates
Cleco Power’s generation dispatch and transmission operations are integrated with MISO. MISO operates a fully functioning RTO market with two major market processes: the Day-Ahead Energy and Operating Reserves Market and the Real-Time Energy and Operating Reserves Market. Both use market-based mechanisms to manage transmission congestion across the MISO market area. For more information about the risks associated with Cleco’s participation in MISO, see Part I, Item 1A, “Risk Factors - Regulatory Risks - MISO.”
For information on Cleco Power’s transmission rates, see Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 5 - Revenue Recognition - Transmission Revenue.”
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Market Structure
Wholesale Electric Markets
RTO
In 1999, FERC issued Order No. 2000, which established a general framework for all transmission-owning entities in the nation to voluntarily place their transmission facilities under the control of an appropriate RTO. Cleco Power’s generation dispatch and transmission operations are integrated with MISO. For more information about Cleco Power’s integration into MISO, see “-Transmission Rates.”
ERO
NERC, subject to oversight by FERC, is the ERO responsible for developing and enforcing mandatory reliability standards for users, owners, and operators of the bulk power system. NERC, as the ERO, delegates authority to the SERC Reliability Corporation.
A revised NERC reliability standard relating to the winterization of generation assets became effective on April 1, 2023. This revised standard requires the implementation of cold weather preparedness plans that include geographical based freeze protection measures, annual inspections, unit design temperature basis, and employee training. A new winterization standard requiring additional freeze protection measures was approved by FERC and fully implemented by Cleco, with an effective date of October 1, 2024. Management does not expect this new standard to have any impact on Cleco’s results of operations, financial condition, or cash flows.
A NERC Operations and Planning Reliability Standards audit is conducted every three years for Cleco Power. The next Operations and Planning Reliability Standards audit for Cleco Power began in the fall of 2024, and is expected to conclude in March 2025.
A NERC CIP audit is also conducted at least every three years for Cleco Power. NERC CIP audits for Cleco Power were concluded in 2023. The next audit is anticipated to begin in 2025.
Management is unable to predict the final outcome of any future audits or whether any findings will have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. For a discussion of risks associated with FERC’s regulation of Cleco Power’s transmission system, see Part I, Item 1A, “Risk Factors - Regulatory Risks - Reliability and CIP Standards Compliance”.
Retail Electric Markets
Currently, the LPSC does not provide exclusive service territories for electric utilities under its jurisdiction. Instead, retail service is obtained through a long-term nonexclusive franchise. The LPSC uses a “300-foot rule” for determining the supplier for new customers. The “300-foot rule” requires a customer to take service from the electric utility that is within 300 feet of the respective customer. If the customer is beyond 300 feet from any existing utility service, they may choose their electric supplier. The application of the rule has led to competition with neighboring utilities for retail customers at the borders of Cleco Power’s service areas. In the fourth quarter of 2024, Cleco Power filed a complaint with the LPSC under the 300-foot rule. There is currently a procedural schedule in place and the expected hearing date is March 24, 2025.
Cleco Power also competes in its service area with suppliers of alternative forms of energy, some of which may be less costly than electricity for certain applications. Cleco Power could experience some competition for electric sales to industrial customers in the form of cogeneration.
IRP
The IRP process includes conducting stakeholder meetings and receiving feedback from stakeholders. The final IRP was filed with the LPSC in May 2023. On March 21, 2024, the LPSC issued an order acknowledging that Cleco Power’s Final IRP complied with the LPSC’s IRP General Order. The LPSC’s acknowledgement completes this IRP cycle. The next IRP cycle is expected to begin in the fourth quarter of 2025.
The IRP report describes how Cleco Power plans to meet its forecasted load requirements on a reliable and economic basis, while reducing Cleco Power’s carbon footprint. The IRP is used as a guide in future decision-making and does not represent firm operational commitments.
Service Quality Plan (SQP)
In October 2015, the LPSC proposed an SQP containing 21 requirements for Cleco Power. The SQP has provisions relating to employee headcount, employee benefits, customer service, reliability, vegetation management, and reporting. In April 2016, the SQP was approved by the LPSC. The SQP expired in December 2020; however, Cleco continued to maintain its compliance with the SQP. On March 28, 2024, Cleco Power filed its annual SQP monitoring report for 2023 based on the expired reporting requirements.
A request to renew the conditions of the expired SQP was included in Cleco Power’s application for its most recent rate case, which was approved by the LPSC in June 2024. As a result, all parties were required to engage and present an amended and extended SQP, including an implementation plan and timeline, 90 days from the issuance of the LPSC order approving the settlement of the rate case. On October 15, 2024, Cleco Power submitted a proposed amended and extended SQP with the LPSC.
Franchises
For information on franchises, see Part I, Item 1, “Business - Regulatory Matters, Industry Developments, and Franchises - Franchises.”
Recent Authoritative Guidance
For a discussion of recent authoritative guidance, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Recent Authoritative Guidance.”
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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
RISK OVERVIEW
Cleco is exposed to counterparty credit risk, liquidity risk, interest rate risk, and commodity price risk. Cleco has implemented a governance framework, inclusive of risk policies and procedures to help manage these and other risks.
Counterparty Credit Risk
Cleco is exposed to counterparty credit risk when a counterparty fails to meet their financial obligations which causes Cleco to incur replacement cost losses. Cleco may be exposed when it enters certain transactions such as commodity derivative or physical commodity transactions directly with market participants and contracts with retail electric customers that require Cleco to construct grid facilities for the purpose of serving those customers. Cleco enters into long-form contract and master agreements with counterparties that govern the risk of counterparty credit default and allow for collateralization above prenegotiated thresholds to help mitigate potential losses. Alternatively, Cleco may be required to provide credit support with respect to bilateral transactions and contracts that Cleco has entered into or may enter into in the future. The amount of credit support required may change based on margining formulas, changes in credit agency ratings or liquidity ratios.
Cleco monitors and manages its credit risk exposure through credit risk management policies and procedures that require retail customer and counterparty credit quality review and monitoring, establishment of credit and default terms in bilateral contracts and master agreements, monitoring changing credit exposure as compared to fair value, and collateralization and other methods of counterparty credit assurance.
For more information, see Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - General Considerations and Credit-Related Risks.”
Liquidity Risk
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Disruption in the capital and credit markets may potentially increase the costs of capital and limit the ability to access the capital markets. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its business. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. For more information, see Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - General Considerations and Credit-Related Risks.”
Interest Rate Risk
Cleco monitors its mix of fixed- and variable-rate debt obligations in light of changing market conditions and from time to time may alter that mix, for example, refinancing balances outstanding under its variable-rate bank facilities with
fixed-rate debt or vice versa. Calculations of the changes in fair market value and interest expense of the debt securities are made over a one-year period.
Sensitivity to changes in interest rates for variable-rate obligations is computed by assuming a 1% change in the current interest rate applicable to such debt.
At December 31, 2024, Cleco Holdings had $10.0 million of short-term debt outstanding under its $175.0 million revolving credit facility at an all-in interest rate of 6.064%. At December 31, 2024, the borrowing costs under Cleco Holdings’ revolving credit facility were equal to SOFR plus 1.725% or ABR plus 0.625%, plus commitment fees of 0.275% paid on the unused portion of the facility. Each 1% increase in the interest rate applicable to Cleco Holdings’ short-term variable rate debt would result in a decrease in Cleco Holdings’ pretax earnings of $0.1 million on an annualized basis.
At December 31, 2024, Cleco Power had $110.0 million of short-term debt outstanding under its $300.0 million revolving credit facility at an all-in interest rate of 5.794%. The borrowing costs under Cleco Power’s revolving credit facility are equal to SOFR plus 1.35% or ABR plus 0.25%, plus commitment fees of 0.15% paid on the unused portion of the facility. Each 1% increase in the interest rate applicable to Cleco Power’s short-term variable rate debt would result in a decrease in Cleco Power’s pretax earnings of $1.1 million on an annualized basis.
At December 31, 2024, Cleco Power had a $125.0 million long-term variable rate bank term loan outstanding, at an interest rate of SOFR plus 1.35%, for an all-in interest rate of 5.707%. Each 1% increase in the interest rate applicable to Cleco Power’s long-term variable rate debt would result in a decrease in Cleco Power’s pretax earnings of $1.3 million on an annualized basis. The weighted average rate for the outstanding term loan debt at Cleco Power for the year ended December 31, 2024, was 6.565%.
Each 1% increase in the interest rate applicable to Cleco’s short- and long-term variable rate debt would result in a decrease in Cleco’s consolidated pretax earnings of $2.5 million on an annualized basis.
Cleco may enter into contracts to mitigate the volatility in interest rate risk. For each reporting period presented, the Registrants did not enter into any contracts to mitigate the volatility in interest rate risk.
Commodity Price Risk
Cleco Power’s financial performance can be adversely impacted by the volatility in future fuel and power prices, which may impact customer costs passed through Cleco Power’s FAC; therefore, Cleco Power has implemented a natural gas hedging program to partially mitigate the volatility of customer costs. The program includes transacting in financially settled swaps, physical fixed price supply agreements, and financially settled options contracts. Cleco Power executes this program within a risk management framework inclusive of risk management policies, procedures, and guidelines, set forth by its Board of Managers and management. Cleco Power may be exposed to transmission congestion price risk as a result of physical transmission constraints present between MISO LMP nodes when serving customer load. Cleco Power is awarded and/or purchases FTRs in auctions facilitated by MISO. FTRs
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CLECO POWER 2024 FORM 10-K
are accounted for as derivatives not designated as hedging instruments for accounting purposes.
During 2024, Cleco Cajun and Cleco Power had natural gas derivative contracts consisting of fixed price physical forwards and financially settled swap and/or options contract transactions. After the closing of the Cleco Cajun Divestiture, all natural gas derivative contracts related to Cleco Cajun were liquidated during June 2024. Cleco monitors the Value at Risk (VaR) of its natural gas derivative contracts requiring derivative accounting treatment. VaR is defined as the maximum expected loss over a given holding period at a given confidence level based on observable market prices and volatilities. Cleco uses a parametric variance-covariance model methodology to estimate VaR using a combination of implied and historical volatilities within a 5-day holding period at a 95% confidence interval. Given Cleco’s reliance on historical data, VaR is effective in estimating risk exposures in markets in which there are no sudden fundamental changes or abnormal shifts in market conditions. An inherent limitation of VaR is that past changes in market risk factors, even when
weighted toward more recent observations, may not produce accurate predictions of future market risk. VaR should be evaluated in light of this and the methodology’s other limitations.
The following table presents the VaR of natural gas derivative contracts based on these assumptions:
FOR THE YEAR ENDED DEC. 31, 2024
(THOUSANDS) AT DEC. 31, 2024 HIGH LOW AVERAGE
Cleco $ 4,631 $ 13,864 $ 2,801 $ 7,085
Cleco Power $ 4,631 $ 9,066 $ 2,576 $ 4,709
For more information on the accounting treatment and fair value of FTRs and natural gas derivative contracts, see Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 2 - Summary of Significant Accounting Policies - Derivatives and Other Risk Management Activity,” “Note 8 - Fair Value Accounting Instruments,” and “Note 9 - Derivative Instruments.”
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Report of Independent Registered Public Accounting Firm
To the Board of Managers and Member of
Cleco Corporate Holdings LLC
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Cleco Corporate Holdings LLC and its subsidiaries (the “Company”) as of December 31, 2024 and 2023, and the related consolidated statements of income, of comprehensive income, of changes in member’s equity, and of cash flows for each of the three years in the period ended December 31, 2024, including the related notes and financial statement schedules listed in the index appearing under Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024 in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Goodwill Impairment Assessment - Cleco Power Reporting Unit
As described in Notes 2 and 18 to the consolidated financial statements, the Company’s consolidated goodwill balance was $1.49 billion at December 31, 2024, all of which was assigned to the Cleco Power reporting unit. Management conducts an impairment test as of August 1 of each year, or more often if an event occurs or circumstances change that would indicate the carrying amount may be impaired. Fair value is estimated by management using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. Significant assumptions used in these fair value estimates include estimation of future cash flows related to capital expenditures, long-term rate of growth, and discount rate.
The principal considerations for our determination that performing procedures relating to the goodwill impairment assessment of the Cleco Power reporting unit is a critical audit matter are (i) the significant judgment by management when developing the fair value measurement of the reporting unit; (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management’s significant assumptions related to capital expenditures, long-term rate of growth, and discount rate; and (iii) the audit effort involved the use of professionals with specialized skill and knowledge.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included, among others, (i) testing management’s process for developing the fair value estimate; (ii) evaluating the appropriateness of the discounted cash flow model; (iii) testing the completeness, accuracy, and relevance of underlying data used in the model; and (iv) evaluating the significant assumptions used by management relating to capital expenditures, long-term rate of growth, and discount rate. Evaluating management’s assumptions related to the capital expenditures and projected long-term rate of growth involved evaluating whether the assumptions used by
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CLECO POWER 2024 FORM 10-K
management were reasonable considering, as applicable, (i) the current and past performance of the reporting unit, (ii) the consistency with external market and modeled rate base changes, and (iii) whether these assumptions were consistent with evidence obtained in other areas of the audit. Professionals with specialized skill and knowledge were used to assist in the evaluation of the Company’s discounted cash flow model and the long-term rate of growth and discount rate assumptions.
Accounting for the Effects of Regulatory Matters
As described in Notes 2, 6, and 14 to the consolidated financial statements, Cleco Power LLC (“Cleco Power”), a wholly-owned subsidiary of the Company, complies with the accounting policies and practices prescribed by its regulatory commissions, Federal Energy Regulatory Commission (FERC) and the Louisiana Public Service Commission (LPSC). Cleco Power’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC, while rates for wholesale power sales are based on market-based rates and are ultimately reviewed by FERC. Cleco Power must evaluate its various transactions related to regulatory orders and accounting guidance to ensure the appropriate timing of revenue recognition, the evaluation of cost deferral, and the recoverability and refund of certain assets. Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process. As of December 31, 2024, there were $617.7 million of deferred costs included in regulatory assets and $127.7 million of regulatory liabilities awaiting cash outflow or potential refund. Under the current regulatory environment, Cleco Power believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable,
Cleco Power would be required to write-down such assets. Further, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power could require discontinuance of the application of the authoritative guidance of regulated operations.
The principal considerations for our determination that performing procedures relating to the accounting for the effects of regulatory matters is a critical audit matter are (i) the significant judgment by management in evaluating the impact of regulatory orders and accounting guidance on relevant transactions and (ii) a high degree of auditor judgment, subjectivity, and effort in performing audit procedures and evaluating audit evidence related to the timing of revenue recognition, the evaluation of cost deferral, and the recoverability and refund of certain assets.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included, among others, evaluating (i) management’s process for identifying relevant transactions which require regulatory treatment; (ii) management’s assessment regarding the accounting impacts arising from regulatory orders and accounting guidance; (iii) the reasonableness of management’s assessment regarding the timing of revenue recognition, probability of recovery of regulatory assets, and the establishment of regulatory liabilities; and (iv) the regulatory assets and liabilities calculated by management based on provisions and formulas outlined in rate orders and other correspondence.
/s/ PricewaterhouseCoopers LLP
New Orleans, Louisiana
March 7, 2025
We have served as the Company’s auditor since 2016.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Statements of Income
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating revenue
Electric operations $ 1,048,371 $ 1,187,915 $ 1,513,386
Other operations 103,277 111,565 98,768
Gross operating revenue 1,151,648 1,299,480 1,612,154
Electric customer credits (3,940) (60,689) (7,674)
Operating revenue, net 1,147,708 1,238,791 1,604,480
Operating expenses
Fuel used for electric generation 244,122 506,264 430,215
Purchased power 117,129 160,570 286,756
Other operations and maintenance 253,528 248,085 230,175
Depreciation and amortization 244,707 199,935 186,139
Taxes other than income taxes 60,743 64,469 57,965
Regulatory disallowance - - 13,841
Total operating expenses 920,229 1,179,323 1,205,091
Operating income 227,479 59,468 399,389
Interest income 15,067 5,393 5,250
Allowance for equity funds used during construction 2,310 5,747 3,740
Equity income from investees, before tax
677 - -
Other expense, net (13,021) (694) (11,240)
Interest charges
Interest charges, net 156,718 165,529 145,773
Allowance for borrowed funds used during construction (3,163) (673) (1,817)
Total interest charges 153,555 164,856 143,956
Income (loss) from continuing operations before income taxes 78,957 (94,942) 253,183
Federal and state income tax expense (benefit) 14,056 (65,073) 20,035
Income (loss) from continuing operations, net of income taxes 64,901 (29,869) 233,148
Income (loss) from discontinued operations, net of income taxes 45,517 14,642 (44,337)
Net income (loss) $ 110,418 $ (15,227) $ 188,811
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Statements of Comprehensive Income
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Net income (loss)
$ 110,418 $ (15,227) $ 188,811
Other comprehensive income, net of tax
Postretirement benefits (loss) gain (net of tax expense of $973 in 2024, tax benefit of $1,905 in 2023, and tax expense of $8,728 in 2022)
2,428 (5,171) 23,688
Total other comprehensive (loss) income, net of tax
2,428 (5,171) 23,688
Comprehensive income (loss), net of tax
$ 112,846 $ (20,398) $ 212,499
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Balance Sheets
AT DEC. 31,
(THOUSANDS) 2024 2023
Assets
Current assets
Cash and cash equivalents $ 30,472 $ 122,576
Restricted cash and cash equivalents 15,918 15,818
Customer accounts receivable (less allowance for credit losses of $1,337 in 2024 and $3,012 in 2023)
47,520 48,949
Accounts receivable - affiliate 35,459 24,216
Other accounts receivable 23,979 30,518
Unbilled revenue 44,687 42,856
Fuel inventory, at average cost 95,810 68,387
Materials and supplies, at average cost 158,976 141,688
Energy risk management assets 11,294 8,129
Accumulated deferred fuel 457 11,627
Cash surrender value of company/trust-owned life insurance policies
61,891 56,922
Prepayments 27,685 24,269
Regulatory assets 295,125 34,280
Assets held for sale - discontinued operations
- 159,514
Other current assets - 918
Total current assets 849,273 790,667
Property, plant, and equipment
Property, plant, and equipment 4,991,574 4,838,994
Accumulated depreciation (1,050,376) (924,624)
Net property, plant, and equipment 3,941,198 3,914,370
Construction work in progress 138,040 119,572
Total property, plant, and equipment, net 4,079,238 4,033,942
Goodwill 1,490,797 1,490,797
Operating lease right of use assets 14,905 20,070
Restricted cash and cash equivalents 116,493 113,573
Note receivable - 11,990
Regulatory assets - deferred taxes, net 2,008 43,866
Regulatory assets 308,833 615,495
Intangible asset - securitization 384,908 398,658
Intangible assets - other 7,751 10,633
Assets held for sale - discontinued operations
- 546,218
Receivable - Cleco Cajun Divestiture
98,153 -
Other deferred charges 17,247 24,484
Total assets $ 7,369,606 $ 8,100,393
The accompanying notes are an integral part of the consolidated financial statements.
(Continued on next page)
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Balance Sheets
AT DEC. 31,
(THOUSANDS) 2024 2023
Liabilities and member’s equity
Liabilities
Current liabilities
Short-term debt $ 120,000 $ 110,000
Long-term debt and finance leases due within one year 264,934 256,811
Accounts payable 125,483 119,801
Accounts payable - affiliate 21,368 10,683
Customer deposits 58,002 56,982
Provision for rate refund 20,510 60,768
Taxes payable 59,629 19,963
Interest accrued 19,919 22,209
Energy risk management liabilities 256 15,786
Regulatory liabilities
8,327 21,939
Deferred compensation 17,013 14,277
Postretirement benefit obligations 26,439 35,520
Liabilities held for sale - discontinued operations
- 39,019
Other current liabilities 29,565 24,378
Total current liabilities 771,445 808,136
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net 748,246 801,397
Postretirement benefit obligations 166,702 196,321
Regulatory liabilities
1,500 -
Storm reserves 76,178 111,509
Asset retirement obligations 13,450 13,723
Operating lease liabilities 12,788 17,276
Provision for rate refund
19,896 -
Customer advances for construction
27,440 26,815
Credit deposits
14,750 7,000
Liabilities held for sale - discontinued operations
- 75,933
Other deferred credits 31,154 27,186
Total long-term liabilities and deferred credits 1,112,104 1,277,160
Long-term debt and finance leases, net 2,645,043 3,141,924
Total liabilities 4,528,592 5,227,220
Commitments and contingencies (Note 16)
Member’s equity 2,841,014 2,873,173
Total liabilities and member’s equity $ 7,369,606 $ 8,100,393
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Statements of Cash Flows
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating activities
Net income (loss)
$ 110,418 $ (15,227) $ 188,811
Adjustment to reconcile net income (loss) to net cash provided by operating activities
Depreciation and amortization
259,292 237,614 289,486
Provision for credit losses 2,048 5,506 3,357
Regulatory disallowance - - 13,841
Electric customer credits 1,300 58,700 -
Unearned compensation expense
8,774 10,102 5,502
Allowance for equity funds used during construction
(2,310) (5,747) (3,740)
Loss (gain) on energy risk management assets and liabilities, net
5,276 103,876 (21,805)
Loss on Cleco Cajun Divestiture
43,715 173,000 -
Deferred lease revenue
- (2,301) (9,205)
Deferred income taxes
(22,504) (75,103) (7,911)
Cash surrender value of company/trust-owned life insurance
(2,451) (2,211) 1,266
Derecognition of previously deferred Project Diamond Vault costs
10,336 - -
Changes in assets and liabilities
Accounts receivable
20,319 8,112 (61,848)
Accounts receivable - affiliate
(10,373) (9,445) (11,309)
Unbilled revenue
(1,831) 3,184 (8,377)
Fuel inventory and materials and supplies
(68,494) (52,621) (43,703)
Prepayments
(10,108) (22,438) (15,846)
Accounts payable
(11,856) (37,827) 20,711
Accounts payable - affiliate
10,685 (2,409) (38,206)
Customer deposits
7,654 5,311 6,778
Postretirement benefit obligations
(28,989) (2,793) (847)
Regulatory assets and liabilities, net
(5,397) 7,592 21,537
Deferred fuel recoveries (4,515) 54,028 8,742
Asset retirement obligations (6,701) (7,348) (4,958)
Other deferred accounts
2,943 (4,422) (8,339)
Taxes accrued
39,010 225 11,337
Interest accrued
(2,290) (3,330) 10,337
Energy risk management assets and liabilities, net
(8,973) (6,500) 6,500
Storm reserves
(37,094) 2,790 1,006
Other operating
(1,079) 874 (8,205)
Net cash provided by operating activities 296,805 421,192 344,912
Investing activities
Additions to property, plant, and equipment (259,525) (230,238) (236,767)
Return of investment in company-/trust-owned life insurance - 417 41,671
Payments received on note receivable 11,914 822 761
Proceeds from sale of discontinued operations (net of transaction fees of $10.8 million)
463,769 - -
Other investing
1,081 1,183 1,078
Net cash provided by (used in) investing activities 217,239 (227,816) (193,257)
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Statements of Cash Flows
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
(Continued on next page)
Financing activities
Draws on revolving credit facilities 142,000 125,000 226,000
Payments on revolving credit facilities (132,000) (124,000) (117,000)
Issuances of long-term debt
16,599 100,000 424,946
Repayments of long-term debt
(487,798) (175,174) (417,700)
Payment of financing costs
(7) (375) (6,968)
Distributions to member
(145,005) (53,496) (219,588)
Other financing
(1,017) (836) (755)
Net cash used in financing activities
(607,228) (128,881) (111,065)
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents (93,184) 64,495 40,590
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period
256,067 (1)
191,572 150,982
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period
$ 162,883 (2)
$ 256,067 (1)
$ 191,572
Supplementary cash flow information
Interest paid, net of amount capitalized
$ 155,670 $ 170,680 $ 131,760
Income taxes paid, net $ 9,138 $ 2,162 $ -
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment
$ 5,010 $ 5,052 $ 10,247
Reduction in property, plant, and equipment due to regulatory disallowance $ - $ - $ 13,841
Reduction in property, plant, and equipment due to securitization of capitalized storm costs $ - $ - $ 197,689
(1) Includes cash and cash equivalents of $122,576, current restricted cash and cash equivalents of $15,818, and non-current restricted cash and cash equivalents of $113,573. Also includes cash, cash equivalents, and restricted cash equivalents in assets held for sale of $4,100.
(2) Includes cash and cash equivalents of $30,472, current restricted cash and cash equivalents of $15,918, and non-current restricted cash and cash equivalents of $116,493.
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO
Consolidated Statements of Changes in Member’s Equity
(THOUSANDS)
MEMBERSHIP
INTEREST
RETAINED
EARNINGS AOCI
TOTAL
MEMBER’S
EQUITY
Balances, Dec. 31, 2021 $ 2,454,276 $ 523,509 $ (23,629) $ 2,954,156
Distributions to member
- (219,588) - (219,588)
Net income - 188,811 - 188,811
Other comprehensive income, net of tax - - 23,688 23,688
Balances, Dec. 31, 2022 $ 2,454,276 $ 492,732 $ 59 $ 2,947,067
Distributions to member
- (53,496) - (53,496)
Net loss - (15,227) - (15,227)
Other comprehensive loss, net of tax - - (5,171) (5,171)
Balances, Dec. 31, 2023 $ 2,454,276 $ 424,009 $ (5,112) $ 2,873,173
Distributions to member - (145,005) - (145,005)
Net income - 110,418 - 110,418
Other comprehensive income, net of tax - - 2,428 2,428
Balances, Dec. 31, 2024 $ 2,454,276 $ 389,422 $ (2,684) $ 2,841,014
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
Report of Independent Registered Public Accounting Firm
To the Board of Managers and Member of
Cleco Power LLC
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Cleco Power LLC and its subsidiaries (the “Company” or “Cleco Power”) as of December 31, 2024 and 2023, and the related consolidated statements of income, of comprehensive income, of changes in member’s equity, and of cash flows for each of the three years in the period ended December 31, 2024, including the related notes and financial statement schedule listed in the index appearing under Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024 in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated
financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Accounting for the Effects of Regulatory Matters
As described in Notes 2, 6, and 14 to the consolidated financial statements, the Company complies with the accounting policies and practices prescribed by its regulatory commissions, Federal Energy Regulatory Commission (FERC) and the Louisiana Public Service Commission (LPSC). The Company’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC, while rates for wholesale power sales are based on market-based rates and are ultimately reviewed by FERC. The Company must evaluate its various transactions related to regulatory orders and accounting guidance to ensure the appropriate timing of revenue recognition, the evaluation of cost deferral, and the recoverability and refund of certain assets. The Company capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process. As of December 31, 2024, there were $510.1 million of deferred costs included in regulatory assets and $127.7 million of regulatory liabilities awaiting cash outflow or potential refund. Under the current regulatory environment, the Company believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or competition, the Company’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable, the Company would be required to write-down such assets. Further, potential deregulation of the industry or possible future changes in the method of rate regulation of the Company could require discontinuance of the application of the authoritative guidance of regulated operations.
The principal considerations for our determination that performing procedures relating to the accounting for the effects of regulatory matters is a critical audit matter are (i) the significant judgment by management in evaluating the impact of regulatory orders and accounting guidance on relevant transactions and (ii) a high degree of auditor judgment, subjectivity, and effort in performing audit procedures and evaluating audit evidence related to the timing of revenue recognition, the evaluation of cost deferral, and the recoverability and refund of certain assets.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These
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CLECO POWER 2024 FORM 10-K
procedures included, among others, evaluating (i) management’s process for identifying relevant transactions which require regulatory treatment; (ii) management’s assessment regarding the accounting impacts arising from regulatory orders and accounting guidance; (iii) the reasonableness of management’s assessment regarding the timing of revenue recognition, probability of recovery of regulatory assets, and the establishment of regulatory liabilities; and (iv) the regulatory assets and liabilities calculated by management based on provisions and formulas outlined in rate orders and other correspondence.
/s/ PricewaterhouseCoopers LLP
New Orleans, Louisiana
March 7, 2025
We have served as the Company’s auditor since 2016.
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CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Statements of Income
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating revenue
Electric operations $ 1,051,253 $ 1,197,369 $ 1,523,066
Other operations 95,137 111,561 98,759
Affiliate revenue 12,452 8,904 6,377
Gross operating revenue 1,158,842 1,317,834 1,628,202
Electric customer credits (3,940) (60,689) (7,674)
Operating revenue, net 1,154,902 1,257,145 1,620,528
Operating expenses
Fuel used for electric generation 237,603 389,427 610,737
Purchased power 117,129 160,570 286,756
Other operations and maintenance 245,651 233,863 216,851
Depreciation and amortization 236,444 191,745 178,231
Taxes other than income taxes 57,754 60,676 55,075
Regulatory disallowance - - 13,841
Total operating expenses 894,581 1,036,281 1,361,491
Operating income 260,321 220,864 259,037
Interest income 4,125 5,011 5,082
Allowance for equity funds used during construction 2,310 5,747 3,740
Equity income from investees, before tax
677 - -
Other expense, net (11,151) (28) (7,081)
Interest charges
Interest charges, net 102,021 99,552 90,035
Allowance for borrowed funds used during construction (3,163) (673) (1,817)
Total interest charges 98,858 98,879 88,218
Income before income taxes 157,424 132,715 172,560
Federal and state income tax expense (benefit) 18,506 (4,434) 2,503
Net income $ 138,918 $ 137,149 $ 170,057
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Statements of Comprehensive Income
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Net income $ 138,918 $ 137,149 $ 170,057
Other comprehensive income, net of tax
Postretirement benefits gain (loss) (net of tax expense of $157 in 2024, tax benefit of $825 in 2023, and tax expense of $3,525 in 2022)
98 (2,237) 9,567
Amortization of interest rate derivatives to earnings (net of tax expense of $191 in 2024, $93 in 2023, and $93 in 2022)
154 251 251
Total other comprehensive income (loss), net of tax
252 (1,986) 9,818
Comprehensive income, net of tax $ 139,170 $ 135,163 $ 179,875
The accompanying notes are an integral part of the consolidated financial statements.
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CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Balance Sheets
AT DEC. 31,
(THOUSANDS) 2024 2023
Assets
Utility plant and equipment
Property, plant, and equipment $ 6,113,217 $ 5,969,355
Accumulated depreciation (2,348,169) (2,244,217)
Net property, plant, and equipment 3,765,048 3,725,138
Construction work in progress 136,217 118,249
Total utility plant and equipment, net 3,901,265 3,843,387
Current assets
Cash and cash equivalents 23,714 49,211
Restricted cash and cash equivalents 15,918 15,818
Customer accounts receivable (less allowance for credit losses of $1,337 in 2024 and $3,012 in 2023)
47,520 48,949
Accounts receivable - affiliate 1,174 4,543
Other accounts receivable 23,233 27,768
Unbilled revenue 44,687 42,856
Fuel inventory, at average cost 95,810 68,387
Materials and supplies, at average cost 158,976 141,688
Energy risk management assets 11,294 3,087
Accumulated deferred fuel 457 11,627
Cash surrender value of company-owned life insurance policies 10,123 9,792
Prepayments 23,524 17,375
Regulatory assets 287,390 26,545
Other current assets - 918
Total current assets 743,820 468,564
Operating lease right of use assets 14,905 20,070
Restricted cash and cash equivalents 116,469 113,549
Note receivable - 11,990
Regulatory assets - deferred taxes, net 2,008 43,866
Regulatory assets 209,028 505,623
Intangible asset - securitization 384,908 398,658
Other deferred charges 16,366 23,835
Total assets $ 5,388,769 $ 5,429,542
The accompanying notes are an integral part of the consolidated financial statements.
(Continued on next page)
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CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Balance Sheets
AT DEC. 31,
(THOUSANDS) 2024 2023
Liabilities and member’s equity
Member’s equity $ 2,107,407 $ 2,063,237
Long-term debt and finance leases, net 1,546,624 1,697,152
Total capitalization 3,654,031 3,760,389
Current liabilities
Short-term debt 110,000 -
Long-term debt and finance leases due within one year 264,934 190,314
Accounts payable 110,361 95,565
Accounts payable - affiliate 11,389 13,200
Customer deposits 58,002 56,982
Provision for rate refund 20,510 60,768
Taxes payable
13,422 23,709
Interest accrued 11,781 11,752
Energy risk management liabilities 256 15,112
Regulatory liabilities
8,327 21,939
Postretirement benefit obligations 21,701 30,777
Other current liabilities 17,131 14,617
Total current liabilities 647,814 534,735
Commitments and contingencies (Note 16)
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net 788,016 806,560
Postretirement benefit obligations 109,464 132,321
Regulatory liabilities
1,500 -
Storm reserves 76,178 111,509
Asset retirement obligations 13,450 13,598
Operating lease liabilities 12,788 17,276
Provision for rate refund
19,896 -
Customer advances for construction
27,440 26,815
Credit deposits
14,750 7,000
Other deferred credits 23,442 19,339
Total long-term liabilities and deferred credits 1,086,924 1,134,418
Total liabilities and member’s equity $ 5,388,769 $ 5,429,542
The accompanying notes are an integral part of the consolidated financial statements.
CLECO
CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Statements of Cash Flows
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating activities
Net income $ 138,918 $ 137,149 $ 170,057
Adjustment to reconcile net income to net cash provided by operating activities
Depreciation and amortization
242,117 197,366 185,029
Provision for credit losses 2,048 5,506 3,357
Regulatory disallowance - - 13,841
Electric customer credits 1,300 58,700 -
Unearned compensation expense
1,867 1,661 858
Allowance for equity funds used during construction
(2,310) (5,747) (3,740)
Deferred income taxes
12,380 (21,112) (4,690)
Derecognition of previously deferred Project Diamond Vault costs
10,336 - -
Changes in assets and liabilities
Accounts receivable
(1,377) 18,044 (48,353)
Accounts receivable - affiliate
5,176 1,286 13,253
Unbilled revenue
(1,831) 3,184 (8,377)
Fuel inventory and materials and supplies
(44,615) (36,443) (27,764)
Prepayments
(5,875) (5,407) (3,808)
Accounts payable
(5,295) (19,185) (854)
Accounts payable - affiliate
(2,255) 1,060 (56,714)
Customer deposits
7,654 5,311 6,778
Postretirement benefit obligations
(27,175) (1,839) 215
Regulatory assets and liabilities, net
(7,384) 5,604 19,550
Deferred fuel recoveries (4,515) 54,028 8,742
Asset retirement obligations (3,489) (7,124) (4,728)
Other deferred accounts
10,564 1,651 (3,287)
Taxes accrued
(11,845) 6,567 9,704
Interest accrued
29 (3,524) 10,196
Energy risk management assets and liabilities, net
(8,973) - -
Storm reserves
(37,094) 2,790 1,006
Other operating
2,229 417 (6,006)
Net cash provided by operating activities 270,585 399,943 274,265
Investing activities
Additions to property, plant, and equipment
(255,336) (220,982) (228,940)
Payments received on note receivable
11,914 822 761
Return of investment in company-owned life insurance
- 417 6,496
Other investing
1,081 1,086 990
Net cash used in investing activities (242,341) (218,657) (220,693)
Financing activities
Draws on revolving credit facility 110,000 25,000 162,000
Payments on revolving credit facility - (70,000) (117,000)
Issuances of long-term debt
16,599 100,000 424,946
Repayments of long-term debt
(81,098) (109,574) (350,000)
Payment of financing costs (205) (104) (6,960)
Distributions to member
(95,000) (94,838) (105,500)
Other financing
(1,017) (836) (755)
Net cash (used in) provided by financing activities (50,721) (150,352) 6,731
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents (22,477) 30,934 60,303
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period
178,578 (1)
147,644 87,341
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period
$ 156,101 (2)
$ 178,578 (1)
$ 147,644
The accompanying notes are an integral part of the consolidated financial statements.
(Continued on next page)
CLECO
CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Statements of Cash Flows
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Supplementary cash flow information
Interest paid, net of amount capitalized
$ 96,700 $ 98,143 $ 71,912
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment
$ 5,010 $ 4,196 $ 9,954
Reduction in property, plant, and equipment due to regulatory disallowance $ - $ - $ 13,841
Reduction in property, plant, and equipment due to securitization of capitalized storm costs $ - $ - $ 197,689
(1) Includes cash and cash equivalents of $49,211, current restricted cash and cash equivalents of $15,818, and non-current restricted cash and cash equivalents of $113,549.
(2) Includes cash and cash equivalents of $23,714, current restricted cash and cash equivalents of $15,918, and non-current restricted cash and cash equivalents of $116,469.
The accompanying notes are an integral part of the consolidated financial statements.
CLECO
CLECO POWER 2024 FORM 10-K
CLECO POWER
Consolidated Statements of Changes in Member’s Equity
(THOUSANDS) MEMBER’S
EQUITY
AOCI
TOTAL
MEMBER’S
EQUITY
Balances, Dec. 31, 2021 $ 1,966,720 $ (18,183) $ 1,948,537
Distributions to member (105,500) - (105,500)
Net income 170,057 - 170,057
Other comprehensive income, net of tax - 9,818 9,818
Balances, Dec. 31, 2022 $ 2,031,277 $ (8,365) $ 2,022,912
Distributions to member (94,838) - (94,838)
Net income 137,149 - 137,149
Other comprehensive loss, net of tax - (1,986) (1,986)
Balances, Dec. 31, 2023 $ 2,073,588 $ (10,351) $ 2,063,237
Distributions to member (95,000) - (95,000)
Net income 138,918 - 138,918
Other comprehensive income, net of tax - 252 252
Balances, Dec. 31, 2024 $ 2,117,506 $ (10,099) $ 2,107,407
The accompanying notes are an integral part of the consolidated financial statements.
CLECO
CLECO POWER 2024 FORM 10-K
Index to Applicable Notes to the Financial Statements of the Registrants
Note 1 The Company Cleco and Cleco Power
Note 2 Summary of Significant Accounting Policies Cleco and Cleco Power
Note 3 Discontinued Operations Cleco
Note 4 Leases Cleco and Cleco Power
Note 5 Revenue Recognition Cleco and Cleco Power
Note 6 Regulatory Assets and Liabilities Cleco and Cleco Power
Note 7 Jointly Owned Generation Units Cleco and Cleco Power
Note 8 Fair Value Accounting Instruments Cleco and Cleco Power
Note 9 Derivative Instruments Cleco and Cleco Power
Note 10 Debt Cleco and Cleco Power
Note 11 Pension Plan and Employee Benefits Cleco and Cleco Power
Note 12 Income Taxes Cleco and Cleco Power
Note 13 Segment Disclosures Cleco
Note 14 Regulation and Rates Cleco and Cleco Power
Note 15 Variable Interest Entities Cleco and Cleco Power
Note 16 Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees Cleco and Cleco Power
Note 17 Affiliate Transactions Cleco and Cleco Power
Note 18 Intangible Assets and Goodwill Cleco and Cleco Power
Note 19 Accumulated Other Comprehensive Loss Cleco and Cleco Power
Note 20 Storm Restoration Cleco and Cleco Power
Notes to the Financial Statements
Note 1 - The Company
Cleco is composed of the following:
•Cleco Power, a regulated electric utility subsidiary, which owns eight generating units with a total rated capacity of 2,676 MW and serves approximately 295,000 customers in Louisiana through its retail business and supplies wholesale power in Louisiana. Cleco Power also owns a 50% interest in Oxbow. Cleco Power owns all of the outstanding membership interests in Cleco Securitization I and Cleco Securitization II, special purpose limited liability companies that are consolidated with Cleco Power in its financial statements. For more information on Oxbow and Cleco Securitization I, see Note 15 - “Variable Interest Entities.” Cleco Securitization II was formed in preparation of issuing energy transition bonds to finance the securitization of the stranded costs associated with the retirement of the Dolet Hills Power Station as well as deferred fuel and other mine-related costs. For more information on the securitization, see Note 16 - “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
•Prior to the close of the Cleco Cajun Divestiture, Cleco Cajun, an unregulated electric utility subsidiary, which owned 14 generating units with a total rated capacity of 3,379 MW and supplied wholesale power and capacity in Louisiana. The Cleco Cajun Divestiture closed on June 1, 2024. For more information, see Note 3 - “Discontinued Operations.”
•Cleco’s other operations consist of the following:
◦Cleco Holdings, a holding company,
◦Support Group, a shared services subsidiary, and
◦Diversified Lands, an investment subsidiary.
Note 2 - Summary of Significant Accounting Policies
Discontinued Operations
In March 2023, Cleco Holdings’ management, with the support of its Board of Managers, committed to a plan of action for the disposition of the Cleco Cajun Sale Group. As a result, Cleco Holdings’ management determined that the criteria under GAAP for the Cleco Cajun Sale Group to be classified as held for sale were met, and the sale represents a strategic shift that will have a major effect on Cleco’s future operations and financial results. Therefore, the results of operations and financial position of the Cleco Cajun Sale Group have been presented as discontinued operations since March 31, 2023. On June 1, 2024, the Cleco Cajun Divestiture closed. For more information, see Note 3 - “Discontinued Operations.”
Use of Estimates
The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.
Principles of Consolidation
The accompanying consolidated financial statements of Cleco include the accounts of Cleco Holdings and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
Following the formation of Cleco Securitization I and the closing of the storm recovery securitization financing on June 22, 2022, Cleco Power became the primary beneficiary of Cleco Securitization I, and as a result, the financial statements of Cleco Securitization I are consolidated with the financial statements of Cleco Power. For additional information about
CLECO
CLECO POWER 2024 FORM 10-K
Cleco Securitization I, see Note 15 - “Variable Interest Entities.” For additional information about the storm recovery securitization financing and its regulatory impacts, see Note 6- “Regulatory Assets and Liabilities - Deferred Storm Restoration Costs.”
Cleco Securitization II is a special-purpose, wholly owned subsidiary of Cleco Power that was formed in preparation of issuing energy transition bonds to finance the securitization of stranded costs associated with the retirement of the Dolet Hills Power station as well as deferred fuel and other mine-related costs. Cleco Power has contributed its initial investment in accordance with the operating agreement of Cleco Securitization II and expects the securitization financing to close by the end of March 2025. Cleco Power is the owner of Cleco Securitization II, and as a result, the financial statements of Cleco Securitization II are consolidated with the financial statements of Cleco Power. For more information on the securitization settlement , see Note 16 - “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
Goodwill
Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject to amortization. Goodwill is assessed as of August 1 of each year or more often if an event occurs or circumstances change that would indicate the carrying amount may be impaired. For more information on goodwill, see Note 18 - “Intangible Assets and Goodwill - Goodwill.”
Intangible Assets
Intangible assets include Cleco Securitization I’s right to bill and collect storm recovery charges and fair value adjustments for acquired long-term wholesale power supply agreements. These intangible assets are being amortized in a manner that best reflects the economic impact derived from such assets.
Impairment is tested if there are events or circumstances that indicate that an impairment analysis should be performed. If such an event or circumstance occurs, intangible impairment testing is performed prior to goodwill impairment testing. Impairment is calculated as the excess of the asset and liabilities’ respective carrying amounts over their respective fair values. For more information on intangible assets, see Note 18 - “Intangible Assets and Goodwill.”
Statements of Cash Flows
Cleco’s and Cleco Power’s Consolidated Statements of Cash Flows are prepared using the indirect method. This method requires adjusting net income to remove the effects of all deferrals and accruals of operating cash receipts and payments and to remove items whose cash effects are related to investing and financing cash flows. For more information on Cleco’s treatment of discontinued operations on the Consolidated Statements of Cash Flows, see, Note 3 - “Discontinued Operations.”
Regulation
Cleco Power is subject to regulation by FERC and the LPSC. Cleco Power complies with the accounting policies and practices prescribed by its regulatory commissions. Cleco Power’s retail rates are regulated by the LPSC and rates for transmission services are regulated by FERC. Rates for
wholesale power sales are based on market-based rates. Cleco Power must evaluate its various transactions related to regulatory orders and accounting guidance to ensure the appropriate timing of revenue recognition, the evaluation of cost deferral, and the recoverability of certain assets and refund of certain liabilities. Cleco Power capitalizes or defers certain costs for recovery from its customers and recognizes a liability for amounts expected to be returned to its customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process. Regulatory assets and liabilities are amortized consistent with the treatment in the ratemaking process. Pursuant to this regulatory process, Cleco Power has recorded regulatory assets and liabilities.
Any future plan adopted by the LPSC for purposes of transitioning utilities from LPSC regulation to retail competition may affect the regulatory assets and liabilities recorded by Cleco Power if the criteria for the application of the authoritative guidelines for industry regulated operations cannot continue to be met. At this time, Cleco Power cannot predict whether any legislation or regulation affecting Cleco Power will be enacted or adopted and, if enacted, what form such legislation or regulation may take.
For more information regarding the regulatory assets and liabilities recorded by Cleco Power, see Note 6 - “Regulatory Assets and Liabilities.” For more information on Cleco Power’s retail rates, see Note 14 - “Regulation and Rates.”
AROs
Cleco Power recognizes an ARO when there is a legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel to incur costs to remove an asset when the asset is retired. These guidelines also require an ARO, which is conditional on a future event, to be recorded even if the event has not yet occurred.
Cleco Power recognizes AROs at the present value of the projected liability in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is accreted to its present value each accounting period. Cleco Power defers this accretion as a regulatory asset based on its determination that these costs can be collected from customers. Concurrent with the recognition of the liability, Cleco Power capitalizes these costs to the related property, plant, and equipment asset. These capitalized costs are depreciated over the same period as the related property asset. Cleco Power also defers the current depreciation of the asset retirement cost as a regulatory asset.
For more information on Cleco Power’s ARO regulatory asset, see Note 6 - “Regulatory Assets and Liabilities - AROs.”
Property, Plant, and Equipment
Property, plant, and equipment consists primarily of electric utility generation and energy transmission and distribution assets. Property, plant, and equipment are stated at the cost to acquire or construct the assets, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant, and equipment at Cleco Power’s share of the cost to construct or purchase the respective assets. For information on jointly owned assets, see Note 7 - “Jointly Owned Generation Units.”
CLECO
CLECO POWER 2024 FORM 10-K
At the date of the 2016 Merger, Cleco’s gross balance of fixed depreciable assets was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on such date. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation.
Cleco’s cost of improvements to property, plant, and equipment is capitalized. Costs associated with repairs and major maintenance projects are expensed as incurred. Cleco capitalizes the cost to purchase or develop software for internal use.
Cleco Power defers project costs to construction work in progress that it believes are prudently incurred and probable of recovery through future rates. These deferred costs are related to the initial stage of a construction project during which time the feasibility of the construction of property, plant, and equipment is being investigated. In 2022, Cleco Power began development efforts for Project Diamond Vault, which intended to use an amine-based carbon capture technology with the goal of reducing Madison Unit 3’s carbon dioxide emissions. In connection with this effort, a $9.0 million congressional appropriation was secured to help offset the costs associated with a related Feasibility study, a Pre-FEED study, and a FEED study. Both the related Feasibility study and the Pre-FEED study have been completed. The FEED study, which focused on the use of this amine-based carbon capture technology began in April 2024. Due to increases in the estimated investment required as well as the current economic and financing environment, Cleco Power’s management decided to discontinue the FEED study and transition to evaluate other potential carbon capture and sequestration technologies or alternatives to decarbonize Madison Unit 3, including fuel switching technology. At December 31, 2023, Cleco Power had $10.3 million of deferred project costs related to Project Diamond Vault recorded in Construction work in progress on Cleco’s and Cleco Power’s Consolidated Balance Sheets. As of June 30, 2024, Cleco Power deferred an additional $0.5 million of project costs to Construction work in progress on Cleco’s and Cleco Power’s Consolidated Balance Sheets. Subsequently, at June 30, 2024, due to the uncertainty of recoverability and given that the unique nature of these costs did not relate to Cleco’s core operations, $10.8 million of these previously deferred project costs were removed from Construction work in progress on Cleco’s and Cleco Power’s Consolidated Balance Sheets and recorded to Other expense, net on Cleco’s and Cleco Power’s Consolidated Statements of Income. As of December 31, 2024, Cleco Power has recorded a total of $11.8 million, net of $7.5 million received from the congressional appropriation, to Other expense, net on Cleco’s and Cleco Power’s Consolidated Statements of Income for costs related to Project Diamond Vault. Cleco Power has incurred an additional $0.4 million of expenses and has submitted these costs for reimbursement from the congressional appropriation.
Upon retirement or disposition, the cost of Cleco Power’s depreciable plant and the cost of removal, net of salvage value, are charged to accumulated depreciation. For Cleco’s other subsidiaries, upon disposition or retirement of depreciable assets, the difference between the net book value of the property and any proceeds received for the property is recorded as a gain or loss on asset disposition on Cleco’s Consolidated Statements of Income. Any cost incurred to remove the asset is charged to expense.
The amounts of unamortized computer software costs on Cleco’s Consolidated Balance Sheets at December 31, 2024, and 2023 were $171.4 million and $156.7 million, respectively. The amounts of unamortized computer software costs on Cleco Power’s Consolidated Balance Sheets at December 31, 2024, and 2023 were $170.0 million and $154.9 million, respectively. Amortization of capitalized computer software costs charged to expense in Cleco’s and Cleco Power’s Consolidated Statements of Income for the years ending December 31, 2024, 2023, and 2022 is shown in the following tables:
Cleco
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Amortization
$ 19,981 $ 11,092 $ 11,881
Cleco Power
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Amortization
$ 19,574 $ 10,650 $ 11,614
During 2024, there was a change in the estimated life of the internal software Cleco Power owns and used to provide services to Cleco Cajun in accordance with service level agreements. As a result, Cleco Power recorded an increase of $7.1 million for accelerated amortization of the internal software.
Depreciation on property, plant, and equipment is calculated primarily on a straight-line basis over the useful lives of the assets. The following table presents the useful lives of depreciable assets for Cleco and Cleco Power:
CATEGORY (YEARS) YEARS
Utility Plants
Generation
10 - 55
Distribution
15 - 50
Transmission
5 - 55
Other utility plant
5 - 45
Other property, plant, and equipment
5 - 45
At December 31, 2024, and 2023, Cleco’s and Cleco Power’s property, plant, and equipment consisted of the following:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Utility plants
Generation $ 1,914,812 $ 1,944,260
Distribution 1,693,668 1,585,742
Transmission 878,833 844,897
Other utility plant 490,975 454,329
Other property, plant, and equipment 13,286 9,766
Total property, plant, and equipment 4,991,574 4,838,994
Accumulated depreciation (1,050,376) (924,624)
Net property, plant, and equipment $ 3,941,198 $ 3,914,370
CLECO
CLECO POWER 2024 FORM 10-K
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Regulated utility plants
Generation $ 2,300,880 $ 2,339,410
Distribution 2,129,721 2,022,257
Transmission 1,089,964 1,056,218
Other utility plant 592,652 551,470
Total property, plant, and equipment 6,113,217 5,969,355
Accumulated depreciation (2,348,169) (2,244,217)
Net property, plant, and equipment $ 3,765,048 $ 3,725,138
During 2024, Cleco Power’s regulated utility property, plant, and equipment increased primarily due to replacing and upgrading distribution line equipment related to the DSMART project, as well as other distribution system improvements.
Cleco Power’s property, plant, and equipment includes plant acquisition costs related primarily to the acquisition of Acadia Unit 1 in 2010. The plant acquisition adjustment and accumulated amortization are reported in Property, plant, and equipment and Accumulated depreciation, respectively, on Cleco’s and Cleco Power’s Consolidated Balance Sheets at December 31, 2024, and 2023, and are shown in the following tables:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Acadia Unit 1
Plant acquisition adjustment $ 76,116 $ 76,116
Accumulated amortization (27,749) (24,566)
Net plant acquisition adjustment $ 48,367 $ 51,550
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Acadia Unit 1
Plant acquisition adjustment $ 95,578 $ 95,578
Accumulated amortization (47,211) (44,028)
Net plant acquisition adjustment $ 48,367 $ 51,550
Fuel Inventory and Materials and Supplies
At December 31, 2024, and 2023, fuel inventory consisted primarily of petroleum coke, coal, limestone, and natural gas used to generate electricity.
Materials and supplies consist of transmission and distribution line construction and repair materials, as well as generating station and transmission and distribution substation repair materials.
Both fuel inventory and materials and supplies are recorded at the lower of cost or net realizable value using the average cost method and are issued from stock using the average cost of existing stock. Fuel inventory is recorded when purchased and subsequently charged to expense when used. Materials and supplies are recorded when purchased and subsequently charged to expense or capitalized to property, plant, and equipment when installed.
Reserves for Credit Losses
Customer accounts receivable are recorded at the invoiced amount and do not bear interest. Customer accounts
receivable are generally considered past due 21 days after the billing date. Cleco recognizes write-offs within the allowance for credit losses once all recovery methods have been exhausted. It is the policy of management to review accounts receivable and unbilled revenue monthly using a reserve matrix based on historical bad debt write-off as well as current and forecasted economic conditions, to establish a credit loss estimate. Management’s historical credit loss analysis included periods of economic recessions, natural disasters, and temporary changes to collection policies. Due to the critical necessity of electricity, these past events have not significantly impacted Cleco’s credit loss rates.
Cleco’s credit losses at December 31, 2024, are within normal levels and historical trends.
The tables below present the changes in the allowance for credit losses by receivable for Cleco and Cleco Power:
Cleco
(THOUSANDS) ACCOUNTS
RECEIVABLE OTHER
TOTAL
Balances, Dec. 31, 2022 $ 1,147 $ 1,638 $ 2,785
Current period provision 5,506 - 5,506
Charge-offs (4,939) - (4,939)
Recovery 1,298 - 1,298
Balances, Dec. 31, 2023 3,012 1,638 4,650
Current period provision 2,048 - 2,048
Charge-offs (4,815) - (4,815)
Recovery 1,092 - 1,092
Balances, Dec. 31, 2024 $ 1,337 $ 1,638 $ 2,975
Cleco Power
(THOUSANDS) ACCOUNTS
RECEIVABLE
Balances, Dec. 31, 2022 $ 1,147
Current period provision 5,506
Charge-offs (4,939)
Recovery 1,298
Balances, Dec. 31, 2023 3,012
Current period provision 2,048
Charge-offs (4,815)
Recovery 1,092
Balances, Dec. 31, 2024 $ 1,337
Cleco also has a receivable in conjunction with the Cleco Cajun Divestiture of $113.0 million, discounted to its net present value. For more information on the receivable, see Note 3 - “Discontinued Operations.”
Other Reserves
Cleco maintains property insurance on generating stations, buildings and contents, and substations. Cleco is self-insured for any damage to its power lines. To mitigate the exposure to potential financial loss for storm-related damage to lines and property, the LPSC approved Cleco Power to establish a funded storm reserve. For more information on the storm reserve, see Note 6 - “Regulatory Assets and Liabilities - Storm Reserves.”
Cleco also maintains liability and workers’ compensation insurance to mitigate financial losses due to injuries and damages to the property of others. Cleco’s insurance covers claims that exceed certain self-insured limits. For claims within certain self-insured limits, Cleco maintains reserves. At December 31, 2024, and 2023, the general liability and
CLECO
CLECO POWER 2024 FORM 10-K
workers compensation reserves together were $11.5 million and $6.7 million, respectively.
Additionally, Cleco maintains directors and officers insurance to protect managers from claims which may arise from their decisions and actions taken within the scope of their regular duties.
Cash Equivalents
Cleco considers highly liquid, marketable securities, and other similar instruments with original maturity dates of three months or less to be cash equivalents.
Restricted Cash and Cash Equivalents
Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general company purposes.
Cleco’s and Cleco Power’s restricted cash and cash equivalents consisted of the following:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Current
Cleco Securitization I operating expenses and storm recovery bond issuance costs and debt service
$ 15,918 $ 15,818
Total current 15,918 15,818
Non-current
Cleco Securitization II operating expenses
1 -
Diversified Lands’ mitigation escrow 24 24
Cleco Power’s future storm restoration costs 116,468 113,549
Total non-current 116,493 113,573
Total restricted cash and cash equivalents $ 132,411 $ 129,391
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Current
Cleco Securitization I operating expenses and storm recovery bond issuance costs and debt service
$ 15,918 $ 15,818
Total current 15,918 15,818
Non-current
Cleco Securitization II operating expenses
1 -
Future storm restoration costs 116,468 113,549
Total non-current 116,469 113,549
Total restricted cash and cash equivalents $ 132,387 $ 129,367
On October 8, 2024, Cleco Power made a filing with the LPSC seeking approval to withdraw storm restoration costs associated with the April 2024 storm, as well as costs associated with other storm events that occurred since December 2022, from the storm reserve. This request is currently under review by the LPSC. For more information about the regulatory asset and storm reserves, see Note 6 - “Regulatory Assets and Liabilities - Storm Reserves.”
Equity Investments
Cleco and Cleco Power account for investments in unconsolidated affiliated companies using the equity method of accounting. The amounts reported on Cleco’s and Cleco
Power’s Consolidated Balance Sheets represent assets contributed by Cleco or Cleco Power, plus their share of the net income of the affiliate, less any distributions of earnings (dividends) received from the affiliate. The revenues and expenses (excluding income taxes) of these affiliates are netted and reported on one line item as equity income from investees on Cleco’s and Cleco Power’s Consolidated Statements of Income.
Cleco evaluates for impairments of equity method investments when events and circumstances have occurred that indicate a possible other-than-temporary decline in the fair value of the investment and the possible inability to recover the carrying value through operations. Cleco uses estimates of the future cash flows from the investee and observable market transactions in order to calculate fair value and recoverability. An impairment is recognized when an other-than-temporary decline in market value occurs and recovery of the carrying value is not probable. There were no impairments recorded for 2024, 2023, or 2022. For more information on Cleco’s equity investments, see Note 15 - “Variable Interest Entities.”
Income Taxes
Cleco accounts for income taxes under the asset and liability method. Income taxes recorded on the income statement and related balance sheet amounts are comprised of a current portion and a deferred portion. The current portion represents Cleco’s estimate of the income taxes payable or receivable for the current year. The deferred portion represents Cleco’s estimate of the future income tax effects of events that have been recognized in the financial statements or income tax returns in the current or prior years. Cleco makes assumptions and estimates when it records income taxes, such as its ability to deduct items on its tax returns, the timing of the deduction, and the effect of regulation on income taxes. Cleco’s income tax expense and benefit and related assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities and changes in tax regulations. The actual results may differ from the estimated results based on these assumptions and may have a material effect on Cleco’s results of operations. Cleco Group files a federal income tax return for all wholly owned subsidiaries. Cleco Power computes its federal and state income taxes as if it were a stand-alone taxpayer. The LPSC generally requires Cleco Power to flow the effects of state income taxes to customers. For more information on income taxes, see Note 12 - “Income Taxes.”
Investment Tax Credits
Investment tax credits, which were deferred for financial statement purposes, are amortized as a reduction to income tax expense over the estimated service lives of the properties that gave rise to the credits.
Debt Issuance Costs, Premiums, and Discounts
Issuance costs, premiums, and discounts applicable to debt securities are amortized to interest expense ratably over the lives of the related issuances. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issuance. Debt issuance costs, premiums, and discounts are presented as a direct deduction from the carrying value of the related debt liability.
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Revenue and Fuel Costs
Utility Revenue
Revenue from retail sales and transmission of electricity is recognized when the service is provided. The costs of fuel and purchased power used for Cleco Power’s retail customers currently are recovered from its customers through Cleco Power’s FAC. These costs are subject to audit and final determination by the LPSC. Sales taxes and pass-through fees collected on the sale of electricity are not recorded in utility revenue.
Cleco recognizes wholesale revenue, inclusive of both energy and capacity performance obligations, under the invoice practical expedient for the amount Cleco has the right to invoice.
Unbilled Revenue
Cleco Power accrues estimated revenue monthly for energy used by customers but not yet billed. The monthly estimated unbilled revenue amounts are recorded as unbilled revenue and a receivable. Cleco Power uses actual customer energy consumption data available from AMI to calculate unbilled revenues.
Other Operations Revenue
Other operations revenue is recognized at the time products or services are provided to and accepted by customers, and collectability is reasonably assured.
Sales and Use Taxes
Cleco collects a sales and use tax on the sale of electricity that subsequently is remitted to the state in accordance with state law. These amounts are not recorded as income or expense on Cleco’s or Cleco Power’s Consolidated Statements of Income but are reflected at gross amounts on Cleco’s and Cleco Power’s Consolidated Balance Sheets as a receivable until the tax is collected and as a payable until the liability is paid.
Franchise and Consumer Fees
Cleco Power operates under nonexclusive franchise rights granted by municipalities through franchise agreements in which franchise fees are collected and paid. A portion of the franchise fees associated with these franchise agreements is collected by Cleco Power from its retail customers and submitted to the municipality. These fees are recorded as a receivable until it is collected and as a payable until the liability is paid.
Cleco Power also pays periodic franchise fees to the government units, which may include upfront payments upon the renewal of the franchise agreement. The upfront payments are amortized over the life of the franchise agreement and the periodic fees are expensed in the period in which they are incurred. These amounts are recovered from retail customers through base rates.
Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s and Cleco Power’s Consolidated Statements of Income as revenue and expense, but is reflected at gross amounts on Cleco’s and Cleco Power’s Consolidated Balance Sheets as a receivable until it is collected and as a payable until the liability is paid.
AFUDC
The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC for which a return on and recovery of is permitted in setting rates charged for utility services. AFUDC represents the estimated debt and equity costs of capital funds that are necessary to finance construction of new and improvements to existing assets. While cash is not realized directly from such allowance, AFUDC increases the revenue requirement over the same life of the plant through a higher rate base and higher depreciation.
The following tables show the composite AFUDC rates, including borrowed and other funds for the years ended December 31, 2024, 2023, and 2022:
FOR THE YEAR ENDED DEC. 31,
2024 2023 2022
PRETAX BASIS NET OF TAX PRETAX BASIS NET OF TAX PRETAX BASIS NET OF TAX
AFUDC composite rate 8.65 % 7.62 % 8.11 % 6.50 % 9.06 % 7.09 %
Fair Value Measurements and Disclosures
Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes. For more information about fair value levels, see Note 8 - “Fair Value Accounting Instruments.”
Derivatives and Other Risk Management Activity
Accounting guidance requires derivative instruments and hedging activities to be recognized at fair value on the balance sheet. Cleco may elect the normal purchase and normal sale scope exception to the application of fair value accounting for these instruments and activities if they meet certain accounting criteria. Cleco’s Energy Market Risk Management Policy authorizes hedging against commodity price risk with physical
or financially settled derivative instruments. Due to regulatory treatment, associated mark-to-market adjustments for changes in fair value of recognized derivatives are generally recognized in Accumulated deferred fuel on the balance sheet. For more information on derivative instruments, see Note 9 - “Derivative Instruments.”
Accounting for MISO Transactions
Cleco Power participates in MISO’s Energy and Operating Reserve market and has the opportunity to participate in the MISO capacity market. The hourly power sales and purchases are netted and net sales and net purchases are reported in Electric operations and Purchased power, respectively, on Cleco’s and Cleco Power’s Consolidated Statements of Income. Power sales and purchases in the MISO market are made at prevailing market prices, also known as LMP, which represents the cost of providing the next MW of electrical energy at a specific location on the grid. LMP includes a component directly related to congestion on the transmission system and, as a result, can be different based on the location
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and time of the day the energy is dispatched causing energy costs to increase.
Leases
Cleco determines if a contract is a lease at its inception. A lease is deemed to exist when the right to control the use of identified property, plant, or equipment is conveyed through a contract for a certain period of time and consideration is paid. If a contract is determined to be a lease, Cleco recognizes a ROU asset and lease liability at the commencement date based on the present value of lease payments over the lease term. The present value of the lease payments is determined by using the implicit interest rate if readily determinable. Cleco’s incremental borrowing rate for a term similar to the duration of the lease based on information available at the commencement date is used if the implicit interest rate is not readily determinable.
Cleco recognizes ROU assets and lease liabilities for leasing arrangements with terms greater than one year. Except for the marine transportation asset class, Cleco accounts for lease and non-lease components in a contract as a single lease component for all classes of underlying assets. Cleco’s marine transportation contracts contain non-lease components, such as maintenance and labor. Cleco allocates the consideration in these contracts between lease and non-lease components based on estimates of fair value from third parties that typically execute leases for this class of assets.
Expense for a lessee operating lease is recognized as a single lease cost on a straight-line basis over the lease term and reflected in the appropriate income statement line item based on the leased asset’s function. Income for a lessor operating lease is recognized as a single lease income item on a straight-line basis over the lease term and reflected in the appropriate income statement line item based on the lease asset’s function. For more information on leases, see Note 4 - “Leases.”
Recent Authoritative Guidance
In March 2023, FASB issued guidance that applies to leases between entities under common control. The guidance provides a practical expedient for determining whether an arrangement between entities under common control is a lease as well as the classification of the lease. In addition, the leasehold improvements amortization period is to be determined by the useful life to the common group rather than the term of the lease. The new guidance is effective for fiscal years beginning after December 15, 2023, including interim periods within those fiscal years. Cleco has arrangements with entities under common control. The implementation of this guidance did not have a material impact on the results of operations, financial condition, or cash flows of the Registrants.
In November 2023, FASB issued guidance to improve reportable segment disclosure requirements. The guidance enhances interim disclosure requirements, clarifies circumstances in which an entity can disclose multiple segment measures of profit or loss, provides new segment disclosure requirements for entities with a single reportable segment, and contains other disclosure requirements. Disclosure requirements include disclosing significant segment expenses by reportable segment if they are regularly provided to the chief operating decision maker and included in each reported measure of segment profit or loss. Disclosures are required on both an annual and an interim basis. The guidance is effective for fiscal years beginning after December
15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted. The implementation of this guidance did not have a material impact on the results of operations, financial condition, or cash flows of the Registrants.
In December 2023, FASB issued guidance to improve disclosures relating to income taxes. The guidance enhances annual disclosure requirements by requiring registrants to disclose a greater disaggregation of information in the tabular rate reconciliation of income tax expense and increased disclosure of income taxes paid by jurisdiction. The guidance is effective for fiscal years beginning after December 15, 2024. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.
In November 2024, FASB issued guidance to improve disclosures of certain expenses. This guidance enhances annual and interim disclosure requirements by requiring registrants to disclose purchases of inventory, employee compensation, depreciation, intangible asset amortization, and depreciation, depletion, and amortization recognized as part of oil- and gas-producing activities. The guidance is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027, with early adoption permitted. This update should be applied either prospectively or retrospectively to all prior periods presented. Management expects to have additional disclosures upon adoption of this guidance, but does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.
Note 3 - Discontinued Operations
In March 2023, Cleco Holdings’ management, with the support of its Board of Managers, committed to a plan of action for the disposition of the Cleco Cajun Sale Group. As a result, Cleco Holdings’ management determined that the criteria under GAAP for the Cleco Cajun Sale Group to be classified as held for sale were met, and the sale represents a strategic shift that will have a major effect on Cleco’s future operations and financial results. Therefore, the results of operations and financial position of the Cleco Cajun Sale Group have been presented as discontinued operations since March 31, 2023. Certain expenses incurred by the Cleco Cajun Sale Group as a result of common services provided by Support Group are reflected in Cleco’s results of continuing operations due to the expected ongoing nature of those expenses. In addition, revenue recognized by Cleco Power from transmission services provided to the Cleco Cajun Sale Group is no longer eliminated upon consolidation of Cleco’s financial statements and is reflected in Cleco’s results of continuing operations due to the ongoing nature of these services.
On June 1, 2024, the Cleco Cajun Sellers completed the sale of the Cleco Cajun Sale Group. Upon closing, the Cleco Cajun Sellers received $474.5 million, net of adjustments as set forth in the Cleco Cajun Divestiture Purchase and Sale Agreement and adjustments based on net working capital. Also, in conjunction with the closing of the Cleco Cajun Divestiture, the Cleco Cajun Sellers paid $10.8 million to professional service firms that were engaged to facilitate the transaction. Cleco expects to receive an additional $113.0 million by June 2026, which is not contingent upon the post-divestiture performance of the divested business. This
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receivable is discounted to its net present value and recorded in Receivable - Cleco Cajun Divestiture on Cleco’s Consolidated Balance Sheet. In connection with the sale, Cleco entered into an other services agreement and a transition services agreement to provide certain services to the Cleco Cajun Purchasers for up to twelve months. As of December 31, 2024, the transition services agreement has been terminated.
In February 2019 in connection with the approval of the Cleco Cajun Acquisition, Cleco made commitments to the LPSC that included the repayment of $400.0 million of Cleco Holdings’ debt by December 31, 2024. On April 26, 2024, the remaining $66.7 million of that debt was paid and this LPSC commitment was satisfied. Interest expense on that debt is included in discontinued operations.
Cleco determined that the estimated fair value less the estimated cost to sell the Cleco Cajun Sale Group was less than the carrying value of the Cleco Cajun Sale Group. As a result, the Cleco Cajun Sale Group had an impairment of $173.0 million at December 31, 2023. During the three months
ended March 31, 2024, an additional impairment charge of $17.0 million was recorded. On June 1, 2024, the Cleco Cajun Divestiture closed, and an incremental $27.1 million loss on the sale of the Cleco Cajun Sale Group was recorded. This resulted in a cumulative loss related to the Cleco Cajun Divestiture of $217.1 million. The incremental loss on the sale of the Cleco Cajun Sale Group recognized during the three months ended June 30, 2024, was the difference between the fair value of the proceeds received and the derecognized net assets of the Cleco Cajun Sale Group on the closing date. During the three months ended September 30, 2024, the working capital adjustments related to the Cleco Cajun Divestiture were finalized and resulted in a $0.4 million decrease to the loss on the Cleco Cajun Divestiture that was previously recorded.
The following table presents the amounts that have been reclassified from continuing operations and included in discontinued operations within Cleco’s Consolidated Statements of Income for the years ended December 31, 2024, 2023, and 2022:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating revenue, net
Electric operations $ 207,555 $ 543,519 $ 496,042
Other operations 50,992 125,816 148,823
Operating revenue, net 258,547 669,335 644,865
Operating expenses
Fuel used for electric generation 21,061 126,130 169,195
Purchased power 93,074 230,284 380,233
Other operations and maintenance 37,685 87,599 70,611
Depreciation and amortization 4,336 15,891 69,999
Taxes other than income taxes
- 13,160 12,330
Total operating expenses 156,156 473,064 702,368
Operating income (loss)
102,391 196,271 (57,503)
Other income, net
240 47 127
Interest, net 1,396 (6,919) (6,079)
Loss - Cleco Cajun Divestiture(1)
(43,715) (173,000) -
Income (loss) from discontinued operations before income taxes 60,312 16,399 (63,455)
Federal and state income tax expense (benefit) 14,795 1,757 (19,118)
Income (loss) from discontinued operations, net of income taxes $ 45,517 $ 14,642 $ (44,337)
(1) This represents the loss on the classification as held for sale until the closing of the Cleco Cajun Divestiture. After the closing of the Cleco Cajun Divestiture, this represents the loss on the sale of the Cleco Cajun Sale Group.
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The following table presents the assets and liabilities of the Cleco Cajun Sale Group that were reclassified as held for sale within Cleco’s Consolidated Balance Sheets as of December 31, 2023:
(THOUSANDS) AT DEC. 31, 2023
Cash, cash equivalents, and restricted cash equivalents $ 4,100
Accounts receivable 70,001
Fuel inventory, at average cost 47,243
Materials and supplies, at average cost 36,283
Energy risk management assets 1,066
Property, plant, and equipment, net 648,676
Prepayments 18,587
Intangible assets - other 32,569
Other assets 20,207
Accumulated loss recognized on classification as held for sale
(173,000)
Total assets held for sale - discontinued operations $ 705,732
Accounts payable $ 30,442
Deferred lease revenue 19,945
Intangible liabilities 12,695
Asset retirement obligations 46,165
Other liabilities 5,705
Total liabilities held for sale - discontinued operations $ 114,952
Cleco has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. The following table presents the cash flows from discontinued operations related to the Cleco Cajun Sale Group for the years ended December 31, 2024, 2023, and 2022:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Net cash (used in) provided by operating activities - discontinued operations
$ (822) $ 8,778 $ 6,878
Net cash used in investing activities - discontinued operations $ (3,278) $ (8,745) $ (6,867)
Note 4 - Leases
Cleco maintains operating and finance leases in its ordinary course of business activities.
Operating Leases
Cleco Power leases utility systems from two municipalities and one non-municipal public body. One municipal lease has a term of 10 years and expires on August 11, 2031. The second municipal lease has a term of 10 years and expires on May 13, 2028. The non-municipal lease has a term of 27 years and expires on July 31, 2039. Each utility system lease contains fixed and variable components, as well as provisions for extensions.
During 2024, Cleco Power renewed its lease for 111 railcars for coal transportation which expires on March 31, 2027. Cleco Power reassesses its need for the railcars upon the expiration of each term. Cleco Power pays a monthly rental fee per car. The railcar lease does not contain contingent rent payments.
Cleco Power had leases for three towboats in order to transport petroleum coke to Madison Unit 3. During 2024, Cleco Power modified its agreement to reduce the number of
towboats to two with an expiration date of April 2025 due to a change in fuel strategy.
As a result of a cancellation notice and two amendments, Cleco Power reclassified its barge finance lease to an operating lease for 20 barges through April 15, 2025. For more information on the barge lease see “- Finance Lease.”
Cleco’s and Cleco Power’s remaining operating leases provide for office and operating facilities, office equipment, and tower rentals.
The following is a schedule by year of future minimum lease payments due under Cleco’s and Cleco Power’s long-term operating leases together with the present value of the net minimum lease payments as of December 31, 2024:
(THOUSANDS)
Years ending Dec. 31,
2025 $ 3,167
2026 2,596
2027 2,347
2028 2,208
2029 2,205
Thereafter 5,370
Total minimum lease payments
17,893
Less: amount representing interest
2,351
Present value of net minimum operating lease payments
$ 15,542
Current liabilities
$ 2,754
Non-current liabilities $ 12,788
Finance Lease
In April 2018, Cleco Power entered into an agreement with Savage Inland Marine for continued use of barges used to transport solid fuel to Madison Unit 3 through March 2033. Upon commencement, Cleco Power loaned Savage Inland Marine $16.8 million to purchase the barges and a receivable was established. At December 31, 2023, $12.9 million of this receivable remained. At December 31, 2024, this receivable was satisfied as part of the termination of the finance lease discussed below. The agreement met the accounting definition of a finance lease at inception.
The barge lease rate contained both a fixed and variable component, of which the latter was adjusted periodically for associated executory costs. If the barges were idle, the lessor was required to attempt to sublease the barges to third parties with the revenue reducing Cleco Power’s lease payment. At December 31, 2023, the amount of leased property under the finance lease consisted of $16.8 million for barges and $6.4 million of accumulated amortization, for a net finance lease asset of $10.4 million.
In October 2024, pursuant to a provision for early termination in accordance with the terms of the agreement, Cleco Power notified Savage Inland Marine that Cleco Power would be terminating the lease agreement effective April 15, 2025. This resulted in the lease being classified as an operating lease. Consequently, the net finance lease asset and finance lease obligation were derecognized and a $2.2 million gain was recorded in Accumulated deferred fuel on Cleco’s and Cleco Power’s Consolidated Balance Sheets. In addition, an operating lease obligation of $0.4 million was recognized.
For the year ended December 31, 2024, Cleco Power paid $2.0 million in lease payments. For each of the years ended December 31, 2023 and 2022, Cleco Power paid $2.2 million in lease payments. For the years ended December 31, 2024, 2023, and 2022, Cleco Power received $0.7 million, $2.6
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million, and $0.6 million, respectively, of revenue from subleases.
Additional Lessee Disclosures
Cleco’s and Cleco Power’s total lease cost includes amounts on the income statement, as well as amounts capitalized as part of property, plant, or equipment or inventory. The following tables reflect total lease costs for Cleco and Cleco Power for the years ended December 31, 2024, and 2023:
Cleco
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023
Finance lease cost
Amortization of ROU assets
$ 1,027 $ 1,120
Interest on lease liabilities
1,175 1,367
Operating lease cost
3,772 3,589
Variable lease cost
737 790
Total lease cost
$ 6,711 $ 6,866
Cleco Power
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023
Finance lease cost
Amortization of ROU assets
$ 1,027 $ 1,120
Interest on lease liabilities
1,175 1,367
Operating lease cost
3,772 3,581
Variable lease cost
737 790
Total lease cost
$ 6,711 $ 6,858
The following tables present additional information related to Cleco’s and Cleco Power’s operating and finance leases as of and for the years ended December 31, 2024, and 2023:
AT DEC. 31,
(THOUSANDS) BALANCE SHEET LINE ITEM 2024 2023
Supplemental balance sheet information
ROU assets
Operating
Operating lease right of use assets
$ 14,905 $ 20,070
Finance
Property, plant, and equipment
- 10,360
Total ROU assets
$ 14,905
$ 30,430
Current lease liabilities
Operating
Other current liabilities
$ 2,754 $ 2,973
Finance
Long-term debt and finance leases due within one year
- 925
Non-current lease liabilities
Operating
Operating lease liabilities
12,788 17,276
Finance
Long-term debt and finance leases, net
- 12,046
Total lease liabilities
$ 15,542 $ 33,220
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023
Supplemental cash flow information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases
$ 3,663 $ 3,571
Operating cash flows from finance leases
$ 1,175 $ 1,367
Financing cash flows from finance leases
$ 844 $ 836
AT DEC. 31,
(THOUSANDS) 2024 2023
Other supplemental information
Operating leases
Weighted-average remaining lease term
11.7 years
12.2 years
Weighted-average discount rate
4.16 % 4.30 %
Finance leases
Weighted-average remaining lease term
N/A
9.3 years
Weighted-average discount rate
N/A 10.18 %
Note 5 - Revenue Recognition
Revenue from Contracts with Customers
Retail Revenue
Retail revenue from contracts with customers is generated primarily from Cleco’s regulated electric sales from residential, commercial, and industrial customers. Cleco Power recognizes retail revenue from these contracts as a series, and progress towards satisfaction of the performance obligation is measured using an output method based on kWh delivered. Accordingly, revenue from electricity sales is recognized as energy is delivered to the customer. Cleco Power bills retail customers, based on rates regulated by the LPSC, on a monthly basis with payments generally due within 20 days of the invoice date.
Included in retail revenue is unbilled electric revenue, which represents the amount customers will be billed for services rendered from the meter reading from the most recent bill to the end of the respective accounting period. Actual customer energy consumption data available from AMI is used to calculate unbilled revenue. Also included in retail revenue is electric customer credits, which represents potential refunds to customers and offsets base revenue. For more information on the regulation of Cleco Power’s retail revenue, see Note 14 - “Regulation and Rates - TCJA” and “- FRP.”
Wholesale Revenue
Cleco’s wholesale revenue is generated primarily through the sale of energy and capacity to electric cooperatives and municipalities. The electricity revenue performance obligations, representing both energy and capacity, are satisfied as a series of performance obligations, and progress towards satisfaction of the performance obligations are measured using an output method. The energy performance obligation measure of progress is based on kWh delivered. The capacity performance obligation measure of progress is based on time elapsed and is recognized each month as Cleco’s generating units stand ready to deliver electricity to the customer. Cleco recognizes wholesale revenue, inclusive of both performance obligations, under the invoice practical expedient for the amount Cleco has the right to invoice. Wholesale customers are charged market based rates that are subject to FERC’s triennial market power analysis. Cleco also enters into transactions through MISO for spot energy sales which are transacted in the Day-Ahead Energy and Operating Reserves Market and the Real-Time Energy and Operating Reserves Market. For more information on the accounting for MISO transactions, see Note 2 - “Summary of Significant Accounting Policies - Accounting for MISO Transactions.”
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Transmission Revenue
Cleco Power earns transmission revenues pursuant to MISO’s FERC filed tariff. The performance obligation of transmission service is satisfied as service is provided. Revenue from the transmission of electricity for Cleco Power is recorded based on a separate FERC-approved annual filing rate mechanism effective June 1 of each year. These rates are based on the respective costs to provide transmission services.
Other Revenue
Other revenue from contracts with customers, which is not a significant source of Cleco’s revenue, consisted of customer-forfeited discounts and reconnect fees, electric property rental, and other miscellaneous fees. The performance obligation under these contracts is satisfied and revenue is recognized as control of the products is delivered or services are rendered.
Revenue Unrelated to Contracts with Customers
On September 1, 2022, Cleco Power began billing and collecting, on behalf of Cleco Securitization I, a new storm recovery surcharge from all retail customers. This surcharge represents the recovery of costs incurred by Cleco Power as a result of Hurricanes Laura, Delta, Zeta, and Ida and Winter Storms Uri and Viola, as well as interest and associated expenses. Cleco Power remits the collected storm recovery surcharge to Cleco Securitization I to service Cleco Securitization I storm recovery bonds. The storm recovery surcharge will continue to be billed and collected from Cleco Power’s retail customers through the life of the Cleco Securitization I storm recovery bonds.
Disaggregated Revenue
Operating revenue, net for the years ended December 31, 2024, 2023, and 2022 was as follows:
FOR THE YEAR ENDED DEC. 31, 2024
(THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)
$ 453,518 $ - $ - $ 453,518
Commercial (1)
302,380 - - 302,380
Industrial (1)
177,176 - - 177,176
Other retail (1)
16,317 - - 16,317
Electric customer credits (3,940) - - (3,940)
Total retail revenue 945,451 - - 945,451
Wholesale, net 99,128 (1)
(2,881) (2)
- 96,247
Transmission 43,004 - - 43,004
Other 19,514 - (22) 19,492
Affiliate (3)
12,452 108,127 (120,579) -
Total revenue from contracts with customers 1,119,549 105,246 (120,601) 1,104,194
Revenue unrelated to contracts with customers
Securitization 32,619 - - 32,619
Other 2,734 (4)
8,162 (5)
(1) 10,895
Total revenue unrelated to contracts with customers 35,353 8,162 (1) 43,514
Operating revenue, net $ 1,154,902 $ 113,408 $ (120,602) $ 1,147,708
(1) Includes fuel recovery revenue.
(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.
(3) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.
(4) Represents realized gains associated with FTRs. For more information on FTRs see Note 8 - “Fair Value Accounting Instruments - FTRs.”
(5) Primarily related to the other services agreement and transition services agreement as a result of the Cleco Cajun Divestiture.
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FOR THE YEAR ENDED DEC. 31, 2023
(THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)
$ 469,099 $ - $ - $ 469,099
Commercial (1)
304,422 - - 304,422
Industrial (1)
179,506 - - 179,506
Other retail (1)
16,543 - - 16,543
Electric customer credits (60,689) - - (60,689)
Total retail revenue 908,881 - - 908,881
Wholesale, net 221,547 (1)
(9,454) (2)
- 212,093
Transmission, net 56,701 - - 56,701
Other 20,797 - - 20,797
Affiliate (3)
8,904 120,716 (129,620) -
Total revenue from contracts with customers 1,216,830 111,262 (129,620) 1,198,472
Revenue unrelated to contracts with customers
Securitization
34,063 - - 34,063
Other 6,252 (4)
5 (1) 6,256
Total revenue unrelated to contracts with customers 40,315 5 (1) 40,319
Operating revenue, net $ 1,257,145 $ 111,267 $ (129,621) $ 1,238,791
(1) Includes fuel recovery revenue.
(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.
(3) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.
(4) Represents realized gains associated with FTRs. For more information on FTRs see Note 8 - “Fair Value Accounting Instruments - FTRs.”
FOR THE YEAR ENDED DEC. 31, 2022
(THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)
$ 558,247 $ - $ - $ 558,247
Commercial (1)
370,678 - - 370,678
Industrial (1)
229,634 - - 229,634
Other retail (1)
18,727 - - 18,727
Electric customer credits (7,674) - - (7,674)
Total retail revenue 1,169,612 - - 1,169,612
Wholesale, net 331,906 (1)
(9,680) (2)
- 322,226
Transmission
63,545 - - 63,545
Other 21,966 - - 21,966
Affiliate (3)
6,377 109,015 (115,392) -
Total revenue from contracts with customers 1,593,406 99,335 (115,392) 1,577,349
Revenue unrelated to contracts with customers
Securitization
13,247 - - 13,247
Other 13,875 (4)
9 - 13,884
Total revenue unrelated to contracts with customers 27,122 9 - 27,131
Operating revenue, net $ 1,620,528 $ 99,344 $ (115,392) $ 1,604,480
(1) Includes fuel recovery revenue.
(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.
(3) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.
(4) Represents realized gains associated with FTRs. For more information on FTRs see Note 8 - “Fair Value Accounting Instruments - FTRs.”
Cleco has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Cleco and Cleco Power have the right to bill the customer for services performed. Cleco’s contracts are based on demand, except in a few cases where there are defined minimums or stated terms. This results in customer bills that vary each month based on an approved tariff and usage. In limited cases, Cleco may impose monthly or annual minimum capacity requirements on some customers primarily as a credit and cost recovery guarantee and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been
recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. The total fixed consideration related to unsatisfied performance obligations is not material to Cleco’s revenues.
Note 6 - Regulatory Assets and Liabilities
Cleco Power recognizes an asset for certain costs capitalized or deferred for recovery from customers and recognizes a liability for amounts expected to be returned to customers or collected for future expected costs. Cleco Power records these assets and liabilities based on regulatory approval and management’s ongoing assessment that it is probable these
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CLECO POWER 2024 FORM 10-K
items will be recovered or refunded through the ratemaking process.
Under the current regulatory environment, Cleco Power estimates these regulatory assets are probable of full recovery. If in the future, as a result of regulatory changes or competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable,
Cleco Power would be required to write-down such assets. In addition, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power, could require discontinuance of the application of the authoritative guidance of regulated operations.
The following table summarizes Cleco Power’s regulatory assets and liabilities:
Cleco Power
AT DEC. 31, REMAINING
RECOVERY PERIOD (YRS.)
(THOUSANDS) 2024 2023
Regulatory assets
Acadia Unit 1 acquisition costs $ 1,596 $ 1,701 15
Accumulated deferred fuel (1)
457 11,627 Various (7)
Affordability study 8,959 10,337 6.5
AFUDC equity gross-up 57,284 60,381 Various (2)
AMI deferred revenue requirement
409 954 1.25
AROs (6)
11,073 20,094
Coughlin transaction costs 753 784 24.5
COVID-19 executive order
3,372 3,039 2.5
Deferred lignite and mine closure costs (6)
136,778 136,076
Deferred storm restoration costs
- 462
Deferred taxes, net
2,008 43,866 Various (7)
Dolet Hills carrying charge(6)
4,729 -
Dolet Hills Power Station closure costs (6)
122,173 147,323
Financing costs (1)
5,717 6,087 Various (3)
Interest costs 2,712 2,961 Various (2)
Madison Unit 3 property taxes 14,196 13,297 Various (8)
Non-service cost of postretirement benefits
14,057 14,526 Various (2)
Postretirement costs 58,089 64,399 Various (4)
Production operations and maintenance expenses
4,939 7,002 Various (5)
Rodemacher Unit 2 deferred costs (6)
27,265 19,282
Solar development costs (6)
2,122 -
St. Mary Clean Energy Center 870 3,705 0.5
Training costs 5,462 5,618 35
Tree trimming costs 943 3,657 0.25
Other 12,920 10,483 Various (7)
Total regulatory assets 498,883 587,661
Regulatory liabilities
Deferred taxes, net (6,827) (21,939) Various (7)
Residential revenue decoupling (9)
(3,000) -
Storm reserves (76,178) (111,509)
Total regulatory liabilities (86,005) (133,448)
Total regulatory assets, net $ 412,878 $ 454,213
(1) Represents regulatory assets for past expenditures that were not earning a return on investment at December 31, 2024, and 2023, respectively. All other assets are earning a return on investment.
(2) Amortized over the estimated lives of the respective assets.
(3) Amortized over the terms of the related debt issuances.
(4) Amortized over the average service life of the remaining plan participants.
(5) Deferral is recovered over the following three-year regulatory period.
(6) Currently not in a recovery period.
(7) For more information on the remaining recovery period, refer to the following disclosures for each specific regulatory asset or liability.
(8) Beginning July 1, 2021, property taxes paid for the year ended December 31, are being amortized over the subsequent 12 months beginning July 1.
(9) Currently not in a refund period.
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The following table summarizes Cleco’s net regulatory assets and liabilities:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Total Cleco Power regulatory assets, net
$ 412,878 $ 454,213
2016 Merger adjustments (1)
Fair value of long-term debt 89,941 97,345
Postretirement costs 7,461 9,448
Financing costs 6,217 6,560
Debt issuance costs 3,921 4,254
Total Cleco regulatory assets, net $ 520,418 $ 571,820
(1) Cleco regulatory assets include acquisition accounting adjustments as a result of the 2016 Merger.
Acadia Unit 1 Acquisition Costs
In 2009, the LPSC approved Cleco Power’s request to establish a regulatory asset for costs incurred as a result of the acquisition by Cleco Power of Acadia Unit 1 and half of Acadia Power Station’s related common facilities. In 2010, Cleco Power began recovering the Acadia Unit 1 acquisition costs over a 30-year period.
Accumulated Deferred Fuel
Cleco Power is allowed to recover the cost of fuel used for electric generation and power purchased for utility customers through the LPSC-established FAC or related wholesale contract provisions, which enable Cleco Power to pass on to its customers substantially all such charges. The difference between fuel and purchased power revenues collected from retail and wholesale customers and the current fuel and purchased power costs is generally recorded as Accumulated deferred fuel on Cleco Power’s Consolidated Balance Sheet. At December 31, 2024, Accumulated deferred fuel decreased $11.2 million, primarily due to lower mark-to-market losses on gas-related derivative contracts and the expiration of a significant wholesale customer contract, partially offset by the timing of fuel revenue collections. For 2024, approximately 89% of Cleco Power’s total fuel cost was regulated by the LPSC.
Affordability Study
In July 2021, as approved by the LPSC in Cleco Power’s prior retail rate plan, Cleco Power was allowed to establish a regulatory asset related to outside consulting fees for the assessment of Cleco Power’s practices and assistance in the identification of potential cost savings opportunities, while maintaining superior levels of employee safety, reliability, customer service, environmental stewardship, community involvement, and regulatory transparency. In 2021, the regulatory asset began being amortized over 10 years.
AFUDC Equity Gross-Up
Cleco Power capitalizes equity AFUDC as a cost component of construction projects. Cleco Power has recorded a regulatory asset to recover the tax gross-up related to the equity component of AFUDC. These costs are being amortized over the estimated lives of the respective assets constructed.
AMI Deferred Revenue Requirement
In 2011, the LPSC approved Cleco Power’s stipulated settlement in Docket No. U-31393 allowing Cleco Power to
defer the estimated revenue requirements for the AMI project as a regulatory asset. In 2014, the LPSC approved Cleco Power’s recovery of the AMI regulatory asset over the average life of the AMI meters, or 11 years, and Cleco Power began recovering the AMI deferred revenue requirement.
AROs
Cleco Power recorded an ARO liability for the retirement of certain ash disposal facilities. The ARO regulatory asset represents the accretion of the ARO liability and the depreciation of the related assets. For more information on the ARO regulatory asset that was reclassified to the Dolet Hills Power Station Closure Costs regulatory asset, see “- Deferred Lignite and Mine Closure Costs and Dolet Hills Power Station Closure Costs.”
Coughlin Transaction Costs
In January 2014, the LPSC authorized Cleco Power to create a regulatory asset for the transaction costs related to the transfer of Coughlin from Evangeline to Cleco Power. In 2014, Cleco Power began recovering the Coughlin transaction costs over a 35-year period.
COVID-19 Executive Order
In March 2020, the LPSC issued an executive order prohibiting the disconnection of utilities for nonpayment. This order resulted in an increase of expenses and a loss of revenue for Cleco Power. In April 2020, the LPSC issued an order allowing utilities to establish a regulatory asset for expenses incurred from the suspension of disconnections and collection of late fees imposed by the LPSC executive order. On July 1, 2020, the LPSC issued an order terminating the moratorium on disconnections effective July 16, 2020. Cleco began resuming disconnections and late fees and utilizing collection agencies in October 2020. As approved by the LPSC in Cleco Power’s current retail rate plan, beginning on July 1, 2024, the lost revenues and incremental costs associated with the COVID-19 executive order are being amortized over three years.
Deferred Lignite and Mine Closure Costs and Dolet Hills Power Station Closure Costs
In 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine and to include and defer certain accelerated mine closing costs in fuel and related ratemaking treatment. In 2021, the LPSC approved the establishment of a regulatory asset for certain lignite costs that would otherwise be billed through Cleco Power’s FAC and any reasonable incremental third-party professional costs related to the closure of the mine.
In 2020, Cleco Power revised depreciation rates for the Dolet Hills Power Station to utilize the December 31, 2021, expected end-of-life and early retirement of the Dolet Hills Power Station and defer depreciation expense to a regulatory asset for the amount in excess of the previously approved depreciation rates by the LPSC. The Dolet Hills Power Station was retired on December 31, 2021.
In 2022, Cleco Power filed an application with the LPSC requesting approval of the regulatory treatment and recovery of stranded and decommissioning costs associated with the retirement of the Dolet Hills Power Station over 20 years as well as recovery of deferred fuel and mine-related costs. On April 19, 2024, the LPSC approved an uncontested settlement that contains a provision for a $40.0 million reduction in the regulatory asset associated with the Dolet Hills Power Station.
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This amount was recorded as a reduction to the associated regulatory asset on Cleco’s and Cleco Power’s Consolidated Balance Sheets and an increase to Depreciation and amortization on Cleco’s and Cleco Power’s Statements of Income. At June 30, 2024, $12.3 million of the ARO regulatory asset, which is related to the Dolet Hills Power Station, was reclassified to the Dolet Hills Power Station Closure Costs regulatory asset. This amount was included in the related securitization application filed with the LPSC on May 17, 2024. Management anticipates the securitization of these costs to close by the end of March 2025, and as a result, reclassified these costs as current Regulatory assets on Cleco’s and Cleco Power’s Consolidated Balance Sheets.
For more information about the settlement, see Note 16 - “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
Deferred Storm Restoration Costs
In 2020 and 2021, Cleco Power’s distribution and transmission systems sustained substantial damage from four separate hurricanes, Hurricanes Laura, Delta, Zeta, and Ida, and two severe winter storms, Winter Storms Uri and Viola. Cleco Power established a separate regulatory asset to track and defer non-capital expenses associated with each corresponding storm, as approved by the LPSC.
On June 22, 2022, through Cleco Securitization I, Cleco Power completed a securitized financing of Storm Recovery Property, which included the previously mentioned storm restoration costs that were deferred as regulatory assets. In connection with that securitization financing, Cleco Securitization I used the net proceeds from its issuance of storm recovery bonds to purchase the Storm Recovery Property from Cleco Power. Prior to September 1, 2022, certain costs for Hurricanes Laura, Delta, and Zeta were recovered through the interim storm recovery rate. On September 30, 2023, the LPSC approved a settlement allowing Cleco Power to withdraw the remaining unrecovered Hurricane Ida storm restoration costs, plus a carrying charge through September 2023, totaling $10.3 million from the Hurricane Ida storm reserve. On November 1, 2024, Cleco Power received approval from the LPSC to withdraw the remaining $0.4 million of under-collected costs recorded for Hurricanes Laura, Delta, and Zeta from the storm reserve.
Dolet Hills Carrying Charge
On November 20, 2024, the LPSC authorized Cleco Power to establish an additional regulatory asset to accrue a carrying charge at Cleco Power’s weighted average cost of capital on the total of the related Dolet Hills Power Station regulatory assets that will be included in the principal balance of the securitization financing, which is expected to close by the end of March 2025. The amount will be recovered over one year beginning on July 1, 2025, through Cleco Power’s incremental cost recovery rider.
Financing Costs
In 2011, Cleco Power entered into and settled two treasury rate locks. Of the $26.8 million in settlements, $7.4 million was deferred as a regulatory asset relating to ineffectiveness of the hedge relationships. Also in 2011, Cleco Power entered into a forward starting swap contract. These derivatives were entered into in order to mitigate the interest rate exposure on coupon payments related to forecasted debt issuances. In 2013, the
forward starting interest rate swap was settled at a loss of $3.3 million. Cleco Power deferred $2.9 million of the losses as a regulatory asset, which is being amortized over the terms of the related debt issuances.
Interest Costs
Cleco Power’s deferred interest costs include additional deferred capital construction financing costs authorized by the LPSC. These costs are being amortized over the estimated lives of the respective assets.
Madison Unit 3 Property Taxes
Beginning in July 2021, as approved by the LPSC in Cleco Power’s prior retail rate plan, Cleco Power is allowed to recover property taxes paid for Madison Unit 3, including a carrying charge at Cleco Power’s weighted average cost of capital, grossed up for income taxes. The amount included in the cost recovery mechanism each year will amortize over 12 months.
Non-Service Cost of Postretirement Benefits
In 2018, FASB’s amended guidance related to defined benefit pension and other postretirement plans became effective. The amendment allows only the service cost component of net benefit cost to be eligible for capitalization within property, plant, and equipment. Beginning in 2018, Cleco Power’s non-service cost previously eligible for capitalization into property, plant, and equipment are being deferred to a regulatory asset and will be amortized over the estimated lives of the respective assets.
Postretirement Costs
Cleco Power recognizes the funded status of its postretirement benefit plans as a net liability or asset. The net liability or asset is defined as the difference between the benefit obligation and the fair market value of plan assets. For defined benefit pension plans, the benefit obligation is the projected benefit obligation. Historically, the LPSC has allowed Cleco Power to recover pension plan expense. Cleco Power, therefore, recognizes a regulatory asset based on its determination that these costs can be collected from customers. These costs are amortized to pension expense over the average service life of the remaining plan participants (approximately six years as of December 31, 2024, for Cleco’s plan) when it exceeds certain thresholds. The amount and timing of the recovery will be based on the changing funded status of the pension plan in future periods. For more information on Cleco’s pension plan and adoption of these authoritative guidelines, see Note 11 - “Pension Plan and Employee Benefits.”
Production Operations and Maintenance Expenses
Annually, Cleco Power is allowed to defer, as a regulatory asset, production operations and maintenance expenses, net of fuel and payroll, above the retail jurisdictional portion of $29.7 million, adjusted annually for a growth factor (deferral threshold). The amount of the regulatory asset is capped at $25.0 million. The LPSC allows Cleco Power to recover the amount deferred in any calendar year over the following three-year regulatory period, beginning on July 1, when the annual rates are set. Cleco Power deferred $2.0 million in 2024 and had no deferral in 2023.
Rodemacher Unit 2 Deferred Costs
As a result of environmental regulations enacted during 2020, Cleco Power revised Rodemacher Unit 2’s expected end-of-life
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CLECO POWER 2024 FORM 10-K
to coincide with its application to the EPA for an alternative closure date of October 17, 2028. Rodemacher Unit 2’s depreciation expense in excess of the previously LPSC-approved depreciation rates are deferred to a regulatory asset.
Solar Development Costs
In July 2022, Cleco Power entered into a long-term agreement to purchase, among other things, the output, capacity, and current and future environmental resource credits of a 240-MW solar electric generation facility to be constructed in DeSoto Parish, Louisiana and owned by a third party. On September 17, 2024, the LPSC approved the agreement and authorized Cleco Power to establish a regulatory asset for the stipulated settlement of development costs incurred through December 31, 2023, associated with the long-term agreement. As approved by the LPSC, Cleco Power will begin amortizing these costs over 25 years once it begins purchasing power from the third party, which is expected by January 2027.
St. Mary Clean Energy Center
Cleco Power has a regulatory asset for the revenue requirements related to the planning and construction costs incurred for the St. Mary Clean Energy Center. As approved by the LPSC in Cleco Power’s prior retail rate plan, the regulatory asset began being amortized over four years on July 1, 2021.
In September 2022, the LPSC approved a settlement refunding $10.4 million to Cleco Power’s retail customers, which was refunded to customers in October 2022. The $10.4 million refund consisted of $6.6 million for costs recovered in periods prior to September 30, 2022, and $3.8 million for costs recovered from October 1, 2022, until Cleco Power’s base rates were reset with its new retail rate plan on July 1, 2024.
Training Costs
In 2008, the LPSC approved Cleco Power’s request to establish a regulatory asset for training costs associated with existing processes and technology for new employees at Madison Unit 3. Recovery of these expenditures was approved by the LPSC in 2009. In 2010, Cleco Power began amortizing the regulatory asset over a 50-year period.
Tree Trimming Costs
In 2016, the LPSC approved Cleco Power to defer and recover through its base rates tree trimming costs. The LPSC authorized a deferral up to $11.0 million, excluding debt carrying costs. Cleco Power is currently collecting deferred tree trimming costs through its base rates and expects them to be fully amortized by the second quarter of 2025.
Cleco Holdings’ 2016 Merger Adjustments
As a result of the 2016 Merger, Cleco implemented acquisition accounting, which eliminated AOCI at the Cleco consolidated level on the date of the 2016 Merger. Cleco will continue to recover expenses related to certain postretirement costs; therefore, Cleco recognized a regulatory asset based on its determination that these costs that are probable of recovery continue to be collected from customers. These costs will be amortized to Other operations expense over the average remaining service period of participating employees. Cleco will also continue to recover financing costs associated with the settlement of two treasury rate locks and a forward starting swap contract that were previously recognized in AOCI. Additionally, as a result of the 2016 Merger, a regulatory asset
was recorded for debt issuance costs that were eliminated at Cleco, and a regulatory asset was recorded for the difference between the carrying value and the fair value of long-term debt. These regulatory assets are being amortized over the terms of the related debt issuances, unless the debt is redeemed prior to maturity, at which time any unamortized related regulatory asset will be derecognized.
Other
Annually, as approved in Cleco Power’s prior retail rate plan, Cleco Power is allowed to defer, as a regulatory asset, the undercollection of revenues related to the Northlake Transmission Agreement. The amount recorded in the regulatory asset will be amortized over the following regulatory period, beginning on July 1. At December 31, 2024, and 2023, Cleco Power had a regulatory asset of $2.5 million and $1.0 million, respectively, relating to the Northlake Transmission Agreement.
In addition, the LPSC approved recovery of other previously deferred costs associated with Cleco Power’s current and prior retail rate plan, which began being amortized over three years on July 1, 2024. At December 31, 2024, and 2023, Cleco Power had a regulatory asset of $4.5 million and $2.9 million, respectively, recorded for these deferred costs.
In June 2017, the LPSC approved the establishment of a regulatory asset upon the completion of the Coughlin Pipeline project for the revenue requirement associated with the project, until Cleco Power’s prior retail rate plan was approved. As approved by the LPSC in Cleco Power’s prior rate case, the regulatory asset began being amortized over four years on July 1, 2021. At December 31, 2024, and 2023, Cleco Power had a regulatory asset of $0.7 million and $2.0 million, respectively, recorded for the deferred revenue associated with the Coughlin Pipeline project.
In 2021, the Louisiana state corporate income tax rate decreased from 8% to 7.5% and the state deduction for federal income taxes paid was eliminated, effective for income tax periods beginning on or after January 1, 2022. These changes resulted in an increase in income tax expense. Therefore, Cleco Power established a regulatory asset for the increased revenue requirements associated with the income tax expense in excess of the amount previously approved by the LPSC. At December 31, 2023, Cleco Power had a balance of $4.5 million related to this regulatory asset. At June 30, 2024, as approved by the LPSC in Cleco Power's current rate case, $5.5 million for the total costs recorded for the associated regulatory asset were netted with the excess ADIT liability recorded in the Deferred taxes, net regulatory asset. For more information on the excess ADIT liability, see “- Deferred Taxes, Net.”
Cleco Power recovers increases in property taxes through its base rates. Additionally, as approved by the LPSC in Cleco Power’s current retail rate plan, increases in property taxes that are related to the industrial tax exemption program roll-offs will be recovered through the incremental costs recovery rider. At December 31, 2024, Cleco Power had a regulatory asset of $0.6 million for these costs.
On July 1, 2024, as approved by the LPSC in Cleco Power’s current retail rate plan, Cleco Power established a regulatory asset for right-of-way vegetation management costs to mitigate potential disruptions to its transmission and distribution system. At December 31, 2024, Cleco Power had $4.6 million recorded for these costs.
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Deferred Taxes, Net
The regulatory assets and liabilities recorded for deferred income taxes represent the effect of tax benefits or detriments that must be flowed through to customers as they are received or paid. The amounts deferred are attributable to differences between book and tax recovery periods. Tax effects of changes in tax laws must be recognized in the period in which the law is enacted. Also, deferred tax assets and liabilities must be measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled.
In 2017, the TCJA was enacted. Changes in the IRC from the TCJA had a material impact on the Registrants’ financial statements in 2017. At December 31, 2024, and 2023, Cleco and Cleco Power had $189.6 million and $211.5 million, respectively, accrued for the excess ADIT as a result of the TCJA. For more information on the status of the TCJA regulatory liability, see Note 14 - “Regulation and Rates - TCJA.”
On December 4, 2024, the Louisiana state corporate income tax rate decreased from 7.5% to 5.5%, effective for the income tax periods beginning on or after January 1, 2025.
At December 31, 2024, Cleco and Cleco Power recorded a $64.9 million decrease in Regulatory assets - deferred taxes, net for the flowthrough effects of state income taxes. For more information, see Note 12 - “Income Taxes - Tax Rate Changes.”
Residential Revenue Decoupling
Under the terms of Cleco Power’s new retail rate plan, effective July 1, 2024, Cleco Power implemented a residential revenue decoupling mechanism through its infrastructure and incremental cost recovery rider that provides a charge or credit to its residential customers for any under or over collection of residential base revenue as a result of changes in usage driven by weather or other measures. The under or over collection of residential base revenue is assessed on Cleco
Power’s rate year and an associated credit or charge for decoupling, not to exceed $3.0 million, will be adjusted through the infrastructure and incremental cost recovery rider for July 2025 and 2026, respectively.
Storm Reserves
Cleco Power has a storm reserve to fund future storm restoration costs. Accumulated storm restoration costs that are probable of recovery from retail customers are netted against the storm reserve. At December 31, 2023, Cleco Power had a storm reserve balance of $111.5 million, net of $2.5 million of accumulated restoration costs. During 2024, Cleco Power’s service territory was impacted by multiple severe weather events resulting in significant storm restoration costs. At December 31, 2024, Cleco Power had a storm reserve balance of $76.2 million, net of $43.3 million of accumulated storm restoration costs. For more information on the storm restoration costs associated with severe weather events that impacted Cleco Power’s service territory, see Note 20 - “Storm Restoration.”
Note 7 - Jointly Owned Generation Units
Cleco Power operates electric generation units that are jointly owned with other utilities. The joint-owners are responsible for their own share of the capital and the operating and maintenance costs of the respective units. Cleco Power is responsible for its own share of the direct expenses of its jointly owned generation units. Cleco Power’s share of expenses is included in the operating expenses on Cleco’s and Cleco Power’s Consolidated Statements of Income.
At December 31, 2024, the investment in and accumulated depreciation for each generating facility on Cleco’s and Cleco Power’s Consolidated Balance Sheets were as follows:
Cleco
AT DEC. 31, 2024
(THOUSANDS, EXCEPT PERCENTAGES AND MW) UTILITY PLANT
IN SERVICE (2)
ACCUMULATED DEPRECIATION (2)
CONSTRUCTION WORK IN PROGRESS OWNERSHIP INTEREST PERCENTAGE RATED
CAPACITY (MW) OWNERSHIP INTEREST (MW)
Acadia Power Station common facilities (1)
$ 18,854 $ 3,897 $ 258 50 %
Brame Energy Center
Rodemacher Unit 2
$ 88,116 $ 50,930 $ 324 30 % 523 157
Common facilities - Nesbitt Unit 1 and Rodemacher Unit 2
$ 3,367 $ 795 $ 20 62 %
Common facilities - Rodemacher Unit 2 and Madison Unit 3
$ 2,988 $ 467 $ 29 69 %
Common facilities - Nesbitt Unit 1, Rodemacher Unit 2, and Madison Unit 3
$ 11,289 $ 2,417 $ 232 77 %
(1) Cleco Power has a 100% ownership interest in Acadia Unit 1. The common facilities at the Acadia Power Station are jointly owned.
(2) At the date of the 2016 Merger, utility plant in service was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on such date. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation.
Cleco Power
AT DEC. 31, 2024
(THOUSANDS, EXCEPT PERCENTAGES AND MW) UTILITY PLANT
IN SERVICE ACCUMULATED DEPRECIATION CONSTRUCTION WORK IN PROGRESS OWNERSHIP INTEREST PERCENTAGE RATED
CAPACITY (MW) OWNERSHIP INTEREST (MW)
Acadia Power Station common facilities (1)
$ 19,628 $ 4,672 $ 258 50 %
Brame Energy Center
Rodemacher Unit 2 $ 161,696 $ 124,510 $ 324 30 % 523 157
Common facilities - Nesbitt Unit 1 and Rodemacher Unit 2 $ 4,774 $ 2,203 $ 20 62 %
Common facilities - Rodemacher Unit 2 and Madison Unit 3 $ 3,078 $ 557 $ 29 69 %
Common facilities - Nesbitt Unit 1, Rodemacher Unit 2, and Madison Unit 3 $ 21,333 $ 12,461 $ 232 77 %
(1) Cleco Power has a 100% ownership interest in Acadia Unit 1. The common facilities at the Acadia Power Station are jointly owned.
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Note 8 - Fair Value Accounting Instruments
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.
Cleco utilizes a three-tier fair value hierarchy that prioritizes inputs that may be used to measure fair value. The fair value hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Significant increases or decreases in any of those inputs in isolation could result in a significantly different fair value measurement. Cleco classifies fair value balances based on the fair value hierarchy defined as follows:
•Level 1 - observable inputs that reflect unadjusted quoted prices in active markets for identical assets or liabilities that Cleco can observe as of the measurement date.
•Level 2 - observable inputs other than Level 1 prices, such as quoted prices for similar assets or liabilities in active markets, quoted market prices in markets that are not active, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities.
•Level 3 - unobservable inputs for assets or liabilities whose fair value is estimated based on internally or third-party developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.
When available, Cleco uses observable market prices to measure fair value. Credit risk of Cleco and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves. Cleco applies the provisions of the fair value measurement standard to its non-recurring, non-financial measurements including business combinations as well as impairment related to goodwill and other long-lived assets.
Fair Value Measurements on a Recurring Basis
The amounts reflected in Cleco’s and Cleco Power’s Consolidated Balance Sheets at December 31, 2024, and 2023, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, short-term debt, and accounts payable approximate fair value because of their short-term nature.
The following tables disclose the fair value of financial assets and liabilities measured on a recurring basis on Cleco’s and Cleco Power’s Consolidated Balance Sheets. These amounts are presented on a gross basis.
Cleco
FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS) AT DEC. 31, 2024 QUOTED
PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3) AT DEC. 31, 2023 QUOTED
PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
Asset Description
Short-term investments $ 153,972 $ 153,972 $ - $ - $ 242,596 $ 242,596 $ - $ -
FTRs
2,084 - - 2,084 3,087 - - 3,087
Natural gas derivatives 9,210 - 9,210 - 5,042 - 5,042 -
Total assets $ 165,266 $ 153,972 $ 9,210 $ 2,084 $ 250,725 $ 242,596 $ 5,042 $ 3,087
Liability Description
FTRs $ 256 $ - $ - $ 256 $ 781 $ - $ - $ 781
Natural gas derivatives - - - - 15,005 - 15,005 -
Total liabilities $ 256 $ - $ - $ 256 $ 15,786 $ - $ 15,005 $ 781
CLECO
CLECO POWER 2024 FORM 10-K
Cleco Power
FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS) AT DEC. 31, 2024 QUOTED
PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3) AT DEC. 31, 2023 QUOTED
PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
Asset Description
Short-term investments $ 147,648 $ 147,648 $ - $ - $ 169,606 $ 169,606 $ - $ -
FTRs 2,084 - - 2,084 3,087 - - 3,087
Natural gas derivatives 9,210 - 9,210 - - - - -
Total assets $ 158,942 $ 147,648 $ 9,210 $ 2,084 $ 172,693 $ 169,606 $ - $ 3,087
Liability Description
FTRs $ 256 $ - $ - $ 256 $ 781 $ - $ - $ 781
Natural gas derivatives - - - - 14,331 - 14,331 -
Total liabilities $ 256 $ - $ - $ 256 $ 15,112 $ - $ 14,331 $ 781
Cleco has applied the Level 2 and Level 3 fair value techniques between comparative fiscal periods. During the years ended December 31, 2024, and 2023, Cleco did not experience any transfers into or out of Level 3 of the fair value hierarchy.
Short-term Investments
At December 31, 2024, and 2023, Cleco and Cleco Power had short-term investments in money market funds and treasury bills that have a maturity of three months or less when purchased.
The following tables present the short-term investments as recorded on Cleco’s and Cleco Power’s Consolidated Balance Sheets at December 31, 2024, and 2023:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Cash and cash equivalents $ 21,562 $ 113,207
Current restricted cash and cash equivalents $ 15,918 $ 15,818
Non-current restricted cash and cash equivalents
$ 116,492 $ 113,571
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Cash and cash equivalents $ 15,263 $ 40,240
Current restricted cash and cash equivalents $ 15,918 $ 15,818
Non-current restricted cash and cash equivalents
$ 116,467 $ 113,548
FTRs
FTRs are energy-related financial instruments used to provide a financial hedge to manage the risk of transmission
congestion charges between MISO nodes in MISO’s Day-Ahead Energy Market. Cleco is awarded and/or purchases FTRs in auctions facilitated by MISO. FTRs are derivatives not designated as hedging instruments for accounting purposes.
FTRs are valued using MISO’s monthly auction prices as a price index reference (Level 3). Unrealized gains or losses are deferred as a component of Accumulated deferred fuel on the balance sheet in accordance with regulatory policy, and at settlement, realized gains or losses are included in Cleco Power’s FAC and reflected on customers’ bills as a component of the fuel charge.
The following table summarizes the net changes in the net fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy for Cleco and Cleco Power:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Beginning balance
$ 2,306 $ 2,276 $ 4,918
Unrealized gains (losses)*
204 (425) (495)
Purchases 4,240 8,089 7,270
Settlements (4,922) (7,634) (9,417)
Ending balance
$ 1,828 $ 2,306 $ 2,276
* Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s and Cleco Power's Consolidated Balance Sheets.
The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions for Cleco and Cleco Power as of December 31, 2024, and 2023:
FAIR VALUE
VALUATION TECHNIQUE SIGNIFICANT
UNOBSERVABLE INPUTS INPUT/RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE) ASSETS LIABILITIES LOW(1)
HIGH(1)
WEIGHTED
AVERAGE(2)
FTRs at Dec. 31, 2024
$ 2,084 $ 256 RTO auction pricing FTR price - per MWh $ (4.39) $ 8.49 $ 0.27
FTRs at Dec. 31, 2023
$ 3,087 $ 781 RTO auction pricing FTR price - per MWh $ (3.51) $ 7.07 $ 0.24
(1) The low and high prices reflect the lowest and highest values of all single point-to-point FTRs and not the range of aggregate price changes.
(2) The weighted average reflects the market price and volume of each commodity weighted by the total volume of commodities.
Natural Gas Derivatives
Cleco may enter into energy-related physical and financial fixed price forward or options contracts that financially settle or
are physically delivered at a future date. Management has not elected to apply hedge accounting to these contracts as allowed under applicable accounting standards. Cleco
CLECO
CLECO POWER 2024 FORM 10-K
Power’s natural gas derivative contracts are marked-to-market with the resulting unrealized gain or loss recorded as a component of Accumulated deferred fuel on the balance sheet. At settlement, realized gains or losses are included in Cleco Power’s FAC and reflected on customer’s bills as a component of the fuel charge. Prior to the closing of the Cleco Cajun Divestiture, Cleco Cajun’s unrealized gains or losses as well as realized gains or losses at settlement were recorded on the income statements as a component of fuel expense. After the closing of the Cleco Cajun Divestiture in June 2024, all of Cleco Cajun’s natural gas derivative contracts were liquidated. Upon liquidation, a $6.4 million gain was recorded in Cleco’s Consolidated Statements of Income as a component of fuel expense.
Fair Value Measurements on a Nonrecurring Basis
The following tables summarize the carrying value and estimated market value of Cleco’s and Cleco Power’s financial instruments not measured at fair value on Cleco’s and Cleco Power’s Consolidated Balance Sheets:
Cleco
AT DEC. 31,
2024 2023
(THOUSANDS) CARRYING
VALUE* FAIR VALUE CARRYING
VALUE* FAIR VALUE
Long-term debt $ 2,922,003 $ 2,716,251 $ 3,400,293 $ 3,177,654
* The carrying value of long-term debt does not include deferred issuance costs of $11.6 million at December 31, 2024, and $14.2 million at December 31, 2023.
Cleco Power
AT DEC. 31,
2024 2023
(THOUSANDS) CARRYING
VALUE* FAIR VALUE CARRYING
VALUE* FAIR VALUE
Long-term debt $ 1,822,061 $ 1,800,633 $ 1,886,248 $ 1,867,559
* The carrying value of long-term debt does not include deferred issuance costs of $10.1 million at December 31, 2024, and $11.5 million at December 31, 2023.
In order to fund capital requirements, Cleco may issue fixed and variable rate long-term debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed and variable rate debt with similar tenors and credit ratings change. The fair value of the debt could also change from period to period due to changes in the credit rating of the Cleco entity by which the debt was issued. The fair value of long-term debt is classified as Level 2 in the fair value hierarchy.
Concentrations of Credit Risk
Cleco is exposed to counterparty credit risk when a counterparty fails to meet their financial obligations causing Cleco to potentially incur replacement cost losses.
At December 31, 2024, and 2023, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash equivalents. If the short-term investments failed to perform under the terms of the investments, Cleco and Cleco Power would be exposed to a loss of the invested amounts. Collateral on these types of investments is not required. In order to optimize interest income and minimize risk, cash is invested primarily in short-term securities issued by the U.S. government and money market mutual funds to
maintain liquidity and achieve the goal of maintaining the net asset value of a dollar.
When Cleco enters into commodity derivative or physical commodity transactions directly with market participants, Cleco may be exposed to counterparty credit risk. Cleco enters into long-form contract and master agreements with counterparties that govern the risk of counterparty credit default and allow for collateralization above prenegotiated thresholds to help mitigate potential losses. Alternatively, Cleco may be required to provide credit support with respect to bilateral transactions and contracts that Cleco has entered into or may enter into in the future. The amount of credit support required may change based on margining formulas, changes in credit agency ratings, or liquidity ratios.
Note 9 - Derivative Instruments
In the normal course of business, Cleco utilizes derivative instruments, such as natural gas derivatives and FTRs, to mitigate volatility of overall fuel and purchased power costs.
Cleco has not elected to designate any of its current instruments as an accounting hedge. Generally, Cleco’s derivative positions are subject to netting agreements that provide for offsetting of asset and liability positions as well as related collateral with the same counterparty. At December 31, 2024 and 2023, there were no fair value amounts offset on the balance sheets and no collateral posted with or received from counterparties. The following tables present the fair values of derivative instruments and their respective line items as
recorded on Cleco’s and Cleco Power’s Consolidated Balance Sheets at December 31, 2024, and 2023:
Cleco
DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS) BALANCE SHEET LINE ITEM AT DEC. 31, 2024 AT DEC. 31, 2023
Commodity-related contracts
FTRs
Current Energy risk management assets $ 2,084 $ 3,087
Current Energy risk management liabilities (256) (781)
Natural gas derivatives
Current Energy risk management assets 9,210 5,042
Current Energy risk management liabilities - (15,005)
Commodity-related contracts, net $ 11,038 $ (7,657)
Cleco Power
DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
AT DEC. 31,
(THOUSANDS) BALANCE SHEET LINE ITEM 2024 2023
Commodity-related contracts
FTRs
Current Energy risk management assets $ 2,084 $ 3,087
Current Energy risk management liabilities (256) (781)
Natural gas derivatives
Current Energy risk management assets 9,210 -
Current Energy risk management liabilities - (14,331)
Commodity-related contracts, net $ 11,038 $ (12,025)
CLECO
CLECO POWER 2024 FORM 10-K
The following table presents the effect of derivatives not designated as hedging instruments on Cleco’s and Cleco
Power’s Consolidated Statements of Income for the years December 31, 2024, 2023, and 2022:
Cleco
AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) DERIVATIVES LINE ITEM 2024 2023 2022
Commodity contracts
FTRs (1)
Electric operations $ 2,811 $ 6,320 $ 14,118
FTRs (1)
Purchased power (2,988) (4,465) (7,331)
Natural gas derivatives (2)(3)
Fuel used for electric generation (30,748) (139,315) 180,522
Total $ (30,925) $ (137,460) $ 187,309
(1) For the years ended December 31, 2024, 2023, and 2022, unrealized gains (losses) associated with FTRs of $0.2 million, $(0.4) million, and $(0.5) million, respectively, were reported through Accumulated deferred fuel on the balance sheet.
(2) For the years ended December 31, 2024, 2023, and 2022, unrealized gains (losses) associated with natural gas derivatives for Cleco Power of $14.6 million, $(9.8) million, and $4.9 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.
(3) For the year ended December 31, 2023, realized losses associated with natural gas derivatives for Cleco Power of $(2.0) million were reported through Accumulated deferred fuel on the balance sheet. For the years ended December 31, 2024, and 2022, Cleco Power had no realized gains (losses) associated with natural gas derivatives reported through Accumulated deferred fuel on the balance sheet.
Cleco Power
AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) DERIVATIVES LINE ITEM 2024 2023 2022
Commodity contracts
FTRs (1)
Electric operations $ 2,811 $ 6,320 $ 14,118
FTRs (1)
Purchased power (2,988) (4,465) (7,331)
Natural gas derivatives (2)(3)
Fuel used for electric generation (24,289) (22,734) -
Total $ (24,466) $ (20,879) $ 6,787
((1) For the years ended December 31, 2024, 2023, and 2022, unrealized gains (losses) associated with FTRs of $0.2 million, $(0.4) million, and $(0.5) million, respectively, were reported through Accumulated deferred fuel on the balance sheet.
(2) For the years ended December 31, 2024, 2023, and 2022, unrealized gains (losses) associated with natural gas derivatives for Cleco Power of $14.6 million, $(9.8) million, and $4.9 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.
(3) For the year ended December 31, 2023, realized losses associated with natural gas derivatives for Cleco Power of $(2.0) million were reported through Accumulated deferred fuel on the balance sheet. For the years ended December 31, 2024, and 2022, Cleco Power had no realized gains (losses) associated with natural gas derivatives reported through Accumulated deferred fuel on the balance sheet.
The following tables present the volume of commodity-related derivative contracts outstanding at December 31, 2024, and 2023 for Cleco and Cleco Power:
Cleco
TOTAL VOLUME OUTSTANDING
UNIT OF MEASURE AT DEC. 31,
(THOUSAND) 2024 2023
Commodity-related contracts
FTRs MWh 6,720 9,611
Natural gas derivatives MMBtus 18,595 61,119
Cleco Power
TOTAL VOLUME OUTSTANDING
UNIT OF MEASURE AT DEC. 31,
(THOUSAND) 2024 2023
Commodity-related contracts
FTRs MWh 6,720 9,611
Natural gas derivatives MMBtus 18,595 19,915
CLECO
CLECO POWER 2024 FORM 10-K
Note 10 - Debt
Cleco Power’s total long-term indebtedness as of December 31, 2024, and 2023 was as follows:
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Bonds
Senior notes, 3.17%, due 2024
$ - $ 50,000
Senior notes, 3.68%, due 2025
75,000 75,000
Senior notes, 3.47%, due 2026
130,000 130,000
Senior notes, 5.96%, due 2026
100,000 100,000
Senior notes, 4.33%, due 2027
50,000 50,000
Senior notes, 3.57%, due 2028
200,000 200,000
Senior notes, 6.50%, due 2035
295,000 295,000
Senior notes, 6.00%, due 2040
250,000 250,000
Senior notes, 5.12%, due 2041
100,000 100,000
Series A GO Zone bonds, 2.50%, due 2038, mandatory tender in 2025
50,000 50,000
Series B GO Zone bonds, 4.25%, due 2038
50,000 50,000
Cleco Securitization I storm recovery bonds, 4.016%, due 2033
100,927 115,426
Cleco Securitization I storm recovery bonds, 4.646%, due 2044
300,000 300,000
Total bonds 1,700,927 1,765,426
Bank term loan, variable rate, due 2025
125,000 125,000
Finance leases
Barge lease obligations (1)
- 12,971
Gross amount of long-term debt and finance leases
1,825,927 1,903,397
Long-term debt due within one year (264,934) (189,389)
Finance leases classified as long-term debt due within one year - (925)
Unamortized debt discount (3,866) (4,178)
Unamortized debt issuance costs (10,503) (11,753)
Total long-term debt and finance leases, net $ 1,546,624 $ 1,697,152
(1) For more information on Cleco Power’s barge lease obligations, see Note 4 - Leases - Finance Lease.”
Cleco’s total long-term indebtedness as of December 31, 2024, and 2023 was as follows:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Total Cleco Power long-term debt and finance leases, net
$ 1,546,624 $ 1,697,152
Cleco Holdings’ long-term debt, net
Senior notes, 3.250%, due 2025
- 165,000
Senior notes, 3.743%, due 2026
360,000 535,000
Senior notes, 3.375%, due 2029
300,000 300,000
Senior notes, 4.973%, due 2046
350,000 350,000
Bank term loan, variable rate, due 2024 - 66,700
Long-term debt due within one year - (66,497)
Unamortized debt issuance costs(1)
(1,523) (2,776)
Fair value adjustment 89,942 97,345
Total Cleco long-term debt and finance leases, net
$ 2,645,043 $ 3,141,924
(1) For December 31, 2024, and 2023, this amount includes unamortized debt issuance costs for Cleco Holdings of $5.4 million and $7.0 million, respectively, partially offset by deferred debt issuance costs eliminated as a result of the 2016 Merger of $3.9 million and $4.3 million, respectively. For more information, see Note 6 - “Regulatory Assets and Liabilities - Cleco Holdings’ 2016 Merger Adjustments.”
The principal amounts payable under long-term debt agreements for each year through 2029 and thereafter are as follows:
(THOUSANDS) CLECO POWER CLECO
For the year ending Dec. 31,
2025 (1)
$ 215,087 $ 215,087
2026 $ 245,699 $ 605,699
2027 $ 66,336 $ 66,336
2028 $ 216,999 $ 216,999
$ 17,688 $ 317,688
Thereafter $ 1,064,118 $ 1,414,118
(1) Does not include Series A GO Zone bonds that have a maturity date of December 2038 but a mandatory tender in May 2025.
Cleco Power
At December 31, 2024, and 2023, Cleco Power’s long-term debt and finance leases due within one year was $264.9 million and $190.3 million, respectively. The increase of $74.6 million is primarily due to $75.0 million senior notes due in November 2025, $50.0 million GO-Zone bonds with a mandatory tender in April 2025, partially offset by the repayment of $50.0 million senior notes in December 2024.
At December 31, 2024, Cleco Power had $110.0 million outstanding borrowings of borrowings outstanding under its $300.0 million revolving credit facility. The term loan under the term loan agreement bears interest at a rate of SOFR plus 1.35% or ABR plus 0.25%.
On May 17, 2024, Cleco Power entered into a $125.0 million bank term loan agreement. The term loan agreement replaced Cleco Power’s existing term loan agreement and matures on May 17, 2025.
On December 16, 2024, Cleco Power repaid its $50.0 million 3.17% senior notes that matured in December 2024.
Other than Cleco Securitization I storm recovery bonds, all of Cleco Power’s debt outstanding at December 31, 2024, and 2023 is unsecured and unsubordinated.
Cleco
At December 31, 2024, and 2023, Cleco’s long-term debt and finance leases due within one year was $264.9 million and $256.8 million, respectively. The increase of $8.1 million is primarily due to $75.0 million of Cleco Power’s senior notes due in November 2025, $50.0 million of Cleco Power’s GO-Zone bonds with a mandatory tender in April 2025; partially offset by the repayment of Cleco Holdings’ $66.7 million bank term loan, and the repayment of Cleco Power’s $50.0 million senior notes in December 2024.
On April 26, 2024, Cleco Holdings repaid its $66.7 million bank term loan that was due on May 21, 2024. On June 4, 2024, Cleco Holdings redeemed its $165.0 million floating rate senior notes due in May 2025.
On November 27, 2024, Cleco Holdings completed a voluntary tender offer for its 3.743% senior notes due in May 2026 in an aggregate principal amount of $175.0 million.
Other than Cleco Securitization I storm recovery bonds, all of Cleco’s debt outstanding at December 31, 2024, and 2023 is unsecured and unsubordinated.
Upon approval of the Cleco Cajun Acquisition, commitments were made to the LPSC by Cleco, including repayment of $400.0 million of Cleco Holdings’ debt by
CLECO
CLECO POWER 2024 FORM 10-K
December 31, 2024. As of December 31, 2024, Cleco Holdings had satisfied this commitment.
Credit Facilities
At December 31, 2024, Cleco had two separate revolving credit facilities, one for Cleco Holdings in the amount of $175.0 million with $10.0 million outstanding borrowings and one for Cleco Power in the amount of $300.0 million with $110.0 million outstanding borrowings. These revolving credit facilities were entered into on May 17, 2024, and replaced the existing agreements. The total of all revolving credit facilities maintains a maximum aggregate capacity of $475.0 million.
Cleco Holdings and Cleco Power each elected not to renew its individual $10.0 million uncommitted lines of credit that were used to support working capital needs. The individual uncommitted lines of credit allowed up to $10.0 million in short-term borrowings, but no more than $10.0 million in the aggregate. These lines of credit were previously being renewed on an annual basis; however, on September 20, 2024, these lines of credit expired.
Cleco Holdings’ revolving credit facility provides funding for working capital and other financing needs. The revolving credit facility includes restrictive financial covenants and matures in May 2029. Under covenants contained in Cleco Holdings’ revolving credit facility, Cleco is required to maintain total indebtedness, not including securitization indebtedness, less than or equal to 65% of total capitalization. At December 31, 2024, Cleco Holdings was in compliance with the covenants of its revolving credit facility. At December 31, 2024, the borrowing costs under Cleco Holdings’ revolving credit agreement were equal to SOFR plus 1.725% or ABR plus 0.625%, plus commitment fees of 0.275% on the unused portion of the facility. If Cleco Holdings’ credit ratings were to be downgraded one level by the credit rating agencies, Cleco Holdings may be required to pay incremental interest and commitment fees of 0.125% and 0.05%, respectively, under the pricing levels of its revolving credit facility.
Cleco Power’s revolving credit facility provides funding for working capital and other financing needs. The revolving credit facility includes restrictive financial covenants and matures in May 2029. Under covenants contained in Cleco Power’s revolving credit facility, Cleco Power is required to maintain total indebtedness less than or equal to 65% of total capitalization. At December 31, 2024, Cleco Power was in compliance with the covenants of its revolving credit facility. At December 31, 2024, the borrowing costs under Cleco Power’s revolving credit agreement were equal to SOFR plus 1.35% or ABR plus 0.25%, plus commitment fees of 0.15% on the unused portion of the facility. If Cleco Power’s credit ratings were to be downgraded one level by the credit rating agencies, Cleco Power may be required to pay incremental interest and commitment fees of 0.125% and 0.025%, respectively, under the pricing levels of its revolving credit facility.
If Cleco Holdings or Cleco Power were to not comply with certain covenants in their respective revolving credit facilities or other debt agreements, they would be unable to borrow additional funds under the facilities, and the lenders under the
respective credit facility or debt agreement could accelerate all principal and interest outstanding. Further, if Cleco Power were to default under its revolving credit facility or other debt agreements, Cleco Holdings would be considered in default under its revolving credit facility.
Note 11 - Pension Plan and Employee Benefits
Pension Plan and Other Benefits Plan
Employees hired before August 1, 2007, are covered by a non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last ten years of employment with Cleco. Cleco’s policy is to base its contributions to the employee pension plan upon actuarial computations utilizing the projected unit credit method, subject to the IRS’s full funding limitation. Required contributions are driven by liability funding target percentages set by law and could cause the required contributions to be uneven among the years. Based on the funding assumptions at December 31, 2024, management estimates that $76.1 million in pension contributions will be required through 2029, of which $16.5 million is required in 2025. In January 2025, Cleco made an $11.5 million required contribution payment towards the 2025 plan year. In April 2024, July 2024, and January 2025, Cleco made payments of $3.5 million, $7.1 million, and $5.0 million, respectively, toward its 2024 contribution requirement. In July 2024, Cleco also made a $15.2 million required contribution payment towards the 2023 plan year. Cleco was not required to make contributions to the pension plan in 2023 or 2022.
Future discretionary contributions may be made depending on changes in assumptions, the ability to utilize the contribution as a tax deduction, and requirements concerning recognizing a minimum pension liability. Adverse changes in assumptions or adverse actual events could cause additional minimum contributions. The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is the plan sponsor, and Support Group is the plan administrator.
In June 2024, an amendment to the pension plan was executed allowing the transfer of the cash balance and
pension liabilities to the Cleco Cajun Purchaser’s pension plan. This transfer was for the former Cleco Cajun employees that became employees of the Cleco Cajun Purchasers following the closing of the Cleco Cajun Divestiture. The transfer was completed in June 2024.
Cleco’s retirees may be eligible to receive Other Benefits. Dependents of Cleco’s retirees may also be eligible to receive Other Benefits with the exception of life insurance benefits. Cleco recognizes the expected cost of Other Benefits during the periods in which the benefits are earned.
The employee pension plan and Other Benefits plan obligation, plan assets, and funded status at December 31, 2024, and 2023 are presented in the following table:
CLECO
CLECO POWER 2024 FORM 10-K
PENSION BENEFITS OTHER BENEFITS
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2024 2023
Change in benefit obligation
Benefit obligation at beginning of period
$ 525,482 $ 500,869 $ 47,056 $ 43,306
Service cost
4,619 4,977 1,907 1,472
Interest cost
26,140 26,423 2,322 2,285
Actuarial loss (gain)
(25,647) 26,300 (2,011) (5,110)
Expenses paid
(3,396) (3,018) - -
Transfer to Cleco Cajun Purchasers
(1,674) - - -
Derecognition of Cleco Cajun liability - - (380) -
Benefits paid (30,660) (30,069) (4,891) (5,117)
Benefit obligation at end of period
494,864 525,482 44,003 47,056
Change in plan assets
Fair value of plan assets at beginning of period
408,159 402,285 - -
Actual (loss) gain return on plan assets 11,091 38,761 - -
Employer contributions
25,750 200 - -
Expenses paid
(3,396) (3,018) - -
Transfer to Cleco Cajun Purchasers
(1,674) - - -
Benefits paid (30,660) (30,069) - -
Fair value of plan assets at end of period
409,270 408,159 - -
Unfunded status $ (85,594) $ (117,323) $ (44,003) $ (47,056)
The current and non-current portions of the Pension Benefits liability for Cleco and Cleco Power at December 31, 2024, and 2023 are as follows:
AT DEC. 31,
(THOUSANDS) 2024
Current $ 16,344 $ 25,685
Non-current $ 69,250 $ 91,638
The employee pension plan accumulated benefit obligation at December 31, 2024, and 2023 is presented in the following table:
PENSION BENEFITS
AT DEC. 31,
(THOUSANDS) 2024 2023
Accumulated benefit obligation $ 479,948 $ 505,508
The following table presents the net actuarial gains/losses included in other comprehensive income for Other Benefits and in regulatory assets for pension related to current year gains and losses as a result of being included in net periodic benefit costs for the employee pension plan and Other Benefits plan for the years ended December 31, 2024, and 2023:
PENSION BENEFITS OTHER BENEFITS
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2024 2023
Net actuarial (gain) loss occurring during period
$ (6,310) $ 17,082 $ (1,964) $ 5,110
Net actuarial loss (gain) amortized during period
$ - $ - $ 653 $ (45)
The pension net actuarial gain was $6.3 million for the year ended December 31, 2024, primarily due to the increase in the discount rate, partially offset by the actual plan asset returns compared to the expected plan asset returns. The pension net actuarial loss was $17.1 million for the year ended December 31, 2023, primarily due to updated demographic assumptions resulting from the completion of an experience study in 2023 and a decrease in the discount rate. This loss was partially offset by higher than expected return on assets.
The Other Benefits net actuarial gain was $2.0 million for the year ended December 31, 2024, primarily due to updated demographic assumptions, the removal of Cleco Cajun participants, and the increase in the discount rate. The Other
Benefits net actuarial loss was $5.1 million for the year ended December 31, 2023, primarily due to updated demographic assumptions resulting from the completion of an experience study in 2023.
The following table presents net actuarial gains/losses in accumulated other comprehensive income that have not been recognized as components of net periodic benefit costs for the employee pension plan and Other Benefits plans at December 31, 2024, and 2023:
CLECO
CLECO POWER 2024 FORM 10-K
PENSION BENEFITS OTHER BENEFITS
AT DEC. 31, AT DEC. 31,
(THOUSANDS) 2024 2023 2024 2023
Net actuarial loss $ 58,089 $ 64,399 $ 9,685 $ 13,103
The non-service components of net periodic pension and Other Benefits cost are included in Other income (expense), net within Cleco’s and Cleco Power’s Consolidated Statements of Income. The components of net periodic pension and Other Benefits costs for 2024, 2023, and 2022 are as follows:
PENSION BENEFITS OTHER BENEFITS
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022 2024 2023 2022
Components of periodic benefit costs
Service cost $ 4,619 $ 4,977 $ 8,589 $ 1,907 $ 1,472 $ 2,204
Interest cost 26,140 26,423 19,841 2,322 2,285 1,484
Expected return on plan assets (30,428) (29,544) (24,706) - - -
Amortizations
Net loss (gain)
- - 12,332 646 (45) 1,210
Gain on derecognition of Cleco Cajun
- - - (169) - -
Net periodic benefit cost $ 331 $ 1,856 $ 16,056 $ 4,706 $ 3,712 $ 4,898
Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the years ended December 31, 2024, 2023, and 2022 was $1.8 million, $1.9 million, and $3.2 million, respectively.
Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to Other Benefits reflected in Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2024, 2023, and 2022 was $4.3 million, $3.5 million, and $4.4 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at December 31, 2024, and 2023 are as follows:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Current $ 5,279 $ 5,241
Non-current $ 38,724 $ 41,815
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Current $ 4,524 $ 4,479
Non-current $ 30,054 $ 32,289
The measurement date used to determine the pension and other postretirement benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows:
PENSION BENEFITS OTHER BENEFITS
AT DEC. 31, AT DEC. 31,
2024 2023 2024 2023
Weighted-average assumptions used to determine the benefit obligation
Discount rate 5.66 % 5.13 % 5.61 % 5.25 %
Rate of compensation increase
3.00 % 3.50 % N/A N/A
PENSION BENEFITS OTHER BENEFITS
FOR THE YEAR ENDED DEC. 31, FOR THE YEAR ENDED DEC. 31,
2024 2023 2022 2024 2023 2022
Weighted-average assumptions used to determine the net benefit cost
Discount rate 5.13 % 5.44 % 2.98 % 5.25 % 5.61 % 2.82 %
Expected return on plan assets
6.68 % 6.60 % 5.25 % N/A N/A N/A
Rate of compensation increase
3.50 % 2.76 % 2.73 % N/A N/A N/A
In order to calculate the discount rate to measure the liabilities, management uses a theoretical bond portfolio that matched expected benefit payments. The expected return on plan assets was determined by examining the risk profile of each target category as compared to the expected return on that risk, within the parameters determined by Cleco’s Retirement Committee. In assessing the risk as compared to return profile, historical returns as compared to risk were considered. The historical risk compared to returns was
adjusted for the expected future long-term relationship between risk and return. For the calculation of the 2025 periodic expense, Cleco increased the discount rate to 5.66% and increased the expected long-term return on plan assets to 7.07%. Cleco expects pension expense to decrease in 2025 by approximately $2.5 million primarily due to an increase in the expected return on plan assets.
Employee pension plan assets are invested in accordance with the Pension Plan’s Investment Policy Statement. At
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CLECO POWER 2024 FORM 10-K
December 31, 2024, allowable investments included U.S. Equity Portfolios, International Equity - Developed Markets Portfolios, Emerging Markets Equity Portfolios, Multi-Asset Credits, Treasury Separate Trading of Registered Interest and Principal of Securities (STRIPS), Fixed Income Portfolios - Long Credit and Intermediate Government Credit, and Real Estate Portfolios.
Real estate funds and the pooled separate accounts are stated at estimated market value based on appraisal reports prepared annually by independent real estate appraisers (members of the American Institute of Real Estate Appraisers). The estimated market value of recently acquired properties is assumed to approximate cost.
Fair Value Disclosures
Cleco classifies assets and liabilities measured at their fair value according to three different levels, depending on the inputs used in determining fair value. For more information on the fair value hierarchy, see Note 8 - “Fair Value Accounting Instruments.”
There have been no changes in the methodologies for determining fair value at December 31, 2024, and 2023. The following tables disclose the pension plan’s fair value of financial assets measured on a recurring basis:
(THOUSANDS) AT DEC. 31, 2024 QUOTED PRICES
IN ACTIVE
MARKETS FOR
IDENTICAL ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
Asset Description
Cash equivalents $ 5,818 $ - $ 5,818 $ -
Mutual funds
Domestic
121,954 121,954 - -
Corporate debt 76,712 - 76,712 -
Total $ 204,484 $ 121,954 $ 82,530 $ -
Investments measured at net asset value(1)
204,476
Interest accrual 310
Total net assets $ 409,270
(1) Investments measured at net asset value consist of Common/collective trust and real estate fund investments.
(THOUSANDS) AT DEC. 31, 2023 QUOTED PRICES
IN ACTIVE
MARKETS FOR
IDENTICAL ASSETS
(LEVEL 1) SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2) SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)(1)
Asset Description
Cash equivalents $ 22,250 $ - $ 22,250 $ -
Government securities
14,418 - 14,418 -
Mutual funds
Domestic
85,821 85,821 - -
International
42,083 42,083 - -
Corporate debt 94,677 - 94,677 -
Total $ 259,249 $ 127,904 $ 131,345 $ -
Investments measured at net asset value(2)
147,142
Interest accrual 1,768
Total net assets $ 408,159
(1) The classification of real estate funds previously presented as Level 3 assets of $35.0 million at December 31, 2023, have been revised to correct a disclosure error and are presented as investments for which net asset value is used as a practical expedient to approximate fair value in accordance with GAAP.
(2) Investments measured at net asset value consist of Common/collective trust and real estate fund investments.
Cleco utilizes a practical expedient, referred to as net asset value (NAV), to estimate fair value of certain pension investments, Common/collective trust funds and real estate investment funds. Common/collective trust fund investments consist of domestic and international index equities, valued based upon the aggregate market values of the underlying investment index equities. The value of the NAV of each fund or trust is determined as of the close of the national securities exchange on which such fund or trust is listed for trading at the last business day of the year. There are no imposed redemption restrictions and the pension plan does not have any contractual obligations to further invest in the trust. Real
estate fund investments are open-end real estate funds that invest in a portfolio of real properties that are broadly diversified by geography and property type. The real estate asset class is expected to produce returns from income and capital appreciation. Real estate also provides a hedge against inflation. The purpose of each fund is to invest in real estate and real estate related assets that generate a total return from current income and capital appreciation which exceeds the applicable fund’s index. Each fund’s NAV is made available to fund participants quarterly.
The market-related value of plan assets differs from the fair value of plan assets by the amount of deferred asset gains
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CLECO POWER 2024 FORM 10-K
or losses. Actual asset returns that differ from the expected return on plan assets are deferred and recognized in the market-related value of assets on a straight-line basis over a five-year period. For 2024, the return on plan assets was 1.90% compared to an expected long-term return of 6.68%. The 2023 return on pension plan assets was 9.23% compared to an expected long-term return of 6.60%. As of December 31, 2024, none of the pension plan participants’ future annual benefits are covered by insurance contracts.
Pension Plan Strategic Asset Allocation
In December 2023, Cleco’s Retirement Committee revised the pension plan’s asset allocation with a focus on increasing the funded status of the plan. As the funded ratio of the plan increases, the portfolio allocation to return-seeking assets (equity and equity-like investments) would be reduced and be offset by an increase in fixed income investments (defined in the policy as liability-hedging assets). The purpose is to reduce the funded ratio volatility and reduce risk in the portfolio as the funded ratio improves. If the funded ratio declines significantly, Cleco’s Retirement Committee will provide instructions about re-allocations to return-seeking assets.
The general funded status to target portfolio allocations are as follows:
FUNDED STATUS
RETURN-SEEKING
LIABILITY-HEDGING
CREDIT
LIABILITY-HEDGING
GOVERNMENT
≤ 80%
60%
20%
20%
80% to 100%
60% to 47%
20% to 37%
20% to 16%
100% to 115%
47% to 10%
37% to 83%
16% to 7%
≥ 115%
10%
83%
7%
In order to meet these objectives and to control risk, Cleco’s Retirement Committee has established the following guidelines that the investment managers must follow in the management of the pension fund assets:
Liability-Hedging Assets
The pension plan investments may include the following liability-hedging assets:
•High-quality credit-oriented investment grade bonds,
•U.S. Treasuries and other U.S. Government-related securities,
•Mortgage securities issues,
•Real estate debt,
•Private placement credit, and
•Securitized assets.
Cash equivalents are held to meet the benefit obligations of the pension plan and to pay fees. The primary objective of holding liability-hedging assets is to reduce the pension plan’s surplus volatility.
Return-Seeking Assets
The pension plan investments may include the following return-seeking assets:
•Public equity,
•Multi-asset credit, and
•Open-ended real assets.
The use of futures and options positions that leverage portfolio positions through borrowing, short sales, or other encumbrances of the pension plan’s assets is prohibited. Certain liability-hedging managers are exempt from the prohibition on derivatives use due to the nature of long duration fixed income management. The investment manager shall not purchase any securities of its organization or affiliated entities.
Other Pension Plan Disclosures
The assumed health care cost trend rates used to measure the expected cost of Other Benefits is 5.0% for 2025 and remains at 5.0% thereafter. The rate used for 2024 was also 5.0%. Assumed health care cost trend rates have a limited effect on the amount reported for Cleco’s health care plans.
The projected benefit payments for the employee pension plan and Other Benefits plan for each year through 2029 and the next five years thereafter are listed in the following table:
(THOUSANDS) PENSION BENEFITS OTHER
BENEFITS,
GROSS
For the year ending Dec. 31,
2025 $ 32,189 $ 5,279
2026 $ 33,030 $ 5,065
2027 $ 33,741 $ 5,052
2028 $ 34,377 $ 4,990
2029 $ 34,929 $ 4,869
Five years thereafter $ 178,546 $ 22,229
SERP
SERP is a non-qualified, non-contributory, defined benefit pension plan for the benefit of certain executive officers who are designated as participants by the Leadership Development and Compensation Committee. In 2014, SERP was closed to new participants; however, with regard to current SERP participants, including former employees or their beneficiaries, all terms of SERP will continue.
Cleco does not fund the SERP liability, but instead pays for current benefits out of the cash available of the respective company of the employed officer. Because SERP is a non-qualified plan, Cleco has purchased life insurance policies on certain SERP participants as a mechanism to provide a source of funding. These polices are held in a rabbi trust formed by Cleco Power. The rabbi trust is the named beneficiary of the life insurance policies and, therefore, receives the proceeds upon death of the insured participants. The life insurance policies may be used to reimburse Cleco for benefits paid from general funds, pay the SERP participants’ death benefits, or pay future SERP payments. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. Cleco Power is the plan sponsor and Support Group is the plan administrator.
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CLECO POWER 2024 FORM 10-K
SERP’s funded status at December 31, 2024, and 2023 is presented in the following table:
SERP BENEFITS
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023
Change in benefit obligation
Benefit obligation at beginning of period
$ 67,462 $ 68,427
Service cost 134 142
Interest cost 3,343 3,604
Actuarial gain (2,814) (345)
Benefits paid (4,582) (4,366)
Benefit obligation at end of period
$ 63,543 $ 67,462
SERP’s accumulated benefit obligation at December 31, 2024, and 2023 is presented in the following table:
SERP BENEFITS
AT DEC. 31,
(THOUSANDS) 2024 2023
Accumulated benefit obligation $ 63,543 $ 67,462
The following table presents net actuarial gains/losses and prior service credits included in other comprehensive income or regulatory assets related to current year gains and losses as a result of being amortized as a component of net periodic benefit costs for SERP for December 31, 2024, and 2023:
SERP BENEFITS
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023
Net actuarial gain occurring during year $ (2,814) $ (345)
Net actuarial loss amortized during year
$ (58) $ (63)
Prior service credit amortized during year
$ (215) $ (215)
The SERP net actuarial gain was $2.8 million for the year ended December 31, 2024, primarily due to the increase in the discount rate. The following table presents net actuarial losses and prior service credit in accumulated other comprehensive income and regulatory assets that have not been recognized as components of net periodic benefit costs for SERP at December 31, 2024, and 2023:
SERP BENEFITS
AT DEC. 31
(THOUSANDS) 2024 2023
Net actuarial loss $ 4,948 $ 7,819
Prior service credit $ (870) $ (1,085)
The non-service components of net periodic benefit cost related to SERP are included in Other income (expense), net within Cleco’s and Cleco Power’s Consolidated Statements of Income. The components of the net SERP costs for 2024, 2023, and 2022 are as follows:
SERP BENEFITS
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Components of periodic benefit costs
Service cost $ 134 $ 142 $ 227
Interest cost 3,343 3,604 2,679
Amortizations
Prior service credit (215) (215) (215)
Net (gain) loss
(81) (63) 1,049
Net periodic benefit cost $ 3,181 $ 3,468 $ 3,740
The measurement date used to determine the SERP benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows:
SERP BENEFITS
AT DEC. 31,
2024 2023
Weighted-average assumptions used to determine the benefit obligation
Discount rate 5.65 % 5.13 %
Rate of compensation increase N/A N/A
SERP BENEFITS
FOR THE YEAR ENDED DEC. 31,
2024 2023 2022
Weighted-average assumptions used to determine the net benefit cost
Discount rate 5.13 % 5.46 % 2.95 %
Rate of compensation increase N/A N/A N/A
The expense related to SERP reflected on Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2024, 2023, and 2022 was $0.5 million, $0.5 million, and $0.6 million, respectively.
CLECO
CLECO POWER 2024 FORM 10-K
Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at December 31, 2024, and 2023 are as follows:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Current $ 4,815 $ 4,593
Non-current $ 58,728 $ 62,868
Cleco Power
AT DEC. 31,
(THOUSANDS) 2024 2023
Current $ 833 $ 613
Non-current $ 10,160 $ 8,394
The projected benefit payments for SERP for each year through 2029 and the next five years thereafter are shown in the following table:
(THOUSANDS) 2025 2026 2027 2028 2029 FIVE
YEARS
THEREAFTER
SERP $ 4,815 $ 4,935 $ 4,888 $ 4,872 $ 4,842 $ 23,218
401(k)
Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 401(k) Plan is a defined contribution plan and is subject to the applicable provisions of the Employee Retirement Income Security Act of 1974. In accordance with the 401(k) Plan, employer contributions are made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary and active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the years ended December 31, 2024, 2023, and 2022 was as follows:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
401(k) Plan expense
$ 9,069 $ 7,770 $ 7,310
Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the years ended December 31, 2024, 2023, and 2022 was as follows:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
401(k) Plan expense
$ 3,071 $ 2,859 $ 2,685
Note 12 - Income Taxes
Cleco
The following table presents a reconciliation of income tax (benefit) expense at the statutory rate and income tax expense (benefit) on income (loss) from continuing operations reported on Cleco’s Consolidated Statement of Income:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS, EXCEPT PERCENTAGES) 2024 2023 2022
Income (loss) from continuing operations before income taxes
$ 78,957 $ (94,942) $ 253,183
Statutory rate 21.0 % 21.0 % 21.0 %
Tax expense (benefit) at federal statutory rate
$ 16,581 $ (19,938) $ 53,168
Increase (decrease)
Flowthrough of tax benefits (8,671) (7,847) (12,272)
State income taxes, net of federal benefit 5,907 (2,256) 16,519
Permanent adjustments 17,596 (388) (4,621)
Amortization of excess ADIT (15,977) (33,518) (32,639)
Other, net (1,380) (1,126) (120)
Total tax expense (benefit)
$ 14,056 $ (65,073) $ 20,035
Effective rate 17.8 % 68.5 % 7.9 %
Information about current and deferred income tax expense from continuing operations is as follows:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Current federal income tax (benefit) expense
$ (46,955) $ (45,429) $ 25,478
Deferred federal income tax expense (benefit)
42,380 (7,137) (9,835)
Amortization of accumulated deferred investment tax credits
(115) (127) (134)
Total federal income tax (benefit) expense
$ (4,690) $ (52,693) $ 15,509
Current state income tax expense (benefit)
18,833 (9,787) 10,326
Deferred state income tax benefit
(87) (2,593) (5,800)
Total state income tax expense (benefit)
$ 18,746 $ (12,380) $ 4,526
Total federal and state income tax expense (benefit)
$ 14,056 $ (65,073) $ 20,035
Items charged or credited directly to member’s equity
Federal deferred income tax
646 (1,374) 6,297
State deferred income tax
327 (531) 2,431
Total tax expense (benefit) from items charged directly to member’s equity
$ 973 $ (1,905) $ 8,728
Total federal and state income tax expense (benefit)
$ 15,029 $ (66,978) $ 28,763
The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2024, and 2023 was comprised of the following:
AT DEC. 31,
(THOUSANDS) 2024 2023
Depreciation and property basis differences
$ (663,346) $ (764,958)
Fuel costs (2,161) 232
Merger fair value adjustments (41,583) (46,052)
Net operating loss carryforward 11,761 57,464
NMTC 68,655 78,955
Other (4,925) (9,820)
Other comprehensive income 4,717 5,927
Postretirement benefits
28,774 38,282
Regulated operations regulatory liability, net
(150,138) (161,427)
Accumulated deferred federal and state income taxes, net
$ (748,246) $ (801,397)
CLECO
CLECO POWER 2024 FORM 10-K
Cleco Power
The following table presents a reconciliation of income tax expense at the statutory rate and income tax expense (benefit) on income (loss) reported on Cleco Power’s Consolidated Statement of Income:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS, EXCEPT PERCENTAGES) 2024 2023 2022
Income before tax $ 157,424 $ 132,715 $ 172,560
Statutory rate 21.0 % 21.0 % 21.0 %
Tax expense at federal statutory rate
$ 33,059 $ 27,870 $ 36,238
Increase (decrease)
Flowthrough of tax benefits (8,671) (7,847) (12,272)
State income taxes, net of federal benefit
11,321 12,296 12,109
Amortization of excess ADIT (15,977) (33,518) (32,639)
Other, net (1,226) (3,235) (933)
Total tax expense (benefit)
$ 18,506 $ (4,434) $ 2,503
Effective rate 11.8 % (3.3) % 1.5 %
Information about current and deferred income tax expense is as follows:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Current federal income tax expense
$ 4,189 $ 11,188 $ 4,921
Deferred federal income tax expense (benefit)
12,736 (20,029) (1,926)
Amortization of accumulated deferred investment tax credits
(114) (127) (134)
Total federal income tax expense (benefit) $ 16,811 $ (8,968) $ 2,861
Current state income tax expense
2,052 5,617 2,406
Deferred state income tax benefit
(357) (1,083) (2,764)
Total state income tax expense (benefit)
$ 1,695 $ 4,534 $ (358)
Total federal and state income tax expense (benefit) $ 18,506 $ (4,434) $ 2,503
Items charged or credited directly to members’ equity
Federal deferred income tax
67 (528) 2,610
State deferred income tax
281 (208) 1,008
Total tax expense (benefit) from items charged directly to member’s equity
$ 348 $ (736) $ 3,618
Total federal and state income tax expense (benefit) $ 18,854 $ (5,170) $ 6,121
The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2024, and 2023 was comprised of the following:
AT DEC. 31,
(THOUSANDS) 2024 2023
Depreciation and property basis differences
$ (663,000) $ (699,020)
Fuel costs (2,161) 1,652
Net operating loss carryforward 11,761 35,359
Other (4,574) (11,465)
Other comprehensive income 2,988 3,336
Postretirement benefits
17,108 25,005
Regulated operations regulatory liability, net
(150,138) (161,427)
Accumulated deferred federal and state income taxes, net
$ (788,016) $ (806,560)
Tax Rate Changes
On December 4, 2024, the Louisiana state corporate income tax rate decreased from 7.5% to 5.5%, effective for the income tax periods beginning on or after January 1, 2025. In accordance with accounting guidance, the impact of the rate change was recorded on Cleco’s and Cleco Power’s consolidated financial statements at December 31, 2024. The impact was a $66.5 million decrease to Accumulated deferred federal and state income taxes, net and a $64.9 million increase to Regulatory liabilities - deferred taxes, net. The impact to income tax expense was $1.6 million.
Valuation Allowance
Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized. At December 31, 2024, and 2023, Cleco had a deferred tax asset resulting from a NMTC carryforward of $68.7 million and $79.0 million, respectively. If the NMTC carryforward is not utilized, it will begin to expire in 2030. Management considers it more likely than not that the deferred tax asset related to the NMTC carryforward will be realized; therefore, no valuation allowance has been recorded for Cleco and Cleco Power.
Quarterly, management monitors and evaluates the realizability of deferred tax assets, and adjustments are recorded as appropriate in future periods. In evaluating the need for a valuation allowance, management considers various factors, including the expected level of future taxable income, available tax planning strategies, and reversals of existing taxable temporary differences. If such estimates and related assumptions change in the future, Cleco and Cleco Power may be required to record a valuation allowance against its deferred tax assets, resulting in additional income tax expense in Cleco’s and Cleco Power’s Consolidated Statements of Income.
Net Operating Losses
For the 2023 tax year, Cleco had a federal net operating loss of approximately $243.5 million and a state net operating loss of $167.2 million. For the 2024 tax year, Cleco expects to utilize a federal net operating loss of $207.8 million and a state net operating loss of $88.8 million.
For the 2023 tax year, Cleco Power had a federal net operating loss of approximately $135.4 million and a state operating loss of $167.2 million. For the 2024 tax year, Cleco Power expects to utilize a federal net operating loss of $99.8 million and state net operating loss of $88.8 million.
Both the federal and state net operating losses may be carried forward indefinitely. Cleco and Cleco Power consider it more likely than not that these income tax losses will be utilized to reduce future income tax payments, and the entire net operating loss carryforward will be utilized.
Uncertain Tax Positions
Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At December 31, 2024, and 2023, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the years ended December 31, 2024, 2023, and 2022, Cleco and Cleco Power had no interest expense related to uncertain tax positions. At December 31, 2024, and 2023, Cleco and Cleco Power had no liability for unrecognized tax positions.
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CLECO POWER 2024 FORM 10-K
Income Tax Audits
Cleco participates in the IRS’s Compliance Assurance Process in which tax positions are examined and agreed upon prior to filing the federal tax return. While the statute of limitations remains open for tax years 2021, 2022, and 2023, the IRS has placed Cleco in the Bridge phase of the Compliance Assurance Process for the 2021 tax year. In this phase, the IRS will not accept any disclosures, conduct any reviews, or provide any assurances. These tax returns were filed consistent with the IRS’s review. The IRS has accepted Cleco’s application for the Compliance Assurance Process for the 2022 tax year and the Compliance Assurance Maintenance phase for the 2023 tax year. In this maintenance phase, the IRS typically will, at its discretion, reduce the level of its review of the tax year relative to the regular Compliance Assurance Process phase.
The state income tax years 2021, 2022, and 2023 remain subject to examination by the Louisiana Department of Revenue.
Cleco classifies income tax penalties as a component of other expenses. For the years ended December 31, 2024, 2023, and 2022, no penalties were recognized.
Note 13 - Segment Disclosures
Cleco
Segment disclosures are based on Cleco’s method of internal reporting, which disaggregates business units by first-tier subsidiary. Cleco’s segment structure and its allocation of corporate expenses were updated to reflect how management measures performance and allocates resources.
Segment managers report periodically to Cleco’s CEO, who is Cleco’s chief operating decision maker, with discrete financial information and, at least quarterly, present discrete financial information to Cleco Holdings’ and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco Holdings’ and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The column shown as Other in the following tables includes the holding company, a shared services subsidiary, an investment subsidiary, discontinued operations, and Cleco Cajun’s natural gas derivatives. After the closing of the Cleco Cajun Divestiture, all of Cleco Cajun’s natural gas derivative contracts were liquidated.
The financial results in the following tables are presented on an accrual basis. EBITDA is a key non-GAAP financial measure used by the CEO to assess the operating performance of Cleco’s segment. Management evaluates the performance of Cleco’s segment and allocates resources to it based on segment profit and the requirements to implement strategic initiatives and projects to meet current business objectives. EBITDA is defined as net income adjusted for interest, income taxes, depreciation, and amortization. Depreciation and amortization in the following tables includes amortization of intangible assets recorded for the fair value adjustment of wholesale power supply agreements as a result of the 2016 Merger. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services.
SEGMENT INFORMATION
FOR THE YEAR ENDED DEC. 31, 2024 (THOUSANDS)
CLECO POWER
Revenue
Base revenue
$ 729,273
Fuel cost recovery revenue (1)
321,980
Other operations 95,137
Affiliate revenue 12,452
Electric customer credits (3,940)
Operating revenue, net $ 1,154,902
Less:
Recoverable fuel and purchased power (1)
$ 321,980
Non-recoverable fuel and purchased power
32,752
Other operations and maintenance (2)
245,651
Taxes other than income taxes
57,754
Other segment items (3)
8,164
EBITDA $ 488,601
(1) These pass through items are regularly provided to the chief operating decision maker as a net amount.
(2) Includes administrative and general expenses of $95.3 million.
(3) Includes amounts for equity portions of AFUDC, pension non-service costs, and changes in the cash surrender value of life insurance policies.
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CLECO POWER 2024 FORM 10-K
FOR THE YEAR ENDED DEC. 31, 2024 (THOUSANDS)
CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue
Base revenue
$ 729,273 $ (2,881) (1)
$ (1) $ 726,391
Fuel cost recovery revenue
321,980 - - $ 321,980
Other operations 95,137 8,162 (22) 103,277
Affiliate revenue 12,452 108,127 (120,579) -
Electric customer credits (3,940) - - (3,940)
Operating revenue, net $ 1,154,902 $ 113,408 $ (120,602) $ 1,147,708
Depreciation and amortization $ 236,444 $ 11,143 (1)
$ 1 $ 247,588
Interest income $ 4,125 $ 11,291 $ (349) $ 15,067
Interest charges $ 98,858 $ 55,046 $ (349) $ 153,555
Federal and state income tax expense (benefit)
$ 18,506 $ (4,450) $ - $ 14,056
Income (loss) from continuing operations, net of income taxes $ 138,918 $ (74,017) $ - $ 64,901
Income from discontinued operations, net of income taxes
$ - $ 45,517 $ - $ 45,517
Net income (loss) $ 138,918 $ (28,500) $ - $ 110,418
Additions to property, plant, and equipment $ 255,336 $ 4,189 $ - $ 259,525
Equity investment in investee $ 1,916 $ (848,952) $ 848,952 $ 1,916
Goodwill $ 1,490,797 $ - $ - $ 1,490,797
Total segment assets $ 6,879,566 $ (286,556) $ 776,596 $ 7,369,606
(1) Includes $2.9 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.
FOR THE YEAR ENDED DEC. 31, 2023 (THOUSANDS)
CLECO POWER
Revenue
Base revenue
$ 692,866
Fuel cost recovery revenue (1)
504,503
Other operations 111,561
Affiliate revenue 8,904
Electric customer credits (60,689)
Operating revenue, net $ 1,257,145
Less:
Recoverable fuel and purchased power (1)
$ 504,512
Non-recoverable fuel and purchased power
45,485
Other operations and maintenance (2)
233,863
Taxes other than income taxes
60,676
Other segment items (3)
(5,719)
EBITDA $ 418,328
(1) These pass through items are regularly provided to the chief operating decision maker as a net amount.
(2) Includes administrative and general expenses of $83.5 million.
(3) Includes amounts for equity portions of AFUDC, pension non-service costs, and changes in the cash surrender value of life insurance policies.
FOR THE YEAR ENDED DEC. 31, 2023 (THOUSANDS)
CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue
Base revenue
$ 692,866 $ (9,454) (1)
$ - $ 683,412
Fuel cost recovery revenue
504,503 - - $ 504,503
Other operations 111,561 5 (1) 111,565
Affiliate revenue 8,904 120,716 (129,620) -
Electric customer credits (60,689) - - (60,689)
Operating revenue, net $ 1,257,145 $ 111,267 $ (129,621) $ 1,238,791
Depreciation and amortization $ 191,745 $ 17,644 (1)
$ - $ 209,389
Interest income $ 5,011 $ 571 $ (189) $ 5,393
Interest charges $ 98,879 $ 66,165 $ (188) $ 164,856
Federal and state income tax benefit
$ (4,434) $ (60,639) $ - $ (65,073)
Income (loss) from continuing operations, net of income taxes $ 137,149 $ (167,018) $ - $ (29,869)
Loss from discontinued operations, net of income taxes $ - $ 14,642 $ - $ 14,642
Net income (loss) $ 137,149 $ (152,376) $ - $ (15,227)
Additions to property, plant, and equipment $ 220,982 $ 9,256 $ - $ 230,238
Equity investment in investee $ 1,992 $ (467,329) $ 467,329 $ 1,992
Goodwill $ 1,490,797 $ - $ - $ 1,490,797
Total segment assets $ 6,920,339 $ 870,743 $ 309,311 $ 8,100,393
(1) Includes $9.5 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.
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FOR THE YEAR ENDED DEC. 31, 2022 (THOUSANDS)
CLECO POWER
Revenue
Base revenue
$ 685,419
Fuel cost recovery revenue (1)
837,647
Other operations 98,759
Affiliate revenue 6,377
Electric customer credits (7,674)
Operating revenue, net $ 1,620,528
Less:
Recoverable fuel and purchased power (1)
$ 837,647
Non-recoverable fuel and purchased power
59,846
Other operations and maintenance (2)
216,851
Taxes other than income taxes
55,075
Regulatory disallowance 13,841
Other segment items (3)
3,341
EBITDA $ 433,927
(1) These pass through items are regularly provided to the chief operating decision maker as a net amount.
(2) Includes administrative and general expenses of $63.7 million.
(3) Includes amounts for equity portions of AFUDC, pension non-service costs, and changes in the cash surrender value of life insurance policies.
FOR THE YEAR ENDED DEC. 31, 2022 (THOUSANDS)
CLECO POWER OTHER ELIMINATIONS TOTAL
Revenue
Base revenue
$ 685,419 $ (9,680) (1)
$ - $ 675,739
Fuel cost recovery revenue
837,647 - - $ 837,647
Other operations 98,759 9 - 98,768
Affiliate revenue 6,377 109,015 (115,392) -
Electric customer credits (7,674) - - (7,674)
Operating revenue, net $ 1,620,528 $ 99,344 $ (115,392) $ 1,604,480
Depreciation and amortization $ 178,231 $ 17,588 (1)
$ - $ 195,819
Interest income $ 5,082 $ 265 $ (97) $ 5,250
Interest charges $ 88,218 $ 55,834 $ (96) $ 143,956
Federal and state income tax expense
$ 2,503 $ 17,532 $ - $ 20,035
Income from continuing operations, net of income taxes
$ 170,057 $ 63,093 $ (2) $ 233,148
Income from discontinued operations, net of income taxes
$ - $ (44,337) $ - $ (44,337)
Net income
$ 170,057 $ 18,756 $ (2) $ 188,811
Additions to property, plant, and equipment $ 228,940 $ 7,827 $ - $ 236,767
Equity investment in investee $ 2,072 $ (320,348) $ 320,348 $ 2,072
Goodwill $ 1,490,797 $ - $ - $ 1,490,797
Total segment assets $ 6,834,970 $ 1,237,096 $ 181,683 $ 8,253,749
(1) Includes $9.7 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.
FOR THE YEARS ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Net income (loss)
$ 110,418 $ (15,227) $ 188,811
Less: income (loss) from discontinued operations, net of income taxes 45,517 14,642 (44,337)
Income (loss) from continuing operations, net of income taxes
64,901 (29,869) 233,148
Add: Depreciation and amortization 247,588 209,389
195,819
Less: Interest income 15,067 5,393 5,250
Add: Interest charges 153,555 164,856 143,956
Add: Federal and state income tax expense (benefit)
14,056 (65,073) 20,035
Add (less): Other corporate costs and noncash items (1) (2)
23,568 144,418 (153,781)
Total segment EBITDA $ 488,601 $ 418,328 $ 433,927
(1) Adjustments made for Other and Eliminations totals not allocated to total segment EBITDA.
(2) Includes (loss) gain on Cleco Cajun’s natural gas derivatives of $(6.5) million, $(116.8) million, and $180.5 million, respectively, for the years ended December 31, 2024, 2023, and 2022.
Cleco Power
Cleco Power is a vertically integrated, regulated electric utility operating within Louisiana, and is viewed as one unit by management. Discrete financial reports are prepared only at the company level.
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Note 14 - Regulation and Rates
Dolet Hills Regulatory Refund
Cleco Power is seeking recovery for stranded and decommissioning costs associated with the retirement of the Dolet Hills Power Station as well as deferred fuel and other mine-related closure costs. These costs were subject to a prudency review by the LPSC. On February 2, 2024, the ALJ released a final recommendation indicating a partial disallowance of the recovery of fuel costs and a refund of related costs previously recovered from customers.
Management estimated that a loss resulting from a potential disallowance was probable, and as a result, an estimated contingent loss of $58.7 million was accrued in provision for rate refund as of December 31, 2023. Cleco Power recorded an additional loss of $1.3 million as of March 31, 2024, as a result of the approval of an uncontested settlement by the LPSC on April 19, 2024. The settlement contains a provision for refunding to Cleco Power’s retail customers $20.0 million per year during each of the third quarters of 2024, 2025, and 2026 for a total refund of $60.0 million. Cleco Power has issued refunds for the third quarter of 2024. For information about the settlement, see Note 16 - “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation - LPSC Audits and Reviews - Dolet Hills Prudency Review.”
FRP
Prior to July 1, 2024, Cleco Power’s annual retail earnings were subject to an FRP approved by the LPSC in June 2021. The prior FRP allowed Cleco Power to earn a target ROE of 9.5%, while providing the opportunity to earn up to 10.0%. Additionally, 60.0% of retail earnings between 10.0% and 10.5%, and all retail earnings over 10.5%, were required to be refunded to customers.
On June 19, 2024, the LPSC approved Cleco Power’s new retail rate plan. Effective July 1, 2024, under the terms of the new FRP, Cleco Power is allowed to earn a target ROE of 9.7%, while providing the opportunity to earn up to 10.3%. Additionally, 60% of retail earnings between 10.3% and 10.9%, and all retail earnings over 10.9%, are required to be refunded to customers. Cleco Power’s next base rate case is required to be filed with the LPSC on or before June 30, 2026. The amount of credits due to customers, if any, is determined by Cleco Power’s monitoring report, which is filed with the LPSC annually. Additionally, as approved in Cleco Power’s FRP, a residential revenue decoupling mechanism was implemented through its infrastructure and incremental cost recovery rider that provides a charge or credit to residential customers for any under or over collection of residential base revenue. For more information on the regulatory liability established for the revenue decoupling mechanism, see Note 6 - “Regulatory Assets and Liabilities - Residential Revenue Decoupling.”
On May 22, 2024, the LPSC approved Cleco Power’s monitoring report for the 12-month period ended June 30, 2023, indicating no material findings and no refund to Cleco Power’s retail customers. On October 31, 2024, Cleco Power filed its monitoring report for the 12-month period ending June 30, 2024, indicating no refund to Cleco Power’s retail customers. Cleco Power has received the LPSC Staff’s draft report indicating no refund and no material findings. Due to the nature of the regulatory process, management is not able to determine the timing of the approval of this report.
Other Deferred Costs
Cleco Power defers other costs that it believes are prudently incurred and probable of recovery from its retail customers. These costs are recorded in Other deferred charges on Cleco’s and Cleco Power’s Consolidated Balance Sheets. On June 19, 2024, the LPSC approved for Cleco Power to recover through its new rates, effective on July 1, 2024, costs associated with Cleco Power’s rate case, IRP, and storm preparation. As a result, $3.8 million was reclassified to Other regulatory assets on Cleco’s and Cleco Power’s Consolidated Balance Sheets. At December 31, 2024, Cleco Power had $4.0 million recorded for deferred costs it anticipates to recover from its customers, subject to approval by the LPSC.
TCJA
The provisions of the TCJA reduced the top federal statutory corporate income tax rate from 35% to 21%. Cleco Power’s retail customers are continuing to receive bill credits resulting from the TCJA. Beginning in July 2021, under Cleco Power’s prior retail rate plan, retail customers received approximately $2.5 million in monthly bill credits for the target retail portion of the unprotected excess ADIT. At June 30, 2024, all amounts for the unprotected excess ADIT had been returned to retail customers.
The retail portion of the protected excess ADIT will be credited until the full amount of the protected excess ADIT has been returned to Cleco Power’s customers through bill credits, which is estimated to be over 30 years. At December 31, 2024, Cleco Power had $189.6 million accrued for the excess ADIT, of which $6.8 million is reflected in current regulatory liabilities.
Teche Unit 3
In May 2023, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3, barring any violations of specific applicable reliability standards. In January 2024, Cleco Power filed a notice with the LPSC to retire Teche Unit 3, and on June 1, 2024, Teche Unit 3 was retired.
Wholesale Rates
Wholesale customers are charged market based rates that are subject to FERC’s triennial market power analysis. Cleco filed its most recent triennial power analysis in December 2023 and received FERC approval on December 13, 2024. The next triennial market power analysis is expected to be filed in December 2026.
Note 15 - Variable Interest Entities
Cleco Securitization I
Cleco Securitization I is a special-purpose, wholly owned subsidiary of Cleco Power that was formed for the purpose of issuing storm recovery bonds to finance the securitization of Storm Recovery Property at Cleco Power. Cleco Securitization I’s assets cannot be used to settle Cleco Power’s obligations and the holders of the storm recovery bonds have no recourse against Cleco Power.
Because Cleco Securitization I’s equity at risk is less than 1% of its total assets, it is considered to be a variable interest entity. Through its equity ownership interest and role as servicer, Cleco Power has the power to direct the most significant financial and operating activities of Cleco Securitization I, including billing, collections, and remittance of retail customer cash receipts to enable Cleco Securitization I to
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pay the principal and interest payments on the storm recovery bonds. Cleco Power also has the obligation to absorb losses up to its equity investment and rights to receive returns from Cleco Securitization I. Therefore, management has determined that Cleco Power is the primary beneficiary of Cleco Securitization I, and as a result, Cleco Securitization I is included in the consolidated financial statements of Cleco Power. No gain or loss was recognized upon initial consolidation.
The following table summarizes the impact of Cleco Securitization I on Cleco’s and Cleco Power’s Consolidated Balance Sheets:
AT DEC. 31,
(THOUSANDS) 2024 2023
Restricted cash - current $ 15,918 $ 15,818
Accounts receivable - affiliate 4,683 3,492
Intangible asset - securitization 384,908 398,658
Total assets $ 405,509 $ 417,968
Long-term debt due within one year 15,087 14,499
Accounts payable - affiliate 1,800 176
Interest accrued 5,997 6,191
Long-term debt, net 380,468 394,944
Total liabilities
403,352 415,810
Member’s equity 2,157 2,158
Total liabilities and member’s equity $ 405,509 $ 417,968
The following table summarizes the impact of Cleco Securitization I on Cleco’s and Cleco Power’s Consolidated Statements of Income:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating revenue $ 32,447 $ 33,913 $ 13,181
Operating expenses (14,183) (14,884) (2,992)
Interest income 667 537 63
Interest charges, net (18,832) (19,467) (10,200)
Income before taxes $ 99 $ 99 $ 52
Oxbow
Cleco and Cleco Power apply the equity method of accounting to report the investment in Oxbow in the consolidated financial statements. Under the equity method, the assets and liabilities of this entity are reported as Equity investment in investee on Cleco’s and Cleco Power’s Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco’s and Cleco Power’s Consolidated Statements of Income.
Oxbow is owned 50% by Cleco Power and 50% by SWEPCO. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco Power’s current assessment of its maximum exposure to loss related to Oxbow at December 31, 2024, consisted of its equity investment of approximately $1.9 million.
The following table presents the components of Cleco Power’s equity investment in Oxbow:
AT DEC. 31,
INCEPTION TO DATE (THOUSANDS) 2024 2023
Purchase price $ 12,873 $ 12,873
Cash contributions 6,399 6,399
Distributions (18,033) (17,280)
Equity income from investee
677 -
Total equity investment in investee $ 1,916 $ 1,992
The following table compares the carrying amount of Oxbow’s assets and liabilities with Cleco Power’s maximum exposure to loss related to its investment in Oxbow:
AT DEC. 31,
(THOUSANDS) 2024 2023
Oxbow’s net assets/liabilities $ 3,832 $ 3,985
Cleco Power’s 50% equity
$ 1,916 $ 1,992
Cleco Power’s maximum exposure to loss $ 1,916 $ 1,992
The following tables contain summarized financial information for Oxbow:
AT DEC. 31,
(THOUSANDS) 2024 2023
Current assets $ 5,055 $ 5,385
Property, plant, and equipment, net 3,486 3,638
Total assets $ 8,541 $ 9,023
Current liabilities $ 529 $ 336
Other liabilities 4,180 4,702
Partners’ capital 3,832 3,985
Total liabilities and partners’ capital $ 8,541 $ 9,023
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Operating revenue $ 363 $ 327 $ 332
Operating expenses (266) (424) (332)
Gain on sale of property
1,356 - -
Interest (expense) income (97) 97 -
Income before taxes $ 1,356 $ - $ -
Oxbow has no third-party agreements, guarantees, or other third-party commitments that contain obligations affecting Cleco Power’s investment in Oxbow.
Note 16 - Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees
Litigation
Gulf Coast Spinning
In September 2015, a potential customer sued Cleco for failure to fully perform an alleged verbal agreement to lend or otherwise fund its startup costs of $6.5 million. Gulf Coast Spinning Company, LLC (Gulf Coast), the primary plaintiff, alleges that Cleco promised to assist it in raising approximately $60.0 million, which Gulf Coast needed to construct a cotton spinning facility near Bunkie, Louisiana (the Bunkie project). According to the petition filed by Gulf Coast in the 12th Judicial
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District Court for Avoyelles Parish, Louisiana, Cleco made such promises of funding assistance in order to cultivate a new industrial electric customer which would increase its revenues under a power supply agreement that it executed with Gulf Coast. Gulf Coast seeks unspecified damages arising from its inability to raise sufficient funds to complete the project, including lost profits.
Diversified Lands loaned $2.0 million to Gulf Coast for the Bunkie project. The loan was secured by a mortgage on the Bunkie project site. Diversified Lands foreclosed on the Bunkie property in February 2020 and has also asserted claims personally against the former owner of Gulf Coast. These claims are based on contracts and credit documents executed by Gulf Coast, the obligations and performance of which were personally guaranteed by the former owner of Gulf Coast. Diversified Lands is seeking recovery of the indebtedness still owed by Gulf Coast to Diversified Lands following the February 2020 foreclosure. This action has been consolidated with the litigation filed by Gulf Coast in the 12th Judicial District Court for Avoyelles Parish, Louisiana. Discovery is ongoing and the trial date has been set for August 2025.
Cleco believes all allegations made by Gulf Coast are contradicted by the written documents executed by Gulf Coast, are otherwise without merit, and that it has substantial meritorious defenses to the claims alleged by Gulf Coast.
Dispute with Saulsbury Industries
In October 2018, Cleco Power sued Saulsbury Industries, Inc., the former general contractor for the St. Mary Clean Energy Center project, seeking damages for Saulsbury Industries, Inc.’s failure to complete the St. Mary Clean Energy Center project on time and for costs incurred by Cleco Power in hiring a replacement general contractor. The action was filed in the Ninth Judicial District Court for Rapides Parish. Saulsbury Industries, Inc. removed the case to the U.S. District Court for the Western District of Louisiana, in March 2019. In September 2020, Cabot Corporation was allowed to join the case pending in the Ninth Judicial District Court for Rapides Parish.
In January 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC, in the U.S. District Court for the Western District of Louisiana. Saulsbury Industries, Inc. alleged that Cleco Power and Cabot Corporation caused delays in the St. Mary Clean Energy Center project, resulting in alleged impacts to Saulsbury Industries, Inc.’s direct and indirect costs. In June 2019, Cleco Power and Cabot Corporation each filed separate motions to dismiss. In October 2019, the District Court denied Cleco Power’s motion as premature and ruled that Saulsbury Industries, Inc. had six weeks to conduct discovery on specified jurisdictional issues. The Magistrate Judge presiding over the Western District of Louisiana consolidated cases issued a report and recommendation to the District Judge that the case instituted by Saulsbury Industries, Inc. be dismissed without prejudice and the case initiated by Cleco Power be remanded to the Ninth Judicial District Court for Rapides Parish. Saulsbury Industries, Inc. did not oppose the Magistrate Judge’s report and recommendation, and the District Judge issued a ruling that adopted the Magistrate Judge’s report and recommendation, which included reasoning consistent with Cleco Power’s arguments. Thus, the federal consolidated cases are now closed.
In October 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC in the 16th Judicial District Court for St.
Mary Parish. Saulsbury Industries, Inc. asserted the same claim as the Western District litigation and further asserts claims for payment on an open account. In December 2019, Cleco Power moved to stay the case, arguing that the Rapides Parish suit should proceed. On February 14, 2020, the court granted Cleco Power’s motion. The 16th Judicial District Court for the St. Mary Parish case held a hearing in October 2020, and the judge granted Cleco Power’s declinatory exceptions of lis pendens. Thus, the St. Mary’s Parish case has been dismissed. Saulsbury appealed this decision.
In May 2022, the Court of Appeal, First Circuit, ruled in favor of Cleco Power and affirmed the decision of the 16th Judicial District Court for St. Mary Parish with respect to Cleco Power. However, the First Circuit Court reversed the 16th Judicial District Court for St. Mary Parish’s decision dismissing Cabot Corporation from the St. Mary Parish case. All parties filed applications for rehearing, which were denied in June 2022.
Cabot Corporation applied for review by the Louisiana Supreme Court of the portion of the First Circuit Court's ruling that denied Cabot Corporation’s exception seeking dismissal from the St. Mary Parish litigation. In November 2022, the Louisiana Supreme Court rendered a decision in favor of Cabot Corporation. The Louisiana Supreme Court’s decision reversed the First Circuit Court’s decision and reinstated the decision of the 16th Judicial District Court granting Cabot Corporation’s declinatory exceptions of lis pendens. The St. Mary Parish case has been dismissed in full.
The stay was lifted in the Rapides Parish case and the Rapides Parish case is proceeding. Cleco Power and Saulsbury are currently participating in discovery.
LPSC Audits and Reviews
Fuel Audits
Generally, Cleco Power’s cost of fuel used for electric generation and the cost of purchased power are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such expenses. Recovery of FAC costs is subject to periodic fuel audits by the LPSC, which are performed at least every other year.
In January 2023, Cleco Power received a notice of audit from the LPSC for the period of January 2020 to December 2022. The total amount of fuel expense included in the audit is $1.10 billion. Cleco Power has responded to multiple sets of LPSC data requests. Cleco Power has FAC filings for January 2023 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of fuel cost is ordered resulting in a refund, it could have a material adverse effect on the results of operations, financial condition or cash flows of the Registrants.
Environmental Audit
In 2009, the LPSC approved Cleco Power to recover certain costs of environmental compliance through an EAC. The costs eligible for recovery are those for prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the costs of reagents such as ammonia and limestone that are a part of the fuel mix used to
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reduce air emissions, among other things. Cleco Power has EAC filings for January 2023 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of environmental cost is ordered resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.
Energy Efficiency Audit
In 2013, the LPSC issued a General Order adopting rules promoting energy efficiency programs. Cleco Power began participating in energy efficiency programs in November 2014. Through an approved rate tariff, Cleco Power recovered $8.5 million and $6.8 million for the 2022 and 2021 program years, respectively.
In May 2024, the LPSC approved the audit report for program years 2021 and 2022, which indicated no material findings.
On January 24, 2024, the LPSC voted to shift control of energy efficiency programs from utilities to an independent, third-party administrator selected by and accountable to the LPSC. This action will remove the provision whereby utilities were allowed to recover any lost revenues associated with unsold electricity. Cleco Power is subject to audits for program years 2023 and thereafter until the time these programs are shifted to the third-party administrator, which is expected in January 2026.
Dolet Hills Prudency Review
Cleco Power is seeking recovery for stranded and decommissioning costs associated with the retirement of the Dolet Hills Power Station as well as deferred fuel and other mine-related closure costs. On February 2, 2024, the ALJ released a final recommendation indicating a partial disallowance of the recovery of fuel costs and a refund of related costs previously recovered from customers. Management estimated that a loss resulting from a potential disallowance was probable, and as a result, an estimated contingent loss of $58.7 million was accrued in provision for rate refund as of December 31, 2023.
On April 19, 2024, the LPSC approved an uncontested settlement containing the following provisions:
•a $40.0 million reduction in the regulatory asset associated with the Dolet Hills Power Station,
•refunding $20.0 million per year to Cleco Power’s retail customers as a credit to their bills during the third quarters of 2024, 2025, and 2026 for a total of $60.0 million, and
•allowing securitization of $305.0 million. If the securitization is not complete by September 1, 2024, Cleco Power is allowed to accrue a carrying charge through the earlier of the completion of the securitization or January 31, 2025.
As a result of the settlement, the following was recorded in Cleco’s and Cleco Power’s Consolidated Financial Statements as of March 31, 2024:
•a $40.0 million reduction in regulatory assets with an offsetting increase recorded as depreciation expense and
•a $1.3 million increase in the provision for rate refund and electric customer credits.
During the third quarter of 2024, approximately $20.0 million was refunded to Cleco Power’s retail customers as a credit to their bills in accordance with the settlement, as previously discussed.
On May 17, 2024, Cleco Power filed an application with the LPSC for a financing order authorizing the securitization. On November 27, 2024, the LPSC issued the financing order authorizing the securitization financing of costs related to the settlement, which became final and not subject to appeal on December 13, 2024. Management anticipates the securitization financing to close by the end of March 2025.
FERC Audits and Reviews
Generally, Cleco Power records wholesale transmission revenue through approved formula rates, Attachment O of the MISO tariff, and certain grandfathered agreements. The calculation of the rate formulas, as well as FERC accounting and reporting requirements, are subject to periodic audits by FERC. In the fourth quarter of 2024, as a part of FERC Docket No. 14-12-016 that reviewed MISO Attachment O rates, FERC ruled that the return on equity component of the rate was not justified. As a result, Cleco Power estimated and recorded a refund of $0.5 million to be refunded during 2025.
Other
Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of December 31, 2024, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters for Cleco and Cleco Power are $11.5 million and $11.0 million, respectively. Cleco and Cleco Power have accrued these
amounts.
Off-Balance Sheet Commitments and Guarantees
Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require the Registrants to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees.
Cleco Holdings entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Holdings had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates or may have contracted with them at terms less favorable to its affiliates.
The off-balance sheet commitments are not recognized on Cleco’s and Cleco Power’s Consolidated Balance Sheets because management has determined that Cleco’s and Cleco Power’s affiliates are able to perform the obligations under their contracts and that it is not probable that payments by Cleco or Cleco Power will be required.
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CLECO POWER 2024 FORM 10-K
Cleco Holdings provided guarantees and indemnities to Entergy Louisiana and Entergy Gulf States as a result of the sale of the Perryville generation facility in 2005. The remaining indemnities relate to environmental matters that may have been present prior to closing. These remaining indemnities have no time limitations. The maximum amount of the potential payment to Entergy Louisiana and Entergy Gulf States is $42.4 million. Management does not expect to be required to pay Entergy Louisiana and Entergy Gulf States under these guarantees.
On behalf of Acadia, Cleco Holdings provided guarantees and indemnities as a result of the sales of Acadia Unit 1 to Cleco Power and Acadia Unit 2 to Entergy Louisiana in 2010 and 2011, respectively. The remaining indemnities relate to the fundamental organizational structure of Acadia. These remaining indemnities have no time limitations or maximum potential future payments. Management does not expect to be required to pay Cleco Power or Entergy Louisiana under these guarantees.
Cleco Holdings provided indemnities to Cleco Power as a result of the transfer of Coughlin to Cleco Power in March 2014. Cleco Power also provided indemnities to Cleco Holdings as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power and Cleco Holdings for their respective indemnities is $40.0 million, except for indemnities relating to the fundamental organizational structure of each respective entity, of which the maximum amount is $400.0 million. Management does not expect to be required to make any payments under these indemnities.
As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of the Dolet Hills Power Station, have agreed to pay the loan and lease principal obligations of the lignite miner, DHLC, when due if DHLC does not have sufficient funds or credit to pay. Any amounts projected to be paid would be based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for reclamation obligations. As of December 31, 2024, Cleco Power does not expect any payments to be made under this guarantee. Cleco Power has the right to dispute the incurrence of such loan and lease obligations through the review of the mining reclamation plan before the incurrence of such obligations. The Amended Lignite Mining Agreement does not affect the amount the Registrants can borrow under their credit facilities.
Cleco has letters of credit to MISO pursuant to energy market requirements. The letters of credit automatically renew each year and have no impact on Cleco Holdings’ or Cleco Power’s revolving credit facility.
Generally, neither Cleco Holdings nor Cleco Power has recourse that would enable them to recover amounts paid under their guarantee or indemnification obligations. There are no assets held as collateral for third parties that either Cleco Holdings or Cleco Power could obtain and liquidate to recover amounts paid pursuant to the guarantees or indemnification obligations.
Long-Term Purchase Obligations
Cleco Holdings has several unconditional long-term purchase obligations primarily related to information technology outsourcing, network monitoring, and software maintenance. Cleco Power has several unconditional long-term purchase obligations primarily related to the purchase of fuel, energy delivery facilities, information technology outsourcing, natural
gas storage, network monitoring, and software maintenance. The aggregate amount of payments required under such obligations at December 31, 2024, is as follows:
(THOUSANDS) CLECO POWER CLECO
For the year ending Dec. 31,
2025 $ 30,330 $ 61,511
2026 12,612 19,420
2027 11,368 11,454
2028 11,173 11,194
2029 10,604 10,604
Thereafter 36,730 36,730
Total long-term purchase obligations $ 112,817 $ 150,913
Cleco’s payments under these agreements for the years ended December 31, 2024, 2023, and 2022 were $55.7 million, $79.2 million, and $52.9 million, respectively. Cleco Power’s payments under these agreements for the years ended December 31, 2024, 2023, and 2022 were $48.6 million, $70.5 million, and $49.0 million, respectively.
Other Commitments
Cleco has accrued for liabilities related to third parties, employee medical benefits, and AROs.
In April 2015, the EPA published a final rule for regulating the disposal and management of CCRs from coal-fired power plants (CCR Rule). In August 2018, the D.C. Court of Appeals vacated several requirements in the CCR regulation, which included eliminating the previous acceptability of compacted clay material as a liner for impoundments. As a result, in August 2020, the EPA published a final rule that would set deadlines for costly modifications including retrofitting of clay-lined impoundments with compliant liners or closure of the impoundments. In November 2020, demonstrations were submitted to the EPA specifying its intended course of action for the ash disposal facilities at Rodemacher Unit 2 and the Dolet Hills Power Station in order to comply with the final CCR Rule. In January 2022, Cleco Power received communication from the EPA that the demonstrations had been deemed complete. Cleco Power withdrew the Dolet Hills demonstration due to the cessation of receiving waste. The remaining demonstrations are still subject to EPA approval based on pending technical review.
On May 8, 2024, the EPA published a final rule that would regulate CCR Management Units (MUs), which includes non-containerized accumulations of CCR on the land at facilities otherwise subject to federal CCR regulations. The final regulation mandates the conducting of facility evaluations at such facilities after the effective date of the rule to determine if CCR MUs are present. For any identified CCR MUs of a particular size, the regulation would require evaluating any impacts on groundwater along with planning for closure of any identified CCR MU sites. Cleco does not expect this final rule to have a material financial impact on its generating units and environmental obligations.
Risks and Uncertainties
Cleco could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco or its affiliates are not in compliance with loan agreements or bond indentures.
CLECO
CLECO POWER 2024 FORM 10-K
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.
Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required and Cleco’s financial condition could be materially adversely affected.
Note 17 - Affiliate Transactions
Cleco
Cleco has entered into service agreements with affiliates to receive and to provide goods and professional services. Goods and services received by Cleco primarily involve services provided by Support Group. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services.
Cleco Power’s affiliates are charged the higher of management’s estimated fair market value or fully loaded costs for goods and services provided by Cleco Power. Cleco, with the exception of Support Group, charges Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group bills fully loaded costs to affiliates, which includes payroll and non-payroll costs.
All charges and revenues from consolidated affiliates were eliminated in Cleco’s Consolidated Statements of Income for the years ending December 31, 2024, 2023, and 2022.
At December 31, 2024, and 2023, Cleco Holdings had an affiliate receivable of $35.5 million and $24.2 million, respectively, from Cleco Group primarily for estimated income taxes paid on behalf of Cleco Group. At December 31, 2024, and 2023, Cleco Holdings had an affiliate payable of $21.4 million and $10.7 million, respectively to Cleco Group primarily for settlement of taxes payable.
For the years ended December 31, 2024, 2023, and 2022, Cleco Holdings made $145.0 million, $53.5 million, and $219.6 million respectively, of distribution payments to Cleco Group. For the years ended December 31, 2024, 2023, and 2022, Cleco Holdings received no equity contributions from Cleco Group.
Cleco Power
Cleco Power has entered into service agreements with affiliates to receive and to provide goods and professional services. Charges from affiliates included in Cleco Power’s Consolidated Statements of Income primarily involve services provided by Support Group in accordance with service agreements. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services.
With the exception of Support Group, affiliates charge Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group charges only fully loaded costs, which are based on management’s estimated fair market value. The following table is a summary of charges from each affiliate included in Cleco Power’s Consolidated Statements of Income:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Support Group
Other operations and maintenance $ 99,547 $ 96,907 $ 87,830
Taxes other than income taxes $ - $ 65 $ (41)
Other expense $ 242 $ 92 $ 60
Cleco Holdings
Other expense $ 625 $ - $ -
The majority of the services provided by Cleco Power relates to the lease of office space to Support Group and transmission and internal software services to Cleco Cajun in accordance with service agreements. Cleco Power charges affiliates the higher of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements.
The following table is a summary of revenue received from affiliates included in Cleco Power’s Consolidated Statements of Income:
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Other operations revenue
Cleco Cajun
$ 3,422 $ 10,208 $ 10,213
Affiliate revenue
Support Group 4,938 5,651 5,475
Cleco Cajun 7,385 3,253 902
Cleco Holdings 129 - -
Total $ 15,874 $ 19,112 $ 16,590
Cleco Power had the following affiliate receivable and payable balances associated with the service agreements:
AT DEC. 31,
2024 2023
(THOUSANDS) ACCOUNTS
RECEIVABLE
ACCOUNTS
PAYABLE
ACCOUNTS
RECEIVABLE
ACCOUNTS
PAYABLE
Cleco Holdings
$ 185 $ 318 $ 14 $ 367
Support Group 989 11,071 1,104 12,833
Cleco Cajun - - 3,425 -
Total $ 1,174 $ 11,389 $ 4,543 $ 13,200
During 2024, 2023, and 2022, Cleco Power made $95.0 million, $94.8 million, and $105.5 million respectively, of distribution payments to Cleco Holdings. Cleco Power received no equity contribution from Cleco Holdings in 2024, 2023 and 2022.
CLECO
CLECO POWER 2024 FORM 10-K
Note 18 - Intangible Assets and Goodwill
Securitized Intangible Asset
On June 22, 2022, Cleco Securitization I acquired the Storm Recovery Property from Cleco Power for a purchase price of $415.9 million. The Storm Recovery Property is classified as a securitized intangible asset on Cleco’s and Cleco Power’s Consolidated Balance Sheets. This securitized intangible asset is being amortized ratably each period consistent with actual collections of the asset's portion of revenue requirement billed to Cleco Power’s customers. At the end of its life, this securitized intangible asset will have no residual value. The amortization is included in Depreciation and amortization on Cleco’s and Cleco Power’s Consolidated Statements of Income. Cleco expects to recognize an estimated $78.5 million of amortization expense over the five years ending December 31, 2029.
The following table presents the amortization expense of the securitized intangible asset in Cleco’s Consolidated Statement of Income:
FOR THE YEAR ENDED DEC. 31.
(THOUSANDS) 2024 2023 2022
Amortization expense
Storm Recovery Property intangible asset $ 13,750 $ 14,465 $ 2,823
The following table summarizes the balance of the securitized intangible asset subject to amortization included on Cleco’s and Cleco Power’s Consolidated Balance Sheets:
AT DEC. 31,
(THOUSANDS) 2024 2023
Storm Recovery Property intangible asset $ 415,946 $ 415,946
Accumulated amortization (31,038) (17,288)
Net securitized intangible asset subject to amortization
$ 384,908 $ 398,658
Other Intangible Assets
As a result of the 2016 Merger, fair value adjustments were recorded on Cleco’s Consolidated Balance Sheet for the valuation of finite intangible assets relating to long-term wholesale power supply agreements. At the end of their lives, these power supply agreement intangible assets will have no residual value. At December 31, 2024, Cleco Power had one remaining power supply agreement intangible asset being amortized over the estimated life of its contract of 19 years, and the amortization is included in Electric operations on Cleco’s Consolidated Statements of Income. Cleco expects to recognize an estimated $3.7 million for amortization expense over the five years ending December 31, 2029.
The following table presents the amortization expense recognized of other intangible assets in Cleco’s Consolidated Statements of Income:
Cleco
FOR THE YEAR ENDED DEC. 31,
(THOUSANDS) 2024 2023 2022
Amortization expense
Power supply agreement
$ 2,881 $ 9,454 $ 9,680
The following table summarizes the balance of other intangible assets subject to amortization included in Cleco’s Consolidated Balance Sheets:
Cleco
AT DEC. 31,
(THOUSANDS) 2024 2023
Power supply agreements
$ 14,238 $ 85,104
Accumulated amortization (6,487) (74,471)
Net other intangible assets subject to amortization
$ 7,751 $ 10,633
Goodwill
On April 13, 2016, in connection with the completion of the 2016 Merger, Cleco recognized goodwill of $1.49 billion. Management assigned the recognized goodwill to the Cleco Power reporting unit. Goodwill is required to be tested for impairment at the reporting unit level on an annual basis or whenever events or circumstances indicate that the value of goodwill may be impaired.
In performing the impairment test, Cleco compares the fair value of the reporting unit to its carrying value including goodwill. If the carrying value including goodwill were to exceed the fair value of a reporting unit, an impairment loss would be recognized. A goodwill impairment loss is measured as the amount by which a reporting unit's carrying value exceeds fair value, not to exceed the carrying amount of goodwill.
Cleco estimates the reporting unit's fair value using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. The income approach cash flow valuations involve a number of estimates that require broad assumptions and significant judgment by management regarding future performance, including estimation of future cash flows related to capital expenditures, the weighted average cost of capital or discount rate and the assumed long-term growth rate approach, which incorporates management's assumptions regarding sustainable long-term growth. The market approach includes significant assumptions around the implied market multiples for certain peer companies. Management selects comparable peers based on each peer’s primary business mix, operations, and market capitalization compared to the applicable reporting unit and calculates implied market multiples based on available projected earnings guidance and peer company market values as of the test date.
Cleco performs an annual impairment test each August. In between annual tests, Cleco monitors its estimates and assumptions regarding estimated future cash flows, including the impact of movements in market indicators in future quarters, and will update the impairment analyses if a triggering event occurs. While Cleco believes the assumptions are reasonable, actual results may differ from projections. To the extent cash flows, long-term growth rates, U.S. Treasury rates, or other factors outside of Cleco’s control may impact Cleco’s projected results, Cleco may be required to reduce all or a portion of the carrying value of goodwill.
Cleco conducted its 2024 annual impairment test using an August 1, 2024, measurement date and determined that the estimated fair value of the Cleco Power reporting unit exceeded its carrying value, and no impairment existed.
CLECO
CLECO POWER 2024 FORM 10-K
Note 19 - Accumulated Other Comprehensive Loss
The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power.
All amounts are reported net of income taxes. Amounts in parentheses indicate debits.
Cleco
(THOUSANDS) POSTRETIREMENT
BENEFIT NET GAIN (LOSS)
Balance, Dec. 31, 2021
$ (23,629)
Other comprehensive income before reclassifications
Postretirement benefit adjustments incurred during the year 23,647
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss 41
Balance, Dec. 31, 2022
$ 59
Other comprehensive income before reclassifications
Postretirement benefit adjustments incurred during the year (3,482)
Amounts reclassified from AOCI
Amortization of postretirement benefit net gain
(1,689)
Balance, Dec. 31, 2023
$ (5,112)
Other comprehensive income before reclassifications
Postretirement benefit adjustments incurred during the year 3,603
Amounts reclassified from AOCI
Amortization of postretirement benefit net gain
(1,175)
Balance, Dec. 31, 2024
$ (2,684)
Cleco Power
(THOUSANDS) POSTRETIREMENT BENEFIT NET
(LOSS) GAIN
NET (LOSS) GAIN
ON CASH
FLOW HEDGES
TOTAL AOCI
Balances, Dec. 31, 2021 $ (12,885) $ (5,298) $ (18,183)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments incurred during the year 8,339 - 8,339
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss 1,228 - 1,228
Reclassification of net loss to interest charges - 251 251
Balances, Dec. 31, 2022 $ (3,318) $ (5,047) $ (8,365)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments incurred during the year (2,623) - (2,623)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss 386 - 386
Reclassification of net loss to interest charges - 251 251
Balances, Dec. 31, 2023 $ (5,555) $ (4,796) $ (10,351)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments incurred during the year (559) - (559)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss 657 - 657
Reclassification of net loss to interest charges - 154 154
Balances, Dec. 31, 2024 $ (5,457) $ (4,642) $ (10,099)
Note 20 - Storm Restoration
During April and May 2024, Cleco Power’s service territory sustained damage in multiple severe weather events. Total storm restoration costs related to these events were approximately $14.2 million.
On September 11, 2024, Hurricane Francine made landfall in southeast Louisiana as a Category 2 storm, causing power outages for approximately 37,000 of Cleco Power’s electric customers. By September 14, 2024, power was restored to all affected customers. Cleco Power’s total storm restoration costs related to this weather event is approximately $23.4 million.
On October 8, 2024, Cleco Power made a filing with the LPSC seeking approval to withdraw storm restoration costs associated with the April 2024 storm, as well as costs associated with other storm events that occurred since December 2022, from the storm reserve. This request is currently under review by the LPSC. Management is assessing the accumulated restoration costs for Hurricane Francine as well as other storms that occurred in 2024 and anticipates filing an additional application seeking approval for withdrawal of these costs from the restricted storm reserve in 2025. For more information on Cleco Power’s total recorded accumulated storm restorations costs, see Note 6 - “Regulatory Assets and Liabilities - Storm Reserves.”
CLECO
CLECO POWER 2024 FORM 10-K

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
Under the supervision and with the participation of Cleco Holdings and Cleco Power (individually, “Registrant” and collectively, the “Registrants”) management, including the CEO and CFO, the Registrants have evaluated the effectiveness of their disclosure controls and procedures as of December 31, 2024. Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms; and that the Registrants’ disclosure controls and procedures are also effective in ensuring that such information is accumulated and communicated to the Registrants’ management, including the CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.
Internal Control Over Financial Reporting
Managements’ Reports on Internal Control Over Financial Reporting
The management of the Registrants are responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) and 15d-15(f) promulgated under the Exchange Act. The Registrants’ internal control over financial reporting is a process designed by, or under the supervision of, the Registrants’ principal executive and financial officers and effected by the Registrants’ board of managers, management,
and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.
As a result of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness in future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.
The management of the Registrants, under the supervision of each of the Registrants’ principal executive officer and principal financial officer, conducted an assessment of the effectiveness of the Registrants’ respective internal control over financial reporting as of December 31, 2024. In making this assessment, management used the criteria in Internal Control-Integrated Framework issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
Based on this assessment, the management of the Registrants concluded that, as of December 31, 2024, the Registrants’ internal control over financial reporting was effective.
Changes in Internal Control over Financial Reporting
There have been no changes in the Registrants’ internal control over financial reporting that occurred during the quarter ended December 31, 2024, that have materially affected, or are reasonably likely to materially affect, the Registrants’ internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
Insider Trading Arrangements
During the three months ended December 31, 2024, no director or officer (as defined in Rule 16a-1(f) of the Exchange Act) of Cleco Holdings or Cleco Power adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.
Cleco Holdings 2025 Retention Plan
The partners of Cleco Partners have informed the Registrants that they are considering their options for their investment in Cleco Holdings. This process may result in the sale of some or all of the equity in Cleco Holdings to a party other than the current partners of Cleco Partners or their affiliates (such transaction being referred as the equity transaction). In order to provide for the retention of key employees throughout this process and to align the interests of such key employees around the ultimate financial result for the current partners of Cleco Partners, Cleco Holdings expects to adopt an additional compensation plan for select named executive officers, executive officers, and employees of the Company. Target awards for participants in the new retention plan are expected
to range from one time to two times base annual salary. Provided that the participant in the new retention plan is employed by the Company on the first anniversary of the closing of the equity transaction, the participant will be paid the cash lump sum of (i) 50% of the target amount for that participant and (ii) between 25% and 100% of the target amount for that participant depending on the amount received by the partners of Cleco Partners in the equity transaction relative to a target price for the equity transaction yet to be determined. Accordingly, the range of payments to a participant may range from 75% of the target amount for such participant to 150% of the target amount for such participant. Any payments under the new retention plan are contingent on the closing of the equity transaction and would generally be made one year after the closing of the equity transaction.
If a participant in the new retention plan resigns, retires, or is terminated with “cause” after closing of the equity transaction but prior to the first anniversary of the equity transaction, such participant would forfeit any and all payments under the new retention plan. If a participant in the new retention plan is no longer employed by the Company as a result of death or “disability,” resigns due to “good reason,” or is terminated without “cause,” the participant (or his/her
CLECO
CLECO POWER 2024 FORM 10-K
estate in the case of the participant’s death) would receive the payment under the terms of the new retention plan if and when the new retention plan otherwise makes payments to the participants in the new retention plan. The term’s “disability,” “good reason,” and “cause” will have the same definitions as such terms are defined in the LTIP.
Any payout amount under the new retention plan will not be treated as salary or taken into account for purposes of determining any other compensation or benefits that may be provided to the participant, including any severance benefits. In the event any payout amount under the new retention plan is subject to Section 280G or 4999 of the IRC, the amount of the payout amount (or any other benefits or payments subject to such sections) shall be reduced, unless otherwise determined
by the Company, to the maximum amount that may be paid to the participant without penalty under such sections if such reduction would result in such participant retaining a greater after-tax amount than if the full benefits or payments were received by such participant.
It is expected that the new retention plan will be adopted by Cleco’s Leadership Development and Compensation Committee and Boards of Managers when sufficient information is available to set the target price for the equity transaction. Accordingly, the terms of the new retention plan included herein are preliminary in nature and may be altered by Cleco’s Leadership Development and Compensation Committee and Boards of Managers.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE OF THE REGISTRANTS
Boards of Managers of Cleco
As of March 7, 2025, the Board of Managers of Cleco Holdings is comprised of 12 managers, as set forth below. Cleco Power’s Board of Managers is comprised of 12 managers, excluding Dylan Arnould, who is a member of the Board of Managers of Cleco Group and Cleco Holdings, and including special independent manager, Melissa Stark. The Board of Managers of Cleco Holdings and the Board of Managers of Cleco Power are collectively referred to below as “the Boards.” The managers’ ages, dates of appointment, employment history, and committee assignments as of March 7, 2025, are also set forth below. Each of Ms. Scott and Messrs. Gallot, Gilchrist, and Wainer serve pursuant to one-year agreements which are considered for renewal annually by the Boards. Ms. Stark serves under a staffing agreement. Mr. Fontenot serves by virtue of his position as the CEO, and the other managers are designated for membership by BCI, John Hancock, or MAM.
Dylan Arnould is a Director in Manulife’s Infrastructure Investment Group. He joined John Hancock/Manulife in 2018 and is responsible for origination, execution, and asset management of investments in various infrastructure sections. Mr. Arnould is 36 years old and became a member of the Boards of Managers for Cleco Group and Cleco Holdings in 2023. Mr. Arnould is a member of the Audit Committee.
Mr. Arnould’s previous industry experience includes development and merger and acquisition of power projects with InterGen, as well as with origination, execution and management of climate technology venture capital investments with the Massachusetts Clean Energy Center.
Mr. Arnould holds a Bachelor of Arts degree from Duke University and a Master of Arts degree in International Economics and International Affairs from the Johns Hopkins University, School of Advanced International Studies.
Andrew Chapman joined Macquarie in 2006 and retired on September 30, 2021. Through his consulting company WesWave LLC, Mr. Chapman is a consultant to MAM and serves on the Boards of Cleco and served on the board of the entity that holds Lordstown Energy Center, a gas-fired power plant in eastern Ohio until late 2024. Consulting through WesWave LLC, he also assists MAM on other matters as requested. During his 15 years with Macquarie, Mr. Chapman has served as a director of utility companies owned in part by MAM’s funds, including Puget Sound Energy, Duquesne Light Company, Aquarion Water Company, Cleco, and entities related to those holdings. Mr. Chapman is 69 years old and became a member of the Boards in 2016. He is the Chair of the Business Planning and Budget Review Committee, and the Leadership Development and Compensation Committee, and a member of the Asset Management Committee, the
Governance and Public Affairs Committee and the Audit Committee.
Mr. Chapman held executive positions with Elizabethtown Water Company, E-town Corporation, American Water Works and the State of New Jersey prior to joining Macquarie in 2006.
Mr. Chapman earned his Master of Business Administration from the Yale School of Management and his bachelor’s degree from the University of California at Berkeley.
William “Bill” Fontenot has served as the President and CEO of Cleco Holdings since January 2018 and CEO of Cleco Power and Cleco Cajun since February 2019. Mr. Fontenot is 62 years old and was appointed to the Boards in 2018. He is a member of the Asset Management Committee, the Business Planning and Budget Review Committee, and the Governance and Public Affairs Committee. Mr. Fontenot has previously served as Interim CEO of Cleco Power from February 2017 to December 2017, Chief Operating Officer of Cleco Power from April 2016 to February 2017, and Senior Vice President of Utility Operations from March 2012 to April 2016.
Mr. Fontenot serves on the boards of the Leaders for a Better Louisiana, Louisiana Central, Louisiana Economic Development Partnership, Edison Electric Institute and the Louisiana State University at Alexandria Foundation.
Mr. Fontenot holds a Bachelor of Science degree in electrical engineering from Louisiana State University.
Paraskevas “Paris” Fronimos is a Director on the Infrastructure and Renewable Resource Investments team of BCI. He is 50 years old and became a member of the Boards in 2019. Mr. Fronimos is the Chair of the Asset Management Committee and a member of the Business Planning and Budget Review Committee.
Mr. Fronimos joined BCI in 2017 and works with the management teams of portfolio companies primarily in the energy, midstream, and utility sectors in BCI’s global portfolio. Mr. Fronimos typically serves as a Non-Executive Director on the boards of BCI’s portfolio companies, including natural gas pipelines in Brazil and in Germany and a district energy company in the United Arab Emirates. Prior to joining BCI, Mr. Fronimos was employed by Nova Scotia Power, a Canadian power utility, as a fuels portfolio manager. He has more than 15 years of experience in the energy and utilities space, having worked on environmental and energy policy, developing greenfield energy projects, advising on transactions, and driving fleet and fuel supply optimization activities, including commodity pricing and hedging.
Mr. Fronimos holds a bachelor’s degree in Mineral Resources Engineering from the Technical University of Crete and a Master’s in Business Administration (specializing in Natural Resources and Energy) from the University of Alberta.
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CLECO POWER 2024 FORM 10-K
Richard “Rick” Gallot, Jr. is the President of the University of Louisiana System. He is 58 years old and became a member of the Boards in 2016. Mr. Gallot is a member of the Leadership Development and Compensation Committee and the Governance and Public Affairs Committee.
Mr. Gallot served as the President of Grambling State University from 2016 to 2023. He serves on the board of Origin Bancorp, Inc. (Nasdaq: OBNK) and was appointed to the Louisiana Cybersecurity Commission by former Louisiana Governor John Bel Edwards. He previously served as a Louisiana state senator for District 29, where he held the position of vice chairman of the Commerce Committee and was a member of the Agriculture, Forestry, Aquaculture, and Rural Development Committee and the Revenue and Fiscal Affairs Committee. He previously served as a member of the Louisiana House of Representatives for District 11, where he served as Chair of the House and Governmental Affairs Committee and was a member of the Executive Committee.
Mr. Gallot obtained his Juris Doctorate from Southern University School of Law and has been a licensed Louisiana attorney since1990.
David Randall “Randy” Gilchrist is the President and CEO of Gilchrist Construction Company (GCC), a central Louisiana-based infrastructure contractor specializing in road and bridge construction. He is 65 years old and became a member of the Boards in 2016. Mr. Gilchrist is a member of the Asset Management Committee and the Audit Committee.
Under Mr. Gilchrist’s leadership, GCC has grown since 1985 from a small site work contractor to one of Louisiana’s leading highway contractors. Mr. Gilchrist has served as President of Associated General Contractors, Chair of Driving Louisiana Forward, Chair of the Central Louisiana Chamber of Commerce, and vice chairman of Central Louisiana Economic Development Alliance. He has also served on the boards of the Rapides Foundation and Rapides Healthcare System.
Christopher Leslie is Executive Chairman of Macquarie Asset Management Real Assets Americas. Prior to taking that role in July 2016, Mr. Leslie was the CEO of Macquarie Infrastructure Partners Inc., which managed more than $7 billion in U.S. and Canadian infrastructure investments. Mr. Leslie is 60 years old and became a member of the Boards in 2016. He is a member of the Leadership Development and Compensation Committee. Mr. Leslie has been or is a director of a number of MAM portfolio companies in the energy, transportation, and communications sectors.
Mr. Leslie joined Macquarie in 1992 in Australia. He has been instrumental in expanding Macquarie’s infrastructure business globally, having launched Macquarie offices in Southeast Asia, India, and North America.
Mr. Leslie holds a Bachelor of Commerce degree from the University of Melbourne.
Jon Perry is a Director within the Infrastructure and Renewable Resources Department at BCI, where he is responsible for sourcing, executing and managing infrastructure investments. He is 48 years old and became a member of the Boards in 2018. Mr. Perry is the Chair of the Audit Committee.
Mr. Perry has over 15 years of experience in the utility and energy sectors. Prior to working with BCI, he held positions as Manager, Mergers and Acquisitions at TransAlta, a leading Canadian independent power producer and Manager, Regulatory and Financial Reporting at FortisAlberta, a
regulated distribution utility. Before then, Mr. Perry held financial and investor relations positions in Canadian junior and mid-cap oil and gas companies.
Mr. Perry holds a Bachelor of Medical Laboratory Sciences from the University of British Columbia. He is also a Chartered Accountant in the Province of Alberta and is a Chartered Financial Analyst charter holder.
Aaron Rubin is a Managing Director at MAM, where he is responsible for MAM’s North American power and utilities investment team. He is 47 years old and became a member of the Boards in 2018. Mr. Rubin is a member of the Business Planning and Budget Review Committee.
Since joining Macquarie in 2008, Mr. Rubin has had extensive responsibility for investment origination and execution as well as for management of portfolio investments. He has also served as the CEO of the Moscow-based Macquarie Russia & CIS Infrastructure Fund, and has been or is a director of a number of Macquarie portfolio companies in the energy, transportation, and communications sectors. Mr. Rubin is currently a director of the holding companies of Puget Energy, an electric and natural gas utility in Washington State, and Cyrq Energy, a leading U.S. geothermal power company. Prior to joining Macquarie, Mr. Rubin was a Vice President on JPMorgan’s North American mergers and acquisitions team.
Mr. Rubin holds a Bachelor of Commerce and a Bachelor of Laws degree from the University of Queensland.
Peggy Scott currently serves as the Chair of the Boards. In addition, she serves on Cleco’s Audit Committee and Governance and Public Affairs Committee. She served as Chairperson and Interim CEO of Cleco Holdings from February 9, 2017, through December 31, 2017. She is 73 years old and became a member of the Boards in 2016.
Ms. Scott serves on the boards of The Eastern Company (Nasdaq: EML) where she chairs the Environment, Health & Safety Committee and is a member of the Compensation Committee. She serves on the board and Governance Committee and is the Chair of the Audit Committee of Martin Sustainable Resources LLC. She previously served on the Blue Cross Foundation of Louisiana board from 2005 to 2024, and held positions of board chair and president. Her recent public company board service includes Benefytt Technologies, Inc. (BFYT) until its 2020 acquisition, and Gresham Smith Partners until June 2022. She also serves on the boards of various corporate and community organizations.
Presently, Ms. Scott is an adviser to growing companies in diverse industries. Previously, she served as the Executive Vice President, Chief Operating Officer, and CFO of Blue Cross Blue Shield of Louisiana (BCBS) and as Chief Strategy Officer. Prior to BCBS, Ms. Scott was an office Managing Partner with Deloitte and held senior executive positions in U.S. and International companies in seven countries where she led transformational growth and change.
Ms. Scott was named one of the ten Outstanding Young Women of America, featured in the Wall Street Journal as National Financial Executive of the year, and inducted into the American Institute of CPAs’ Hall of Fame. She is in the Louisiana State University’s Alumni Hall of Distinction, named a Tulane Outstanding Alumnus, and holds a Presidential citation.
Ms. Scott holds a Master of Business Administration from Tulane University and a Bachelor of Science degree in accounting from Louisiana State University. She is a CPA and
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certified in Valuations and Forensics and as a Master Professional Corporate Director.
Melissa Stark currently serves as the managing principal and owner of Co Issuer Corporate Staffing, LLC, which she established in 2003 to provide independent directors and officers for special purpose entities. She is 62 years old and was appointed in 2016 as a special independent manager of Cleco Power, whose sole purpose is to vote on any bankruptcy-related matters, as specified in Cleco Power’s Second Amended and Restated Operating Agreement.
Ms. Stark serves as a director of a number of companies in the financial sector. From 2001 to 2017, Ms. Stark concurrently served as a principal and co-founder of Water Tower Capital, LLC, a Chicago based investment advisory firm. From 1994 to 1996 she was Vice President - Fixed Income Research at Duff & Phelps (now known as Fitch) where she covered high yield bonds in the retail industry. She served as Vice President - Special Investments at PPM America, Inc. from 1991 to 1994.
Ms. Stark holds a Master of Business Administration in Finance from New York University Stern School of Business.
Steven Turner is a Managing Director within the Infrastructure and Renewable Resources Department at BCI, where he is responsible for sourcing, executing, and managing infrastructure investments. He is 52 years old and became a member of the Boards in 2016. Mr. Turner is the Chair of the Governance and Public Affairs Committee and a member of the Business Planning and Budget Review Committee and the Leadership Development and Compensation Committee.
Mr. Turner serves on the board of Nexus Water Group, a privately held waste/wastewater utility company. He is also a past director of Corix Infrastructure Inc., Macquarie Utilities Inc. and Aquarion Water Company.
Mr. Turner has over 20 years of experience in institutional investing. Prior to joining BCI, he held positions as an
Associate with Ventures West Management, a leading Canadian venture capital firm and as an Associate Equity Analyst with Raymond James Ltd., a full-service brokerage firm.
Mr. Turner has a Bachelor of Science degree in Environmental Engineering from Montana Tech of the University of Montana and holds a Master of Business Administration from the University of Victoria. He is also a registered Professional Engineer in the Province of British Columbia, a Chartered Financial Analyst charter holder and holds the ICD.D designation.
Bruce Wainer is the CEO of Wainer Enterprises, a family-owned commercial development company on Louisiana’s Northshore and in New Orleans. He is 65 years old and became a member of the Boards in 2016. Mr. Wainer is a member of the Business Planning and Budget Review Committee and the Governance and Public Affairs Committee.
Mr. Wainer is the developer of some of the most successful commercial developments in the New Orleans area and a past chairman of the Northshore Business Council. His business affiliations include partner at Wainer Brothers, All State Financial Company and Circle West Trailer Park Company; president of Quality Properties, Inc., Regent Lands, Inc., Flowers, Inc., Upside Down Cajun Brands, Inc., Louisiana Properties, Inc., Tamco, Inc., Riverhill, Inc., Metro Credit Services, Inc. and Pan American Investors, Inc., and manager of Advance Mortgage Company, LLC.
Executive Officers of Cleco
The names of the executive officers of Cleco and certain subsidiaries, their positions held, five-year employment history, and ages as of March 7, 2025, are as follows. Executive officers are appointed annually to serve for the ensuing year or until their successors have been appointed.
NAME OF EXECUTIVE POSITION AND FIVE-YEAR EMPLOYMENT HISTORY
William G. Fontenot
Cleco Holdings
Cleco Power
Cleco Cajun
President and CEO since January 2018.
CEO since February 2019.
CEO since February 2019.
(Age 62)
Kristin L. Guillory
Cleco Holdings
Cleco Power
Cleco Cajun
CFO since July 2021.
CFO since July 2021; President from September 2019 to July 2021.
(Age 42)
Mark D. Kleehammer
Cleco Holdings
General Counsel & Chief Regulatory Officer since July 2023; Vice President, Commercial and Industrial Journey and Products at Entergy Corporation from February 2023 to June 2023; Vice President, Regulatory and Public Affairs at Entergy Louisiana from October 2015 to February 2023,
(Age 56)
Sybil S. Montegut
Cleco Holdings
Support Group
Chief Administrative & Sustainability Officer since January 2024; Vice President Enterprise Analytics & Innovation from May 2020 to January 2024;
Director, Innovation & Transformation from March 2019 to May 2020.
(Age 47)
Justin S. Hilton
Cleco Power
Chief Commercial Officer since January 2024; President from February 2019 to January 2024.
(Age 55)
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NAME OF EXECUTIVE POSITION AND FIVE-YEAR EMPLOYMENT HISTORY
Robert A. Breedlove Cleco Holdings
Chief Operations Officer since January 2024; Vice President, Generation Operations from November 2021 to January 2024; Director, Fleet Maintenance Entergy Corporation from October 2018 to November 2021.
(Age 51)
Paul A. Guillory II
Cleco Power
Support Group
Chief Customer Officer since January 2024; Vice President & Chief Customer Officer from June 2021 to January 2024; Director, Meter, Bill & Revenue Collection from February 2020 to June 2021.
Manager, Business Consulting from December 2016 to February 2020
(Age 42)
Audit Committee
Cleco has a separately-designated standing Audit Committee. The members of Cleco’s Audit Committee are Dylan Arnould, Andrew Chapman, Randy Gilchrist, Jon Perry (who serves as Chair of the committee) and Peggy Scott. The Boards have determined that Andrew Chapman is the Audit Committee financial expert.
Code of Business Conduct & Ethics and Related Party Transactions
Cleco has adopted a Code of Conduct that applies to its principal executive officer, principal financial officer, principal accounting officer, and treasurer. Cleco also has adopted an Ethics Guide applicable to all employees and the Boards. In addition, the Boards have adopted Conflicts of Interest and Related Policies to prohibit certain conduct and to reflect the expectation of the Boards that their members engage in and promote honest and ethical conduct in carrying out their duties and responsibilities, including the ethical handling of actual or apparent conflicts of interest between personal and professional relationships and corporate opportunities. Under the Conflicts of Interest and Related Policies, Cleco considers transactions that are reportable under the SEC’s rules for transactions with related parties to be conflicts of interest and prohibits them. Any request, waiver, interpretation or other administration of the policy shall be referred to the Governance and Public Affairs Committee. Any recommendations by the Governance and Public Affairs Committee to implement a waiver shall be referred to the full Boards for a final determination. The Code of Conduct for Financial Managers, Ethics Guide, and Conflicts of Interest and Related Policies are posted on Cleco’s website at https://cleco.com/about/leadership-governance/codes-of-conduct. Each of these documents is also available free of charge by request sent to: Public Relations, Cleco, P.O. Box 5000, Pineville, LA 71361-5000.
Cleco has an insider trading policy governing the purchase and sale of, and certain other transactions involving, Cleco’s securities that applies to all of Cleco’s directors, officers, and other employees. Cleco believes its insider trading policy is reasonably designed to promote compliance with U.S. federal insider trading laws, rules, and regulations. A copy of Cleco’s insider trading policy is filed as Exhibit 19.1 to this Annual Report on Form 10-K.
Communications with the Boards
The Corporate Governance Guidelines provide for communications with the Boards by interested persons. In order for employees and other interested persons to make their concerns known to the Boards, Cleco has established a procedure for communications with the Boards through the Boards’ Chair. The procedure is intended to provide a method for confidential communication, while at the same time
protecting the privacy of the members of the Boards. Any interested person wishing to communicate with the Boards, or the non-management members of the Boards, may do so by addressing such communication as follows:
Chair of the Boards of Managers
c/o Corporate Secretary
Cleco Holdings
P.O. Box 5000
Pineville, LA 71361-5000
Upon receipt, Cleco’s Corporate Secretary will forward the communication, unopened, directly to the Chair of the Boards. The Chair will, upon review of the communication, make a determination as to whether it should be brought to the attention of the other non-management members and/or the management member of the Boards and whether any response should be made to the person sending the communication, unless the communication was made anonymously.
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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
Compensation Discussion and Analysis (CD&A)
This section provides information about the compensation program in place for the Company’s named executive officers who are included in the Summary Compensation Table. It includes a discussion and analysis of the overall objectives of its compensation program and each element of compensation the Company provides.
Executive Summary
Compensation Philosophy
The compensation principles and philosophy of the Committee are:
•Executives should be rewarded on performance, and incentives should align interests between management and the Company while considering prudent risk taking;
•Total remuneration (the sum of base salary, annual incentives, long-term incentives, and retirement benefits) is determined such that the combination of all pay elements
will deliver a total compensation opportunity comparable to that of the Company’s Peer Group.
•The mix of fixed compensation (base salary and retirement benefits) and variable/at-risk compensation (annual incentive and long-term incentive) should align with the market and are all paid in cash; and
•The competitive market for an executive’s compensation will be based on Comparator Group as adjusted for size and are not adjusted for Cleco’s privately held status or location.
Compensation Program Elements
The Committee targets total compensation (made up of the elements described below) to be competitive with the median of the Comparator Group adjusted for size, but individual positioning may vary above or below the median depending on each executive’s experience, performance, and contribution to the Company. For 2024, Cleco believes that it accomplished its philosophy through the following compensation and benefit components:
2024 PAY ELEMENT
DESCRIPTION
Base Salary • Fixed pay element
• Paid in cash
Annual Cash Incentive (STIP) • Performance-based annual incentive plan that pays out in cash
• Adjusted EBITDA is the largest single metric for the named executive officers
• Additional metrics include safety, system reliability, customer service, generation fleet availability, and milestone measures
Long-Term Incentives • Performance-based incentive paid in cash currently with a three-year cycle
• Payout is contingent on Average ROIC and Total Shareholder Return (TSR), each weighted at 50%
Benefits • Broad-based benefits such as group medical, dental, vision, and prescription drug coverage; basic life insurance; supplemental life insurance; dependent life insurance; accidental death and dismemberment insurance; a defined benefit pension plan (for those employees hired prior to August 1, 2007); and a 401(k) Plan with a Company match for those employees hired before August 1, 2007, as well as a 401(k) Plan with an enhanced benefit for those employees hired on or after August 1, 2007
Executive Benefits • SERP (closed to new participants in 2014 and currently only applicable to CEO)
• Nonqualified Deferred Compensation Plan
Perquisites
• Limited to executive physicals, spousal/companion travel, and relocation assistance
Roles and Responsibilities
Leadership Development and Compensation Committee
The Committee, which consists of one independent Board Manager and three investor Board Managers, is responsible for developing and overseeing the Company’s executive compensation program. The Committee met nine times during 2024.
Relating to executive compensation, the Committee’s responsibilities, which are more fully described in its charter, include:
•establishing and overseeing the Company’s executive compensation philosophy and goals ensuring no material adverse effect on the Company;
•engaging and evaluating an independent compensation consultant to analyze and recommend new or revised policies regarding executive compensation programs and practices;
•annually reporting to the Board or recommending for approval by the Board the overall design of the Company’s executive compensation and benefit programs;
•annually evaluating the performance of the CEO and the CFO and recommending to the Board adjustments in the CEO's and CFO’s compensation and benefits;
•overseeing the administrative committees and periodically reviewing the Company’s benefit plans, including retirement plans;
•reviewing and making recommendations for talent and succession planning and efforts to promote inclusion.
The Compensation Consultant
The Committee engaged Pay Governance to consult on matters concerning executive officers’ compensation and benefits. All executive compensation for 2024 was established by Pay Governance and reviewed by the Committee. Pay Governance acted at the direction of the Committee and was independent of management. Pay Governance was responsible for:
•recommending a group of peer companies to use for its market comparisons;
•reviewing the Company’s executive compensation program, including compensation relative to those executives at comparable companies, short- and long-term incentive targets and metrics, executive retirement benefits, and other executive benefits;
•reviewing the Company’s Board of Manager compensation program;
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•reporting on emerging trends and best practices in the area of executive and Board of Manager compensation; and
•attending the Committee meetings.
The Committee reviewed the compensation consultant’s qualifications as well as its independence and the potential for conflicts of interest. The Committee concluded that Pay Governance is independent, and its services to the Committee do not create any conflicts of interest. The Committee has the sole authority to approve Pay Governance’s compensation and determine the nature and scope of its services. Pay Governance does not perform any other services for or receive any other fees from the Company other than those relating to this Committee.
CEO
The CEO reviews with the Committee base salary adjustments, cash incentives, and long-term incentive awards for all executives other than himself.
Evaluation and Design of the Compensation and Benefit Programs
The Committee believes that compensation and benefits for executive officers who successfully enhance investors’ value should be competitive with the compensation and benefits offered by similar companies in the industry to attract and
retain the high quality executive talent required by the Company. The Committee examines executive officers’ compensation against comparable positions using publicly available proxy data for a group of 12 industry peers (Peer Group) and utility industry survey data to help design and benchmark executive officer compensation. This evaluation includes base salary, annual and long-term incentive plan targets, other potential awards, retirement benefits, and target total compensation. The Peer Group is used to track comparable performance of the long-term incentive plan. The combination of the Peer Group and the utility industry survey data is referred to as the “Comparator Group.”
The Peer Group changed in 2024. Three companies were removed and replaced with more appropriate comparators in order to size-adjust our Peer Group. Alliant Energy Corporation, Hawaiian Electric Industries, Inc., and Pinnacle West Capital Corporation were replaced with ITC Holdings, MGE Energy, Inc., and Unitil Corporation. The Committee will continue to evaluate the Peer Group annually as companies are often acquired, taken private, or grow at a rate that renders them inappropriate for comparison purposes. The Committee evaluates the Peer Group to ensure that peer companies are of similar scope in relation to revenues, assets, and employee count and have a good operational fit.
2024 PEER GROUP COMPANIES
ALLETE, Inc. ITC Holdings
Otter Tail Corporation
Avista Corp.
MGE Energy, Inc.
PNM Resources, Inc.
Black Hills Corporation
NorthWestern Corporation Portland General Electric Company
IdaCorp, Inc.
OGE Energy Corp. Unitil Corporation
In setting executive compensation levels in 2024, the Committee also used utility industry survey data from the most recent Willis Towers Watson Energy Services Executive Compensation Database and utilized regression analysis to establish executive compensation levels. Survey data provides a broader energy industry perspective. This survey data is used in conjunction with the Peer Group data as a competitive market reference point for the Committee to consider in determining pay levels.
Decisions Made in 2024 with Regard to Each Compensation and Benefit Component
Base Salary
The base salary levels for the executive officers as a group, including the named executive officers are set so that, in combination with other pay elements, it will deliver a total compensation opportunity comparable to that of the Company’s Peer Group. The Committee, and then the Board, sets the base salary level for the CEO and CFO. Other executive compensation is set by the CEO after consultation with the Committee.
Base salaries for the named executive officers in 2024 are shown in the table below:
NAME 2024 BASE SALARY
2024 % CHANGE
Mr. Fontenot $ 817,500 9.0 %
Ms. Guillory $ 470,004 5.6 %
Mr. Kleehammer
$ 449,996 5.9 %
Ms. Montegut
$ 325,025 29.5 %
Mr. Hilton (1)
$ 310,000 5.1 %
(1) Cleco Power employee.
Executive Annual Cash Incentive
The Company incentive compensation provides for the executive STIP, an annual, performance-based cash incentive plan. It includes weighting for corporate and individual performance goals. The STIP award opportunities for executive officers are set so that, in combination with other pay elements, it will deliver a total compensation opportunity comparable to that of the Company’s Peer Group. The Committee sets the annual cash incentive level for the CEO and CFO. The CEO establishes STIP levels for other remaining officers. Payouts for all officers are capped at 200% of target.
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The table below presents the target STIP opportunities for the named executive officers in 2024:
NAME TARGET AS %
OF BASE SALARY
Mr. Fontenot 125%
Ms. Guillory 65%
Mr. Kleehammer
60%
Ms. Montegut
50%
Mr. Hilton (1)
50%
(1) Cleco Power employee.
The 2024 STIP award for the named executive officers was based on the corporate and individual performance measures described below. These measures also apply to non-named executive officers.
The Committee included Milestone Measures (Measures) in the 2024 STIP corporate metrics for EMT and other corporate officers weighted at 20% and a stretch objective weighted at an additional 10%. These Measures were associated with progress milestones on key strategic corporate projects related to safety, cybersecurity, financial performance, regulatory objectives, customer satisfaction, completion of the Cleco Cajun divestiture, clean energy solutions, and Madison Unit 3 decarbonization efforts. For the STIP calculation, financial performance represents both the business unit and consolidated levels. Adjusted EBITDA represents net income before interest, income taxes, depreciation, and amortization adjusted for certain pension and SERP expenses, gains and losses on certain life insurance policies, certain merger and acquisition related expenses, variable lease revenue, unrealized gains and losses on derivatives, and other adjustments at the discretion of the Board of Managers. In addition, to continually focus the entire organization on the importance of safety, system reliability, generation fleet availability, sustainability, and to focus Cleco Power and Cleco Support executives and employees on customer satisfaction, the remainder of the STIP opportunity was attributable to related operational measures.
Management recommends the STIP financial and other performance measures to the Committee. Based on the historical performance relative to target and the relative historical performance versus the Peer Group, the Committee reviews, revises as appropriate, and approves the STIP measures for the upcoming year.
Details Related to Corporate Performance Metrics Established to Determine 2024 STIP Award Levels
Metric # 1: Adjusted EBITDA - Cleco Power - An adjusted EBITDA matrix was developed to determine performance and payout ranges related to respective Business Unit adjusted EBITDA performance in 2024. The overall STIP award for the corporate measures for executives is 30%. The final percentage of the financial target award is interpolated based on the performance level.
.
Metric # 2: Adjusted EBITDA Consolidated - An adjusted EBITDA matrix was developed to determine performance and payout ranges related to consolidated adjusted EBITDA performance in 2024. This measure represents 10% of the overall STIP award for the corporate measures for executives. The final percentage of the financial target award is interpolated based on the performance level.
Metric # 3: Safety - For the 2024 safety measure, the Company recognized serious injuries and fatalities (SIFs) by using the Serious Incident Injury Rate (SIIR), which represents 5% of the overall STIP award. The Company also included employee safety leading indicators by incorporating the Safety Observation Participation Rate, which represents 3% of the overall STIP award, and focused on improving contractor safety and awareness by Contractor Safety Observations, which represents 2% of the overall STIP award. These three measures total 10% for the safety metric. The target for SIIR was based on the average rates of the companies in the Southeastern Electric Exchange, of which Cleco is a member, over the five-year period of 2019-2023.
Metric # 4: EFORd - This metric represents the probability a generator will fail due to forced outages or derates when in demand. This metric is 6% of the overall STIP award for corporate measures. The 2024 target was based on the comparison to historical class average forced outage rates, as well as the MISO system-wide weighted average forced outage rate.
Metric # 5: Availability - This metric is an indicator of generation performance impacts related to unplanned outages and derates. This metric is 4% of the overall STIP award. The 2024 target was based on the average performance over the three-year period of 2021-2023 of Cleco Power’s fleet.
Metric # 6: Customer Satisfaction - The Company included Customer Satisfaction in its performance measures in 2024 using the JD Power South Midsize segment (JD Power study) for comparison. For the STIP metric, the Company uses a percentile-based target relative to the peer groups. The Company compared its overall performance against its peers in the JD Power study. This metric represents 10% of the overall STIP award.
Metric # 7: SAIDI - SAIDI measures the average amount of time a customer’s service is interrupted during the year measured in hours per customer per year, and excludes major events per the LPSC’s criteria. The 2024 SAIDI goal was based on the long-term goal of consistent performance improvement aligned with the LPSC target. This metric represents 10% of the overall STIP award for corporate measures.
Metric # 8: Milestone Measures - In addition to the above metrics, Cleco officers had the following STIP metric for 2024. This metric represents 20% of the overall STIP award for the corporate measures for executives and measures progress on certain strategic initiatives. These initiatives included safety, cybersecurity, financial performance, regulatory objectives, customer satisfaction, completion of the Cleco Cajun divestiture, clean energy solutions, and Madison Unit 3 decarbonization efforts. For 2024, executives were able to earn up to 10% in addition to the 20% target based on success of milestone measures. The Committee evaluated the performance of each initiative and determined the 2024 result for the Milestone Measures was 28.3%.
Total Payout for EMT: The calculated STIP payout for Cleco executives was 144.4% of target. The CEO targets differed from other officers such that the safety target was weighted 20% and the Power EBITDA target was weighted 20%. At their discretion, the Committee adjusted Mr. Fontenot’s payout to
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the level of other officers. The resulting total STIP corporate payout of 144.4% for 2024 was calculated as follows:
PERFORMANCE RANGE
METRIC
WEIGHT
THRESHOLD (50%)
TARGET (100%)
MAXIMUM (200%)
2024 RESULTS
PERCENTAGE PAYOUT
Adjusted EBITDA - Cleco Power
30 % $430.1M
$465.0M
$499.9M $497.6M 58.1 %
Adjusted EBITDA - Consolidated
10 % $478.0M
$525.3M
$577.3M $584.1M 20.0 %
Safety: Observation Participation
3 % <94.00 %
98.00 % 100.00 % 100.00 % 6.0 %
Safety: SIIR
5 % >0.292
0.207-0.123
<0.038
0.332 0.0 %
Safety: Contractor Safety Observation
2 % N/A
≥2,035
N/A 2,455 2.0 %
EFORd
6 % >9.38 % 5.11 %-7.24 % <2.96 %
7.24 % 6.0 %
Availability
4 % <66.56 %
75.91 %-85.27 % >94.64 %
79.87 % 4.0 %
Customer Satisfaction
10 % <25th Percentile
50th Percentile
≥90th Percentile
11th Percentile
0.0 %
SAIDI
10 % >2.87
2.59-2.73
<2.45 2.37 20.0 %
Milestones Measures (Stretch Included)
20 % 10 % 20 % 30 % 28.3 % 28.3 %
Resulting Total
100 % 144.4 %
The Committee also has the authority to adjust the amount of any individual STIP award upon recommendation by the CEO. Adjustments for the STIP participants, except for the named executive officers and other members of EMT, may be made by the CEO at his discretion. Adjustments are based on the annual performance of the respective officer.
Long-Term Compensation
In 2024, the Committee continued a cash-based LTIP and issued grants for the three-year cycle for the performance period ending December 31, 2024. The metrics for the LTIP cycle issued in 2024 are weighted 50% on the three-year average ROIC and 50% on TSR and are subject to a 200% maximum payout.
Each executive officer’s target LTIP award level is set annually, so in combination with other pay elements, it will deliver a total compensation opportunity comparable to that of the Company’s Peer Group. The chart below details the targeted opportunity for each of the named executives expressed as a percentage of base salary.
NAME TARGET AS %
OF BASE SALARY (1)
Mr. Fontenot 226 %
Ms. Guillory 120 %
Mr. Kleehammer (2)
110 %
Ms. Montegut
75 %
Mr. Hilton (3)
80 %
(1) Long-term incentives were adjusted to a level approximating +/-10% of the Comparator Group market median for total remuneration based on salary as of the March 28, 2024, grant date.
(2) Mr. Kleehammer was issued LTIP grants for cycles 2022-2024, and 2023-2025 at the above mentioned target percentage with a guaranteed minimum target payout.
(3) Cleco Power employee.
2022-2024 LTIP Award
The Leadership Development & Compensation Committee approved an overall award level of 173.8% of target for the LTIP three-year performance cycle that ended on December 31, 2024. This award level represents ROIC and TSR performance, each weighted at 50%, over the three-year period. This award will be paid in cash and is included in column E of the Summary Compensation Table for 2024.
Retirement Plans - Nonqualified Deferred Compensation Plan
The Company maintains a Deferred Compensation Plan so that members of the Boards, executive officers, and certain key
employees may defer receipt and taxation of certain forms of compensation. Members of the Boards may defer up to 100% of their compensation; executive officers and other key employees may defer up to 50% of their base salary and up to 100% of their annual cash incentive. The use of deferred compensation plans is prevalent within the industry and within the companies in the Peer Group. The Company does not match deferrals or contribute to the plan. Participation in the plan is voluntary. The allocation of deferrals among investment options is made by individual participants. The notional investment options include money market, fixed income, and equity funds. No changes were made to the plan during 2024.
Change in Employment Status and Change in Control Events
During 2024, the Company entered into no new employment agreements with current named executives other than the existing agreements with Mr. Fontenot as President and CEO and Mr. Kleehammer as General Counsel & Chief Regulatory Officer. The Company may enter into employment agreements with its executives generally in connection with recruiting efforts or as necessary to retain certain executives.
The Cleco Corporation Executive Severance Plan
In recognition of the non-renewal of executive employment contracts, the Cleco Corporation Board of Directors adopted the Cleco Corporation Executive Severance Plan (the Executive Severance Plan) on October 28, 2011. The Executive Severance Plan provides the executive officers and other key employees with cash severance benefits in the event of a termination of employment, including involuntary termination in connection with a change in control.
Perquisites and Other Benefits
The Company may make available the following perquisites to its executive officers:
•Executive officer physicals - as a condition of receiving their STIP award, Cleco requires and pays for an annual physical for the executive officers and their spouses;
•Spousal/companion travel - in connection with the various industry, governmental, civic, and entertainment activities of the executive officers, Cleco pays for spousal/companion travel associated with such events;
•Relocation program - in addition to the standard relocation policy available to all employees, Cleco maintains an executive relocation policy whereby the Company will pay
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reasonable and customary closing costs on a new home up to a maximum of 2% of the purchase price of said new home if purchased within one year of the relocation date; and
•Purchase program - under the Executive Severance Plan, if a change in control occurs, a covered executive officer may request the Company to purchase his/her primary residence within one year of the separation date (if the home is within 60 miles of the executive’s primary work location) and provided the executive officer relocates more than 100 miles from the residence to be purchased. The Executive Severance Plan provides details on limits of the purchase amount.
The Committee approves the perquisites based on what it believes is prevailing market practice, as well as specific Company needs. The Company believes the relocation program is an important element in attracting executive talent. Perquisite expenses related to business and spousal companion travel for the executive officers are reviewed by Internal Audit, and any exceptions are reported to the Audit Committee.
See the section titled “All Other Compensation” for details of these perquisites and their value for the named executive officers.
The executive officers, including the named executive officers, participate in the other benefit plans on the same terms as other employees. These plans include paid time off for vacation, sick leave, and bereavement; group medical, dental, vision, and prescription drug coverage (including the annual wellness program); basic life insurance; supplemental life insurance; dependent life insurance; accidental death and dismemberment insurance; defined benefit pension plan (for those hired prior to August 1, 2007); and the 401(k) Plan with a Company match for those employees hired before August 1, 2007, as well as a 401(k) Plan with an enhanced benefit for those employees hired on or after August 1, 2007.
Other Tools and Analyses to Support Compensation Decisions
Tally Sheets
The Committee conducts a review as part of the comparison of the compensation and benefit components that are prevalent within the Comparator Group. The comparison facilitates discussion with the Committee’s outside independent consultant as to the use and amount of each compensation and benefit component versus the applicable Peer Group.
•Annual compensation expense for each named executive officer - this includes the rate of change in total cash compensation from year-to-year; the annual periodic cost of providing retirement benefits; and the annual cost of providing other benefits such as health insurance, as well as the status of any deferred compensation.
•Reportable compensation - to further evaluate total compensation; to evaluate total compensation of the CEO compared to the other executive officers; and to otherwise evaluate internal equity among the named officers.
•Post-employment payments - reviewed pursuant to the potential separation events discussed in “Potential Payments at Termination or Change in Control.”
Trends and Regulatory Updates
As needed, and generally at least annually, the Committee reviews reports related to industry trends, legislative and
regulatory developments, and compliance requirements based on management’s analysis and guidance provided by Pay Governance, as applicable. Plan revisions and compensation program design changes are implemented as needed.
Risk Assessment
The Committee also seeks to structure compensation that will provide sufficient incentives for the executive officers to drive results while avoiding unnecessary or excessive risk taking that could harm the long-term value of the Company. The Committee believes that the following actions and/or measures help achieve this goal:
•the Committee reviews the design of the executive compensation program versus the Comparator Group to ensure an appropriate balance between business risk and resulting compensation;
•the Committee allocates pay mix between fixed and variable-based pay to provide a balance of incentives consistent with the median market;
•the design of the incentive measures is structured to align management’s actions with the interests of the stakeholders;
•incentive payments are dependent on the Company’s performance measured against pre-established targets and goals and/or compared to the performance of companies in the Peer Group;
•the range and sensitivity of potential payouts relative to target performance are reasonable;
•the Committee imposes checks and balances on the payment of compensation discussed herein;
•detailed processes establish the Company’s financial performance measures under its incentive plans; and
•incentive targets are designed to be challenging, yet achievable, to mitigate the potential for excessive risk-taking behaviors.
IRC Section 409A
IRC Section 409A generally was effective as of January 1, 2005. The section substantially modified the rules governing the taxation of nonqualified deferred compensation. The consequences of a violation of IRC Section 409A, unless corrected, are the immediate taxation of amounts deferred, the imposition of an excise tax and the assessment of interest on the amount of the income inclusion, each of which is imposed upon the recipient of the compensation. The plans, agreements and incentives subject to IRC Section 409A have been operated pursuant to and are in compliance with IRC Section 409A.
IRC Section 162(m)
IRC Section 162(m) limits to $1,000,000 the amount Cleco may deduct in a tax year for compensation paid to covered employees defined as the principal executive officer, principal financial officer (or anyone serving that role in a tax year), the next three highest compensated officers after the CEO and CFO, as well as any covered employees from prior years.
The Committee took actions considered appropriate to preserve the deductibility of compensation paid to executive officers, but the Committee did not adopt a formal policy that required all compensation to be fully deductible. As a result, the Committee may have paid or awarded compensation that it deemed necessary or appropriate to achieve business goals and to align the interests of executives with those of Cleco’s
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investors, whether or not the compensation was fully deductible under IRC Section 162(m).
Board Compensation
The Governance and Public Affairs Committee may engage the Committee’s independent consultant from time to time to
conduct market competitive reviews of the Board compensation program. Details of the Boards’ compensation are shown in the “Board of Manager Compensation” table.
Executive Officers’ Compensation
Summary Compensation Table
NAME AND PRINCIPAL POSITION YEAR SALARY($)
BONUS($) NON-EQUITY
INCENTIVE PLAN
COMPENSATION
($) CHANGE IN
PENSION
VALUE AND
NONQUALIFIED
DEFERRED
COMPENSATION
EARNINGS
($)(1)
ALL OTHER
COMPENSATION
($) TOTAL ($)
A B C D E F G H
William G. Fontenot, 2024
$ 809,712 $ 0 $ 4,416,130 $ 10,620 $ 25,762 $ 5,262,224
President & CEO 2023 $ 746,654 $ 0 $ 3,004,254 $ 527,167 $ 31,036 $ 4,309,111
2022 $ 721,000 $ 0 $ 1,888,467 $ 0 $ 26,709 $ 2,636,176
Kristin L. Guillory,
$ 467,119 $ 0 $ 1,251,822 $ 0 $ 16,260 $ 1,735,201
CFO 2023 $ 438,654 $ 0 $ 674,322 $ 101,468 $ 13,817 $ 1,228,261
2022 $ 389,231 $ 0 $ 403,162 $ 0 $ 14,440 $ 806,833
Mark D. Kleehammer, (2)
$ 447,112 $ 0 $ 1,249,893 $ 0 $ 27,974 $ 1,724,979
General Counsel & Chief Regulatory Officer
$ 212,500 $ 420,000 $ 754,712 $ 0 $ 33,779 $ 1,420,991
Sybil S. Montegut, (3)
$ 322,179 $ 0 $ 479,563 $ 0 $ 27,105 $ 828,847
Chief Administrative & Sustainability Officer
Justin S. Hilton, 2024
$ 308,269 $ 0 $ 684,010 $ 28,162 $ 15,080 $ 1,035,521
Chief Commercial Officer
2023 $ 295,000 $ 0 $ 438,335 $ 314,229 $ 16,135 $ 1,063,699
2022 $ 294,231 $ 0 $ 316,116 $ 0 $ 13,035 $ 623,382
(1) Amounts in this column include the change in pension value year over year. For 2024, this amount includes the change in pension value from 2023 to 2024. Negative changes in the pension value year over year are reported as $0.
(2) Mr. Kleehammer is classified as a named executive officer for 2023 and 2024 only.
(3) Ms. Montegut is classified as a named executive officer for 2024 only.
General
The Summary Compensation Table sets forth individual compensation information for the CEO, the CFO, and the three other most highly compensated executive officers of Cleco and its affiliates for services rendered in all capacities to Cleco and its affiliates during the fiscal years ended December 31, 2024, 2023, and 2022 (the “named executives” or “named executive officers”). Compensation components represent both payments made to the named executive officers during the year and other forms of compensation as follows:
•Column C, “Salary;” Column D, “Bonus;” Column E, “Non-Equity Incentive Plan Compensation;” and Column G, “All Other Compensation” represent cash compensation earned by the named executive in 2024, 2023, or 2022.
•The amounts shown in Column F, “Change in Pension Value and Nonqualified Deferred Compensation Earnings,” represent changes in the actuarial value of accrued benefits during 2024, 2023, and 2022 under the Pension Plan and SERP, as applicable. Actuarial value computations are based on assumptions discussed in Part II, Item 8, “Financial Statements and Supplementary Data - Notes to the Financial Statements - Note 11 - Pension Plan and Employee Benefits.” The 2024 changes shown in Column F are due in part to the actuarial impact of the discount rate change used to calculate future benefits under the Pension Plan and SERP. Negative changes, if any, are reported as
zero. This compensation will be payable to the named executive in future years, generally as post-employment retirement payments.
Salary
Data in Column C includes pay for time worked, as well as pay for time not worked, such as vacation, sick leave, jury duty, bereavement, and holidays. The salary level of each of the named executives is determined by a review of market data for companies comparable in size and scope to Cleco, as discussed under “- Compensation Discussion and Analysis - Decisions Made in 2024 with Regard to Each Compensation and Benefit Component - Base Salary.” In some instances, merit lump sum payments are used to recognize positive performance when base pay has reached or exceeded the Company’s base pay policy target, and are included in the salary column. Deferral of 2024, 2023, and 2022 base pay made by Mr. Fontenot, pursuant to the Deferred Compensation Plan, is included in the salary column and is further detailed in the “Nonqualified Deferred Compensation” table. Adjustments to base pay are recommended to the Committee typically on an annual basis, and if approved, usually are implemented in February. Base salary changes made in 2024 for named executives and the reasons for those changes are discussed in “- Compensation Discussion and Analysis - Decisions Made in 2024 with Regard to Each Compensation and Benefit Component - Base Salary.”
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Bonus
Column D, “Bonus” includes non-plan-based, discretionary incentives earned during 2024, 2023, or 2022.
Non-Equity Incentive Plan Compensation
Column E, “Non-Equity Incentive Plan Compensation” contains cash awards earned during 2024 that will be paid in March 2025 under the STIP; earned during 2023 and paid in March 2024 under the STIP; and earned during 2022 and paid in March 2023 under the STIP. Deferral of annual cash incentive payments made by Mr. Fontenot pursuant to the Deferred Compensation Plan is included in Column E and is further detailed in the “Nonqualified Deferred Compensation” table. Column E also includes cash awards earned during 2024 that will be paid in March 2025; earned during 2023 that were paid in March 2024, and earned during 2022 that were paid in March 2023 for the LTIP performance periods ended December 31, 2024, December 31, 2023, and December 31, 2022, respectively.
Change in Pension Value and Nonqualified Deferred Compensation Earnings
The values in Column F represent the aggregate increase in the actuarial present value of benefits earned by each named executive officer during 2024, 2023, and 2022 under the Pension Plan and SERP, including SERP’s supplemental death benefit provision. These values do not represent cash received by the named executives in 2024, 2023, and 2022; rather, these amounts represent the present value of future retirement payments Cleco projects will be made to each named executive. Changes in the present value of the Pension Plan and SERP benefits from December 31, 2023, to December 31, 2024; from December 31, 2022 to December 31, 2023; and from December 31, 2021, to December 31, 2022, result from an additional year of earned service, compensation changes and the increase (or decrease) in value caused by the change
in the discount rate used to compute present value. (Generally, a decrease in the discount rate will increase the present value of benefits and an increase in the discount rate will decrease the present value.) If the discount rate increases by a large enough amount, it can cause the accrued pension and SERP liability to decline versus the prior year. When this occurs, the values reported for Column F are zero.
The present value of the accumulated benefit obligation for each named executive officer is included in the table, “Pension Benefits.” These values are reviewed by the Committee.
Column F also would include any above-market or preferential earnings on deferred compensation paid by the Company. There were no such preferential earnings paid by the Company in 2024, 2023, and 2022.
All Other Compensation
Payments made to or on behalf of named executive officers in Column G, “All Other Compensation,” include the following:
•Contributions by Cleco under the 401(k) Plan on behalf of the named executive officers;
•Term life insurance premiums paid for the benefit of the named executive officers;
•Spousal travel;
•Certain corporate memberships;
•Unused vacation paid at separation or retirement;
•Severance;
•Relocation and home purchase program; and
•Federal Insurance Contributions Act (FICA) tax due currently and paid by the Company on the annual increase in the named executive officers’ future SERP benefits.
The value of the Column G items for 2024 for each named executive officer is as follows:
MR. FONTENOT MS. GUILLORY MR. KLEEHAMMER
MS. MONTEGUT
MR. HILTON
Cleco Contributions to 401(k) Plan $ 13,800 $ 16,171 $ 26,780 $ 25,538 $ 13,954
Taxable Group Term Life Insurance 1,411 67 859 187 859
Spousal Travel 939 22 335 1,380 267
Memberships 0 0 0 0 0
Unused vacation payout at retirement
0 0 0 0 0
Severance 0 0 0 0 0
Relocation and home purchase program
0 0 0 0 0
FICA Tax on SERP 9,612 0 0 0 0
Total Other Compensation $ 25,762 $ 16,260 $ 27,974 $ 27,105 $ 15,080
NAME GRANT DATE ESTIMATED FUTURE PAYMENTS
UNDER NON-EQUITY INCENTIVE
PLAN AWARDS (STIP)
ESTIMATED FUTURE PAYMENTS
UNDER NON-EQUITY INCENTIVE
PLAN AWARDS (2024-2026 LTIP GRANT)
THRESHOLD ($) TARGET ($) MAXIMUM ($) THRESHOLD ($) TARGET ($) MAXIMUM ($)
A B C D E F G H
Mr. Fontenot 01/01/24 $ 0 $ 1,012,140 $ 2,024,279 $ 0 $ 1,850,000 $ 3,700,000
Ms. Guillory 01/01/24 $ 0 $ 303,627 $ 607,255 $ 0 $ 564,005 $ 1,128,010
Mr. Kleehammer
01/01/24 $ 0 $ 268,267 $ 536,534 $ 0 $ 494,996 $ 989,992
Ms. Montegut
01/01/24 $ 0 $ 161,089 $ 322,179 $ 0 $ 243,769 $ 487,538
Mr. Hilton 01/01/24 $ 0 $ 154,135 $ 308,269 $ 0 $ 248,000 $ 496,000
General
The target values for each of the Company’s incentive plans - the STIP and the LTIP - are determined as part of the Committee’s review of executive officer compensation. The Committee’s review, supported by data prepared by Pay
Governance, includes comparisons of base salary and annual and long-term incentive levels of Cleco executive officers versus the Comparator Group as detailed in “- Compensation Discussion and Analysis - Evaluation and Design of the Compensation and Benefit Programs.” Targets for both the
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STIP and the LTIP are set as a percentage of base salary and stated in their dollar equivalent in the table above.
Estimated Future Payments under Non-Equity Incentive Plan Awards (STIP)
See “- Compensation Discussion and Analysis - Decisions Made in 2024 with Regard to Each Compensation and Benefit Component - Executive Annual Cash Incentive” for a discussion of 2024 STIP award calculations.
Estimated Future Payments under Non-Equity Incentive Plan Awards (LTIP)
See “- Compensation Discussion and Analysis - Decisions Made in 2024 with Regard to Each Compensation and Benefit Component - Long-Term Compensation” for a discussion of grants made in 2024.
Pension Benefits
NAME
PLAN NAME (s) NUMBER OF
YEARS OF
CREDITED
SERVICE (#) PRESENT
VALUE OF
ACCUMULATED
BENEFIT ($) PAYMENTS
DURING LAST
FISCAL YEAR ($)
Mr. Fontenot Cleco Corporate Holdings LLC Pension Plan 38
$ 2,157,813 $ 0
Cleco Corporation SERP 38
$ 3,680,915 $ 0
Ms. Guillory (1)
Cleco Corporate Holdings LLC Pension Plan 20
$ 460,538 $ 0
Cleco Corporation SERP 0 $ 0 $ 0
Mr. Kleehammer (2)
Cleco Corporate Holdings LLC Pension Plan 0
$ 0 $ 0
Cleco Corporation SERP 0
$ 0 $ 0
Ms. Montegut (3)
Cleco Corporate Holdings LLC Pension Plan 0
$ 0 $ 0
Cleco Corporation SERP 0
$ 0 $ 0
Mr. Hilton (4)
Cleco Corporate Holdings LLC Pension Plan 35
$ 1,640,950 $ 0
Cleco Corporation SERP 0 $ 0 $ 0
(1) Ms. Guillory is not a participant in SERP as her appointment to her current position was after the plan was closed to new participants.
(2) Mr. Kleehammer is not a participant in the Pension Plan or SERP as he was hired after both plans were closed to new participants.
(3) Ms. Montegut is not a participant in the Pension Plan or SERP as her appointment to her current position was after both plans were closed to new participants.
(4) Mr. Hilton is not a participant in SERP as his appointment to his current position was after the plan was closed to new participants.
General
The Company provides executive officers who meet certain tenure requirements, benefits from the Pension Plan and SERP. Vesting in the Pension Plan requires five years of service with the Company. Mr. Fontenot, Ms. Guillory, and Mr. Hilton are fully vested in the Pension Plan. Mr. Kleehammer and Ms. Montegut, having been hired after August 1, 2007, were not eligible to participate in the Pension Plan and were included in an enhanced 401(k) Plan for those employees hired on or after August 1, 2007.
The “Pension Benefits” table lists the present value of accumulated SERP benefits for the named executive officers as of December 31, 2024. Mr. Fontenot is the only officer with a SERP benefit and is fully vested based on years of service.
The present value of each of the named executive officer’s accumulated benefit values was actuarially calculated and represents the values as of December 31, 2024. These calculations were made using the projected unit credit method for valuation purposes and a discount rate of 5.66%. Other material assumptions relating to the valuation include use of the Pri-2012 Employee and Healthy Retiree gender distinct mortality tables projected generationally using Scale MP-2020 (using White Collar for SERP present values and no collar for Qualified Plan present values), assumed retirement at age 65 and retirement payments in the form of joint and 100% survivor with 10 years certain payment.
The sum of the change in actuarial value of the Pension Plan during 2024 and the change in value of SERP is included in Column F, “Change in Pension Value and Nonqualified Deferred Compensation Earnings,” in the Summary Compensation Table. Negative changes, if any, are reported as zero.
Pension Plan
The Cleco Corporate Holdings LLC Pension Plan, restated effective September 1, 2020, is a defined benefit plan funded
entirely by employer contributions. Effective August 1, 2007, the Pension Plan was closed to new participants. Employees hired or rehired on or after August 1, 2007 are eligible to participate in an enhanced 401(k) Plan. Mr. Fontenot, Ms. Guillory, and Mr. Hilton were hired prior to August 1, 2007.
Benefits under the Pension Plan are determined by years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last ten years of employment. Earnings include base pay, cash incentives, merit lump sums, imputed income with respect to life insurance premiums paid by the Company, pre-tax contributions to the 401(k) Plan, salary and bonus deferrals to the Deferred Compensation Plan, and any other form of payment taxable under IRC Section 3401(a). Earnings exclude reimbursement of expenses, gifts, severance pay, moving expenses, outplacement assistance, relocation allowances, welfare benefits, benefits accrued (other than salary and bonus deferrals) or paid pursuant to the Deferred Compensation Plan, and the value of benefits accrued or paid under the LTIP. For 2024, the amount of earnings was further limited to $345,000 as prescribed by the IRS.
The formula for calculating the defined benefit under the Pension Plan is as follows:
1. Defined Benefit = Annual Benefit + Supplement Benefit
2. Annual Benefit = Final Average Earnings × Years of Service × Pension Factor
3. Supplement Benefit = (Final Average Earnings - Social Security Covered Compensation) × Years of Service × .0065
The applicable pension factor for 2024 was 1.25%. Based on the benefit formula, the pension factor will remain at 1.25% in future years. Social Security-covered income is prescribed by the IRS based on the year of birth.
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Benefits from the Pension Plan are generally paid at normal, late or early retirement dates and are subject to a limit prescribed by the IRS, generally $275,000 in 2024. Normal retirement at age 65 entitles the participant to a full pension. A participant may elect to delay retirement past age 65 as long as he/she is actively employed. Years of service continue to accumulate (up to a maximum of 35) and earnings continue to count toward the final earnings calculation. If a participant chooses to retire after age 55 but before normal retirement age, the amount of the annual pension benefit is reduced by 3% per year between ages 55 and 62. For example, the normal pension benefit at age 55 is reduced by 21%.
SERP
SERP is designed to provide retirement income for certain executive officers. In July 2014, Cleco Corporation’s Board of Directors closed SERP to new participants. In December 2017, the Company entered into an employment agreement with Mr. Fontenot as its CEO, the terms of which amended the calculation of Mr. Fontenot’s SERP benefit to include a fixed benefit depending upon the year Mr. Fontenot separates from the Company.
SERP provides survivor benefits, which are payable to a participant’s surviving spouse or other beneficiary. SERP also contains a supplemental death benefit that was added in 1999 to reflect market practice. If a SERP participant dies while actively employed, the amount of the supplemental death benefit is equal to the sum of two times the participant’s annual
base salary as of the date of death and the participant’s target bonus payable under the annual incentive plan for the year in which death occurs. If a participant dies after termination of employment, the supplemental benefit is equal to the sum of the participant’s final annual base salary and target bonus payable under the annual incentive plan for the year in which the participant retired or otherwise terminated employment. The supplemental death benefit is not dependent on years of service.
Estimated Annual Payments
The following table shows the estimated annual payments at age 55 (or actual attained age if greater than 55) to each of the named executives under the Pension Plan and SERP as of December 31, 2024.
ESTIMATED PAYMENTS AT 55
(OR ACTUAL ATTAINED AGE IF GREATER THAN 55)
PENSION SERP TOTAL
Mr. Fontenot (1)
$ 152,050 $ 212,950 $ 365,000
Ms. Guillory
$ 69,278 $ 0 $ 69,278
Mr. Kleehammer (2)
$ 0 $ 0 $ 0
Ms. Montegut (2)
$ 0 $ 0 $ 0
Mr. Hilton
$ 123,133 $ 0 $ 123,133
(1) Mr. Fontenot is the only named executive officer with a SERP benefit.
(2) Neither Mr. Kleehammer nor Ms. Montegut participate in the Pension Plan, as they were hired after August 1, 2007.
Nonqualified Deferred Compensation
NAME
EXECUTIVE OFFICER
CONTRIBUTIONS IN
2024 ($)(1)
COMPANY CONTRIBUTIONS IN
2024 ($)
AGGREGATE
EARNINGS IN
2024 ($) (2)
AGGREGATE
WITHDRAWALS/
DISTRIBUTIONS IN
2024 ($)
AGGREGATE
BALANCE AT
DECEMBER 31,
2024 ($)(3)
A B C D E F
Mr. Fontenot $ 499,964 $ 0 $ 698,024 $ 0 $ 5,221,343
Ms. Guillory $ 0 $ 0 $ 0 $ 0 $ 0
Mr. Kleehammer
$ 0 $ 0 $ 0 $ 0 $ 0
Ms. Montegut
$ 0 $ 0 $ 0 $ 0 $ 0
Mr. Hilton $ 0 $ 0 $ 0 $ 0 $ 0
(1) The amounts in Column B represent deferrals of salary and non-equity incentive compensation payments made to the named executive officers during 2024 and are included in the amounts shown in Columns C and E, respectively, of the Summary Compensation Table.
(2) The aggregate earnings shown in Column D are not included in the Summary Compensation Table. Negative returns are reflected as zero.
(3) The aggregate balances shown in Column F include amounts reported as salary and non-equity incentive compensation payments in the Summary Compensation Table for the current fiscal year, as well as previous years and the earnings on those amounts.
Deferred Compensation
Named executives and other key employees are eligible to participate in the Company’s Deferred Compensation Plan. Participants are allowed to defer up to 50% of their base salary and up to 100% of their annual cash incentive, as reported in Columns C and E in the Summary Compensation Table. Consequently, the executive officer contributions listed in Column B above are made by the participant and not by Cleco. Mr. Fontenot elected to participate in the Deferred Compensation Plan during 2024. All deferral elections for 2024 were made prior to the beginning of 2024 as required by the regulations under IRC Section 409A. There are no matching contributions made by the Company.
Deferrals become general funds for use by the Company to be repaid to the participant at a pre-specified date. Short-term deferrals may be paid out as early as five years following the end of the plan year (i.e., the year in which compensation was earned). Retirement deferrals are paid at the later of termination of service or the attainment of an age specified by the participant. A bookkeeping account is maintained for each
participant that records deferred salary and/or bonus, as well as earnings on deferred amounts. Earnings are determined by the performance of notional investment alternatives. Participants select which of these alternatives will be used to determine the earnings on their own accounts. The Deferred Compensation Plan is not intended to provide for the payment of above-market or preferential earnings (as these terms are defined under the SEC regulations) on compensation deferred under the plan. As such, the Deferred Compensation Plan does not provide a guaranteed rate of return.
Potential Payments at Termination or Change in Control
The following tables, “Potential Payments at Termination or Change in Control,” detail the estimated value of payments and benefits provided to each named executive officer assuming the following separation events occurred as of December 31, 2024: termination by the executive; disability; death; retirement; constructive termination; termination by the Company for cause; and termination in connection with a
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change in control. The Company has selected these events based on long-standing provisions in employee benefit plans, such as the Pension Plan and 401(k) Plan, or because the use is common within the industry and Comparator Group. Some of the potential severance payments are governed by the separate documents establishing the STIP, LTIP, and SERP.
At its October 2011 meeting, Cleco Corporation’s Compensation Committee approved the Executive Severance Plan to provide severance benefits to executive officers. In October and December 2014, July 2015, and May 2021, Cleco Corporation’s Compensation Committee approved amendments to the Executive Severance Plan. At December 31, 2024, all of the named executive officers were covered by the Executive Severance Plan.
The following narrative describes the type and form of payments and benefits for each separation event. The tables under “Potential Payments at Termination or Change in Control” provide an estimate of potential payments and benefits to each named executive officer under each separation event. Throughout this section, reference to “executive officers” is inclusive of named executive officers.
Termination by the Executive
If an executive officer resigns voluntarily, no payments are made or benefits provided other than those required by law.
Disability
Annual disability benefits are payable when a total and permanent disability occurs and are paid until the executive officer’s normal retirement age, which is age 65. This benefit is provided under SERP, if applicable, and is paid regardless of whether the executive was vested in SERP at the time of disability. At age 65, a disabled executive is eligible to receive annual retirement benefits under the Pension Plan, for those who are participants, and SERP as outlined under the headings “Pension Plan” and “SERP,” respectively. The executive officer also is eligible to receive a one-time, prorated share of the current year’s STIP award and a prorated award for each LTIP performance cycle in which he/she participates to the extent those performance cycles award at their completion.
Death
A prorated share of the current year’s STIP award and a supplemental death benefit provided from SERP, if applicable, are paid to an executive officer’s designated beneficiary in the event of death in service. Both are one-time payments. The executive officer’s designated beneficiary is also eligible to receive a prorated award for each LTIP performance cycle in which the executive officer participates, to the extent those performance cycles award at their completion.
Annual survivor benefits are payable to an executive officer’s surviving spouse for his/her life, or if there is no surviving spouse, to the executive officer’s designated beneficiary for a period of ten years or, if no designated beneficiary is named, to the executive officer’s estate for a period of ten years. Amounts are calculated under the provisions of the Pension Plan and SERP. For more information, see the discussion under the headings “Pension Plan” and “SERP,” respectively, as well as SERP provisions relating to death while in service.
Retirement
In the event of early or normal retirement, the executive officer is eligible to receive a prorated share of the current year’s STIP award and at least a prorated award for each LTIP performance cycle in which he/she participates to the extent those performance cycles award at their completion. Retirement benefits are provided pursuant to the Pension Plan and SERP. Payments are made monthly and are calculated using the assumptions described in the discussion following the “Pension Benefits” table.
Constructive Termination
Payments made and benefits provided upon a constructive termination are ordinarily greater than payments made on account of an executive officer’s retirement, death or disability because separation effectively is initiated by the Company. Certain payments are made contingent upon the execution of a waiver, release and covenants agreement in favor of the Company. Constructive termination also may be initiated by an executive officer if there has been (i) a material reduction in his/her base compensation, other than a reduction uniformly applicable to all executive officers; and (ii) a contemporaneous, material reduction in his/her authority, job duties, or responsibilities.
Under the terms of the Executive Severance Plan, an executive would receive constructive termination payments including up to 52 weeks of base compensation, up to $50,000 in lieu of outplacement services and reimbursement of premiums paid to maintain coverage under Cleco’s medical plan for up to 18 months. The executive also would be eligible for a prorated portion of the current year’s payout under the STIP and a prorated award for the LTIP performance cycles in which he/she participates, to the extent those performance cycles award at their completion.
If the executive officer has vested retirement benefits and has attained eligible retirement age, he/she would receive retirement benefits as described under “Pension Benefits.”
Termination for Cause
“Cause” is defined as an executive’s (i) intentional act of fraud, embezzlement or theft in the course of employment or other intentional misconduct that is materially injurious to the Company’s financial condition or business reputation; (ii) intentional damage to Company property, including the wrongful disclosure of its confidential information; (iii) willful and intentional refusal to perform the essential duties of his/her position; (iv) failure to fully cooperate with government or independent agency investigations; (v) conviction of a felony or crime involving moral turpitude; (vi) willful, reckless, or negligent violation of the material provisions of Cleco’s Code of Conduct; or (vii) reckless or intentional acts or failures to act in a manner which materially compromises his/her ability to perform the essential duties of his/her position; or (viii) willful, reckless, or negligent violation of rules related to the LTIP or rules adopted by the SEC. No payments, other than those required by law, are made or benefits provided under the Executive Severance Plan if an executive officer is terminated for cause. If an executive officer is vested in SERP, that benefit is forfeited. The value of that forfeiture is shown as a negative number in the separation payments tables.
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Change in Control
The term “Change in Control” is defined in the LTIP. One or more of the following triggering events constitute a Change in Control:
•Any “person” (as such term is used in Sections 13(d) and 14(d) of the Exchange Act), other than the Company or an Affiliate or any “person” who on the effective date of this Plan is a director, officer, or is the “beneficial owner” (as determined in Rule 13d-3 promulgated under the Exchange Act) of 20% or more of the combined voting power of outstanding securities of the Company or an employee stock ownership plan (within the meaning of Code Section 4975(e)(7)) sponsored by the Company or an Affiliate, is or becomes the “beneficial owner” (as determined in Rule 13d-3 promulgated under the Exchange Act) of 80% or more of the combined voting power of the outstanding securities of the Company;
•The Company is party to a merger or consolidation with another entity and, as a result of such transaction, 80% or more of the combined voting power of outstanding securities of the Company or its successor in the merger (or a direct or indirect parent company of the Company or its successor in the merger) is owned in the aggregate by persons who were not “beneficial owners” (as determined in Rule 13d-3 promulgated under the Exchange Act) of securities of the Company immediately before such transaction;
•The Company sells, leases, or otherwise disposes of, in one transaction or in a series of related transactions, all or substantially all of its assets;
•The owners of the Company approve a plan of dissolution or liquidation; or
•All or substantially all of the assets or the issued and outstanding membership interests of Cleco Power LLC is sold, leased or otherwise disposed of in one or a series of related transactions to a person, other than the Company or an Affiliate.
Except as described below, payments are made and benefits provided only if an executive’s employment is terminated during the 60-day period preceding or the 24-month period following the Change in Control.
Termination must be involuntary and by the Company without cause or initiated by the executive on account of “Good Reason.” Good reason means that (i) a Participant’s base compensation in effect immediately before the commencement of a Change in Control Period is materially reduced, or there is a material reduction or termination of such Participant’s rights to any employee benefit in effect immediately prior to such period; (ii) a Participant’s authority, duties or responsibilities are materially reduced from those in effect immediately before the commencement of a Change in Control Period, or such Participant has reasonably determined that, as a result of a change in circumstances that materially affects his or her employment with the Company, he or she is unable to exercise the authority, power, duties and responsibilities assigned to him or her immediately before the
commencement of such period; or (iii) a Participant is required to transfer to an office or business location that is more than 60 miles from the primary location to which he or she was assigned prior to the commencement of a Change in Control Period. No event or condition shall constitute Good Reason hereunder unless (a) a Participant provides to the Committee written notice of his or her objection to such event not later than 60 days after such Participant first learns, or should have learned, of such event; (b) such event is not corrected by the Company promptly after receipt of such notice, but in no event more than 30 days after receipt thereof; and (c) such Participant Separates from Service not more than 15 days following the expiration of the 30-day period described in clause (b) hereof. The executive also must satisfy the conditions included in the waiver, release and covenants agreement defined in the Executive Severance Plan.
Under the Executive Severance Plan, an executive would receive an amount up to two times the sum of annualized base salary and the average non-equity incentive plan bonus over the last three fiscal years and reimbursement of COBRA premiums for up to 24 months. Payments may also include the purchase of the executive officer’s primary residence and reimbursement of relocation expenses, but only if the executive relocates his/her primary residence more than 100 miles. No excise tax payments or gross-ups are made; instead, benefits will be reduced in lieu of the imposition of the tax. The numbers shown below do not give effect to this reduction.
Subject to the conditions described above, upon a Change in Control, SERP benefits are: (i) fully vested; (ii) increased by adding three years to an affected executive’s age, subject to a minimum benefit of 50% of compensation; and (iii) subject to a modified actuarial reduction determined by increasing the executive’s age by three years.
If an executive officer is vested and of eligible retirement age, he or she may become eligible to begin to receive the annual retirement benefit described above upon a Change in Control.
The following tables set forth the value of post-employment payments and benefits that are not generally made available to all employees. Each separation event is assumed to occur on December 31, 2024. Retirement is assumed to occur at age 55 or the named executive officer’s actual attained age if greater than 55. Estimated payments under the LTIP and LTIP for disability, death, retirement and constructive termination are uncertain until the completion of the performance period/cycle. In the case of the LTIP, the performance period is the current fiscal year. The estimated payment for the home purchase and relocation is a projection of the expense to the Company to sell the named executive officer’s principal residence including any loss avoided by the named executive officer by having the right to sell the residence to the Company, plus the projected cost to the Company to relocate the named executive officer.
Pursuant to Item 401(j) of Regulation S-K, the separation events disclosed in this Annual Report on Form 10-K are assumed to occur in the past, as of December 31, 2024.
CLECO
CLECO POWER 2024 FORM 10-K
Mr. Fontenot
VALUE OF PAYMENT/BENEFIT TERMINATION
BY EXECUTIVE DISABILITY DEATH RETIREMENT CONSTRUCTIVE
TERMINATION TERMINATION
FOR CAUSE CHANGE IN
CONTROL
Cash Severance $ 0 $ 0 $ 0 $ 0 $ 817,500 $ 0 $ 3,332,434
Annual Cash Bonus 0 1,461,530 1,461,530 1,461,530 1,461,530 0 0
Long-Term Incentive 0 4,990,600 4,990,600 4,990,600 4,990,600 0 5,679,000
Cash Payment in Lieu of Outplacement Services 0 0 0 0 50,000 0 0
Present Value of Incremental SERP Payments(1)
0 3,599,744 7,508,097 3,124,374 3,124,374 (3,124,374) 4,406,059
SERP Supplemental Death Benefit 0 0 2,656,875 0 0 0 0
Purchase of Principal Residence/Relocation
0 0 0 0 0 0 83,500
COBRA Medical Coverage
0 0 0 0 32,247 0 42,996
Total Incremental Value $ 0 $ 10,051,874 $ 16,617,102 $ 9,576,504 $ 10,476,251 $ (3,124,374) $ 13,543,989
(1) As of December 31, 2024, Mr. Fontenot was vested in SERP payments, which would be forfeited upon termination for cause.
Ms. Guillory
VALUE OF PAYMENT/BENEFIT TERMINATION
BY EXECUTIVE DISABILITY DEATH RETIREMENT (1)
CONSTRUCTIVE
TERMINATION TERMINATION
FOR CAUSE CHANGE IN
CONTROL
Cash Severance $ 0 $ 0 $ 0 $ 0 $ 470,004 $ 0 $ 1,442,285
Annual Cash Bonus 0 438,438 438,438 0 438,438 0 0
Long-Term Incentive
0 1,406,959 1,406,959 0 1,406,959 0 1,640,365
Cash Payment in Lieu of Outplacement Services
0 0 0 0 25,000 0 0
Present Value of Incremental SERP Payments 0 0 0 0 0 0 0
SERP Supplemental Death Benefit 0 0 0 0 0 0 0
Purchase of Principal Residence/Relocation Expenses 0 0 0 0 0 0 83,500
COBRA Medical Coverage 0 0 0 0 32,247 0 42,996
Total Incremental Value $ 0 $ 1,845,397 $ 1,845,397 $ 0 $ 2,372,648 $ 0 $ 3,209,146
(1) As of December 31, 2024, Ms. Guillory was not eligible for retirement.
Mr. Kleehammer
VALUE OF PAYMENT/BENEFIT TERMINATION
BY EXECUTIVE DISABILITY DEATH RETIREMENT (1)
CONSTRUCTIVE
TERMINATION TERMINATION
FOR CAUSE CHANGE IN
CONTROL
Cash Severance $ 0 $ 0 $ 0 $ 0 $ 449,996 $ 0 $ 1,385,590
Annual Cash Bonus 0 437,378 437,378 0 437,378 0 0
Long-Term Incentive
0 1,289,180 1,289,180 0 1,289,180 0 1,429,996
Cash Payment in Lieu of Outplacement Services
0 0 0 0 25,000 0 0
Present Value of Incremental SERP Payments
0 0 0 0 0 0 0
SERP Supplemental Death Benefit 0 0 0 0 0 0 0
Purchase of Principal Residence/Relocation Expenses
0 0 0 0 0 0 83,500
COBRA Medical Coverage 0 0 0 0 29,447 0 39,263
Total Incremental Value $ 0 $ 1,726,558 $ 1,726,558 $ 0 $ 2,231,001 $ 0 $ 2,938,349
(1) As of December 31, 2024, Mr. Kleehammer was not eligible for retirement due to his years of service.
Ms. Montegut
VALUE OF PAYMENT/BENEFIT TERMINATION
BY EXECUTIVE DISABILITY DEATH RETIREMENT (1)
CONSTRUCTIVE
TERMINATION TERMINATION
FOR CAUSE CHANGE IN
CONTROL
Cash Severance $ 0 $ 0 $ 0 $ 0 $ 325,025 $ 0 $ 840,163
Annual Cash Bonus 0 232,614 232,614 0 232,614 0 0
Long-Term Incentive
0 450,454 450,454 0 450,454 0 569,230
Cash Payment in Lieu of Outplacement Services
0 0 0 0 25,000 0 0
Present Value of Incremental SERP Payments
0 0 0 0 0 0 0
SERP Supplemental Death Benefit 0 0 0 0 0 0 0
Purchase of Principal Residence/Relocation Expenses
0 0 0 0 0 0 83,500
COBRA Medical Coverage 0 0 0 0 20,967 0 27,956
Total Incremental Value $ 0 $ 683,068 $ 683,068 $ 0 $ 1,054,060 $ 0 $ 1,520,849
(1) As of December 31, 2024, Ms. Montegut was not eligible for retirement.
CLECO
CLECO POWER 2024 FORM 10-K
Mr. Hilton
VALUE OF PAYMENT/BENEFIT TERMINATION
BY EXECUTIVE DISABILITY DEATH RETIREMENT
CONSTRUCTIVE
TERMINATION TERMINATION
FOR CAUSE CHANGE IN
CONTROL
Cash Severance $ 0 $ 0 $ 0 $ 0 $ 310,000 $ 0 $ 856,907
Annual Cash Bonus 0 222,571 222,571 222,571 222,571 0 0
Long-Term Incentive
0 773,539 773,539 773,539 773,539 0 857,150
Cash Payment in Lieu of Outplacement Services
0 0 0 0 25,000 0 0
Present Value of Incremental SERP Payments 0 0 0 0 0 0 0
SERP Supplemental Death Benefit 0 0 0 0 0 0 0
Purchase of Principal Residence/Relocation Expenses
0 0 0 0 0 0 83,500
COBRA Medical Coverage 0 0 0 0 32,247 0 42,996
Total Incremental Value $ 0 $ 996,110 $ 996,110 $ 996,110 $ 1,363,357 $ 0 $ 1,840,553
BOARD OF MANAGERS COMPENSATION
2024 Board of Managers Compensation
NAME (1)
FEES EARNED
OR PAID IN
CASH ($) TOTAL ($)
A B C
Rick Gallot
$ 170,000 $ 170,000
Randy Gilchrist $ 170,000 $ 170,000
Peggy Scott $ 265,000 $ 265,000
Melissa Stark $ 3,750 $ 3,750
Bruce Wainer $ 170,000 $ 170,000
(1)Messrs. Arnould, Chapman, Fronimos, Leslie, Perry, Rubin, and Turner were appointed to the Boards by the Owner Group and do not receive additional compensation for their service on the Boards.
General
Column B, “Fees Earned or Paid in Cash” represents cash compensation earned and/or received in 2024.
A non-management Board Manager may elect to participate in the Company’s Deferred Compensation Plan and defer the receipt of all or part of his or her fees. Benefits are equal to the amount credited to each Board Manager’s individual account based on compensation deferred plus applicable investment returns as specified by the director upon election to participate in the plan. Investment options are similar to those provided to participants in the 401(k) Plan. Funds may be reallocated between investments at the discretion of the Board Manager. Accounts, which may be designated separately by deferral year, are payable in the form of a single-sum payment or in the form of substantially equal annual installments, not to exceed 15, when a Board Manager ceases to serve on the Cleco’s Boards or attains a specified age.
Fees Earned or Paid in Cash
During 2024, each Board Manager who is not a Cleco employee or appointed by the Owner Group, except Ms. Stark, received an annual cash retainer of $170,000. Ms. Stark received an annual cash retainer of $3,750. During this period, the non-management Chair was compensated with an additional retainer of $95,000.
Board Managers are permitted to defer receipt of their fees under the Company’s Deferred Compensation Plan. Messrs. Gallot and Gilchrist elected to defer all or a portion of their fees in 2024.
Cleco reimburses Board Managers for travel and related expenses incurred for attending meetings of Cleco’s Boards and Board committees, including travel costs for spouses/companions. There were no Board Manager spousal expenses during 2024.
Cleco also provides its Board Managers who are not employed by Cleco or appointed by the Owner Group with $200,000 of business travel accident insurance under a group accidental death and dismemberment plan maintained by Cleco Power. The total 2024 premium for all coverage (exempt employees, officers and Board Managers) under this plan was $6,128.
Interests of the Board of Managers
In 2024, no non-management member of Cleco’s Boards performed services for or received compensation from Cleco or its affiliates except for those services relating to his or her duty as a member of Cleco’s Boards.
REPORT OF THE LEADERSHIP DEVELOPMENT AND COMPENSATION COMMITTEE
The Leadership Development and Compensation Committee of the Boards (see “Boards of Managers of Cleco” above and “Director Independence and Related Party Transactions” below), includes four managers, one of whom meets the additional requirements for independence which were adopted by the Board. The Leadership Development and Compensation Committee operates under a written charter last revised in December 2021, a copy of which is posted on Cleco’s website at https://www.cleco.com/about/leadership-governance/board-committees. A copy of this charter also is available free of charge by request sent to: Public Relations, Cleco, P.O. Box 5000, Pineville, LA 71361-5000.
The Leadership Development and Compensation Committee was established in April 2016.
Based on the review and discussions referred to above, the Leadership Development and Compensation Committee recommended to the Company’s Boards that the CD&A and related required compensation disclosure tables be included in this Annual Report on Form 10-K and filed with the SEC.
The Leadership Development and Compensation Committee of the Boards of Managers of Cleco Holdings and Cleco Power
Andrew Chapman, Chair
Christopher Leslie
Richard Gallot, Jr.
Steven Turner
Leadership Development and Compensation Committee Interlocks and Insider Participation
The members of the Leadership Development and Compensation Committee are set forth above. No members of the Leadership Development and Compensation Committee were officers or employees of the Company or any of its
CLECO
CLECO POWER 2024 FORM 10-K
subsidiaries during 2024, were former Company officers, or had any relationship otherwise requiring disclosure.
CEO Pay Ratio
The aggregate compensation of the executive who served in the CEO role in 2024 (Mr. Fontenot) was $5,267,481. This amount differs from the aggregate amount reflected in the Summary Compensation Table included in this Annual Report on Form 10-K because of the inclusion of the value of the Company’s contribution to health and welfare benefits. The median employee’s annual total compensation for 2024 was $128,970, calculated including the same components of total pay as was used for Mr. Fontenot. As a result, Cleco estimates that the CEO’s 2024 annual total compensation was 40.8 times that of the median employee’s annual total compensation. The median employee was determined based on employees of the
Company on December 31, 2024, using the consistently applied compensation measure of target total cash compensation (including base salary and target bonus). Target total cash compensation was annualized for those employees that were not employed for the full year of 2024.
The pay ratio estimate has been calculated in a manner consistent with Item 402(u) of Regulation S-K. In addition, because the SEC rules for identifying the median employee allow companies to adopt a variety of methodologies, to apply certain exclusions, and to make reasonable estimates and assumptions that reflect their compensation practices, the pay ratio reported by other companies may not be comparable to the pay ratio reported above, as other companies may have different employment and compensation practices and may utilize different methodologies, exclusions, estimates and assumptions in calculating their own pay ratios.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Security Ownership of Directors and Management and Certain Beneficial Owners
Following the closing of the 2016 Merger, there are no longer any outstanding shares of Cleco Corporation common stock.
Equity Compensation Plan Information
Cleco has no compensation plans under which equity securities are awarded.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Director Independence and Related Party Transactions
Cleco’s Boards have adopted categorical standards to assist them in making determinations of managers’ independence. These categorical standards are posted on Cleco’s website at https://cleco.com/about/leadership-governance/governance-guidelines. A copy of the standards is also available free of charge by request sent to: Public Relations, Cleco, P.O. Box 5000, Pineville, LA 71361-5000. The Boards have determined that Rick Gallot (member of the Boards of Cleco Group, Cleco
Holdings and Cleco Power), Randy Gilchrist (member of the Boards of Cleco Group, Cleco Holdings and Cleco Power), Peggy Scott (member of the Boards of Cleco Group, Cleco Holdings, and Cleco Power), Melissa Stark (member of the Board of Cleco Power), and Bruce Wainer (member of the Boards of Cleco Group, Cleco Holdings and Cleco Power) are independent within the meaning of the categorical standards adopted by the Boards.
Cleco has no relationships to report under Item 407(a)(3).

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Aggregate fees for professional services rendered by PricewaterhouseCoopers LLP (PwC) for the years ended December 31, 2024, and 2023, respectively, were as follows:
2024 2023
Audit fees $ 2,035,020 $ 2,579,243
Audit-related fees 154,000 157,000
Tax fees 410,179 509,480
Other fees 2,000 2,000
Total $ 2,601,199 $ 3,247,723
Audit fees include professional fees rendered by PwC for financial statement audit and review services that are customary under generally accepted auditing standards or that are customary for the purpose of rendering an opinion or review report on the financial statements.
Audit-related fees consist of assurance and related services that are traditionally performed by PwC, such as audits of stand-alone financial statements or other assurance services not required by statute or regulation.
Tax fees consist of professional services rendered by PwC for tax compliance, tax planning and tax advice, and consulting services, including assistance and representation in
connection with tax audits and appeals, tax advice related to employee benefit plans and requests for rulings or technical advice from taxing authorities.
Other fees primarily reflect costs for training services and accounting research software licenses.
As it relates to PwC’s engagement to audit Cleco’s financial statements for the year ended December 31, 2024, there were no professional services performed by persons other than the principal accountant’s full-time, permanent employees at PwC.
Audit Committee Pre-Approval Policies and Procedures
The Audit Committee has established a policy requiring its pre-approval of all audit and non-audit services provided by the independent registered public accounting firm. The policy requires the general pre-approval of annual audit services and specific pre-approval of all other permitted services. In determining whether to pre-approve permitted services, the Audit Committee considers whether such services are consistent with SEC rules and regulations. Furthermore, requests for pre-approval for services that are eligible for general pre-approval must be detailed as to the services to be provided. The independent registered public accounting firm and management are required to periodically report to the
CLECO
CLECO POWER 2024 FORM 10-K
Audit Committee regarding the extent of services provided by the independent registered public accounting firm in accordance with this pre-approval and the fees for the services performed to date. During 2024 and 2023, all audit and non-audit fees were pre-approved by the Audit Committee in accordance with the policy described above and pursuant to applicable rules of the SEC.
For the fiscal years ended December 31, 2024, and 2023, professional services provided for Cleco Power that were directly billed to Cleco Holdings were allocated to Cleco Power though not billed directly to Cleco Power. The following is Cleco Power’s allocation of professional services provided by PwC:
2024 2023
Audit fees $ 1,648,366 $ 2,014,337
Audit-related fees 154,000 80,000
Tax fees 332,245 412,679
Other fees 1,620 1,620
Total $ 2,136,231 $ 2,508,636
CLECO
CLECO POWER 2024 FORM 10-K
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
FORM 10-K
ANNUAL
REPORT
Report of Independent Registered Public Accounting Firm (PCAOB ID 238)
Report of Independent Registered Public Accounting Firm (PCAOB ID 238)
15(a)(1)
Financial Statements of Cleco
Consolidated Statements of Income for the years ended December 31, 2024, 2023, and 2022
Consolidated Statements of Comprehensive Income for the years ended December 31, 2024, 2023, and 2022
Consolidated Balance Sheets at December 31, 2024, and 2023
Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023, and 2022
Consolidated Statements of Changes in Equity for the years ended December 31, 2024, 2023, and 2022
Financial Statements of Cleco Power
Cleco Power Consolidated Statements of Income for the years ended December 31, 2024, 2023, and 2022
Cleco Power Consolidated Statements of Comprehensive Income for the years ended December 31, 2024, 2023, and 2022
Cleco Power Consolidated Balance Sheets at December 31, 2024, and 2023
Cleco Power Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023, and 2022
Cleco Power Consolidated Statements of Changes in Member’s Equity for the years ended December 31, 2024, 2023, and 2022
Notes to the Financial Statements
15(a)(2)
Financial Statement Schedules
Schedule I - Financial Statements of Cleco Holdings (Parent Company Only)
Condensed Statements of Income for the years ended December 31, 2024, 2023, and 2022
Condensed Statements of Comprehensive Income for the years ended December 31, 2024, 2023, and 2022
Condensed Balance Sheets at December 31, 2024, and 2023
Condensed Statements of Cash Flows for the years ended December 31, 2024, 2023, and 2022
Notes to the Condensed Financial Statements
Schedule II - Valuation and Qualifying Accounts
Cleco - Valuation and Qualifying Accounts for the years ended December 31, 2024, 2023, and 2022
Cleco Power - Valuation and Qualifying Accounts for the years ended December 2024, 2023, and 2022
Financial Statement Schedules other than those shown in the above index are omitted because they are either not required or are not applicable or the required information is shown in the Consolidated Financial Statements and Notes thereto
15(a)(3)
List of Exhibits
The Exhibits designated by an asterisk are filed herewith, except for Exhibits 32.1, 32.2, 32.3, 32.4, which are furnished herewith (and not filed for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liability of that section). The Exhibits not so designated previously have been filed with the SEC and are incorporated herein by reference. The Exhibits designated by two asterisks are management contracts and compensatory plans and arrangements required to be filed as Exhibits to this Report.
Pursuant to paragraph 601(b)(4)(iii)(A) of Regulation S-K, the Registrants have omitted from the following listings of Exhibits, and hereby agrees to furnish to the SEC upon its request, copies of certain instruments, each relating to debt not exceeding 10 percent of the total assets of the respective Registrant and its subsidiaries on a consolidated basis.
CLECO
CLECO POWER 2024 FORM 10-K
EXHIBITS
CLECO SEC FILE OR
REGISTRATION
NUMBER REGISTRATION
STATEMENT OR
REPORT EXHIBIT
NUMBER
2(a) Agreement and Plan of Merger, dated as of October 17, 2014, by and among the Company, Como 1 L.P. and Como 3 Inc.
1-15759 8-K(10/20/14) 2.1
2(b) Purchase and Sale Agreement dated as of February 6, 2018 by and between NRG Energy, Inc., a Delaware Corporation, as Seller, NRG South Central Generating LLC, a Delaware limited liability company, as the Company and Cleco Energy LLC, a Louisiana limited liability company, as Purchaser
1-15759 10-Q(3/18) 2.1
2(c) Letter Agreement, dated as of February 1, 2019 between NRG Energy, Inc. and Cleco Cajun LLC (f/k/a Cleco Energy LLC) amending, supplementing and modifying the Purchase and Sale Agreement (the “Cleco Cajun Divestiture Purchase and Sale Agreement”), dated as of February 6, 2018, by and between NRG Energy, Inc. and Cleco Cajun LLC (f/k/a Cleco Energy LLC).
1-15759 8-K(2/8/19) 10.6
2(d)
Purchase and Sale Agreement dated November 22, 2023 by and among Big Pelican LLC, Pelican South Central LLC, South Central Generating LLC, and Cleco Cajun LLC
1-15759
10-K(2023)
2(d)
3(a) Articles of Entity Conversion of Cleco Corporate Holdings LLC, dated as of April 13, 2016
1-15759 8-K(4/19/16) 3.1
3(b) Limited Liability Company Agreement of Cleco Corporate Holdings LLC, dated as of April 13, 2016
1-15759 8-K(4/19/16) 3.2
4(a)(1) Indenture between Cleco Power (as successor) and Bankers Trust Company, as Trustee, dated as of October 1, 1988 33-24896 S-3(10/11/88) 4(b)
4(a)(2) Agreement Appointing Successor Trustee dated as of April 1, 1996, by and among Central Louisiana Electric Company, Inc., Bankers Trust Company, and The Bank of New York
333-02895 S-3(4/29/96) 4(a)(2)
4(a)(3) First Supplemental Indenture, dated as of December 1, 2000, between Cleco Utility Group Inc. and the Bank of New York
333-52540 S-3/A(1/26/01) 4(a)(2)
4(a)(4) Second Supplemental Indenture, dated as of January 1, 2001, between Cleco Power LLC and The Bank of New York
333-52540 S-3/A(1/26/01) 4(a)(3)
4(a)(5) Eighth Supplemental Indenture, dated as of November 30, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.
1-05663 8-K(11/28/05) 4.1
4(a)(6) Tenth Supplemental Indenture, dated as of November 13, 2009, between Cleco Power LLC and The Bank of New York Mellon Trust Company, N.A. (as successor trustee)
1-05663 8-K(11/12/09) 4.1
4(a)(7) Eleventh Supplemental Indenture, dated as of November 15, 2010, between Cleco Power LLC and The Bank of New York Mellon Trust Company, N.A. (as successor trustee)
1-05663 8-K(11/15/10) 4.1
4(b)(1) Indenture of Mortgage dated May 17, 2016 between Cleco Corporate Holdings LLC and Wells Fargo Bank, N.A.
1-15759 8-K(5/17/16) 4.1
4(b)(2) First Supplemental Indenture dated May 17, 2016 between Cleco Corporate Holdings LLC and Wells Fargo Bank, N.A
1-15759 8-K(5/17/16) 4.2
4(b)(3) Second Supplemental Indenture dated May 17, 2016 between Cleco Corporate Holdings LLC and Wells Fargo Bank, N.A
1-15759 8-K(5/17/16) 4.3
4(b)(4)
Amended and Restated Third Supplemental Indenture dated as of May 1, 2023 between Cleco Corporate Holdings LLC and Regions Bank (as successor to Wells Fargo Bank, N.A.) as trustee
1-15759
8-K(05/02/23)
4.2
4(c)(1) Indenture, dated as of September 11, 2019, by and between Cleco Corporate Holdings LLC and Regions Bank
1-15759 8-K(9/12/19) 4.1
4(c)(2) Supplemental Indenture No.1, dated as of September 11, 2019, by and between Cleco Corporate Holdings LLC and Regions Bank
1-15759 8-K(9/12/19) 4.2
** 10(a)(1) Supplemental Executive Retirement Plan Amended and Restated January 1, 2009
1-15759 10-K(2008) 10(f)(4)
** 10(a)(2) Supplemental Executive Retirement Plan (Amended and Restated January 1, 2009), Amendment No. 1
1-15759 8-K(12/9/08) 10.3
** 10(a)(3) Cleco Corporation Supplemental Executive Retirement Plan Amendment, effective October 28, 2011
1-15759 10-Q(9/11) 10.2
** 10(a)(4) Cleco Corporation Supplemental Executive Retirement Plan Amended and Restated effective January 1, 2009, Amendment No. 3 (No New Participants)
1-15759 10-K(2014) 10(c)(10)
** 10(a)(5) Cleco Corporate Holdings LLC Supplemental Executive Retirement Plan (Amended and Restated January 1, 2009), Amendment No.4 (Special CEO Benefit)
1-15759 8-K(12/21/17) 10.2
** 10(a)(6) Supplemental Executive Retirement Trust dated December 13, 2000
1-15759 10-K(2003) 10(e)(1)(c)
** 10(a)(7) Supplemental Executive Retirement Plan Participation Agreement between Cleco Corporation and Dilek Samil
1-15759 10-K(2002) 10(z)(1)
** 10(a)(8) Supplemental Executive Retirement Plan Participation Agreement between Cleco Corporation and Michael H. Madison
1-15759 10-K(2004) 10(v)(3)
** 10(b)(1) Cleco Corporate Holdings LLC Executive Severance Plan, effective May 21, 2021
1-15759 10-Q(6/21) 10.3
** 10(b)(2) Cleco Corporate Holdings LLC Separation Agreement, dated effective March 23, 2017, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Darren J. Olagues
1-15759 8-K(3/28/17) 10.1
** 10(b)(3) Executive Employment Agreement, dated April 21, 2011, by and between Cleco Corporation and Bruce A. Williamson
1-15759 8-K(4/27/11) 10.1
** 10(b)(4) Employment Agreement, effective as of January 1, 2018, by and between Cleco Corporate Holdings LLC, Cleco Group LLC and Cleco Power LLC and William G. Fontenot
1-15759 8-K(12/21/17) 10.1
**
10(b)(5)
Supplemental Agreement, dated May 16, 2023, by and between Cleco Corporate Holdings LLC and Mark Kleehammer
1-15759 10-Q(6/23)
10.1
** 10(c)(1) Cleco Corporation Deferred Compensation Plan
333-59696 S-8(4/27/01) 4.3
** 10(c)(2) First Amendment to Cleco Corporation Deferred Compensation Plan
1-15759 10-K(2008) 10(n)(5)
** 10(c)(3) Cleco Corporation Deferred Compensation Plan, Corrective Section 409A Amendment
1-15759 8-K(12/9/08) 10.2
** 10(c)(4) Deferred Compensation Trust dated January 2001
1-15759 10-K(2003) 10(u)
** 10(c)(5) Cleco Corporation Deferred Compensation Plan Amendment, effective October 28, 2011
1-15759 10-Q(9/11) 10.5
10(d)(1) Note Purchase Agreement dated May 8, 2012 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(05/09/12) 10.1
10(d)(2) Note Purchase Agreement dated November 13, 2015 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-15759 8-K(11/13/15) 10.1
10(d)(3) Note Purchase Agreement dated December 20, 2016 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(12/21/16) 10.1
10(d)(4) Note Purchase Agreement dated December 18, 2017 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-15759 8-K(12/21/17) 10.1
10(d)(5)
Credit Agreement, dated as of May 17, 2024, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent
1-15759 8-K(5/21/24) 10.1
10(d)(6)
Term Agreement, dated as of May 17, 2024, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent
1-15759 8-K(5/21/24) 10.2
10(d)(7)
Credit Agreement, dated as of May 17, 2024, by and among Cleco Corporate Holdings LLC, the lenders party thereto and Regions Bank, as administrative agent
1-15759 8-K(5/21/24) 10.1
10(e)(1) 2017 Long-Term Incentive Compensation Plan, effective as of January 1, 2017
1-15759 10-Q(3/17) 10.3
CLECO
CLECO POWER 2024 FORM 10-K
EXHIBITS
CLECO SEC FILE OR
REGISTRATION
NUMBER REGISTRATION
STATEMENT OR
REPORT EXHIBIT
NUMBER
10(e)(2) Form of Notice and Acceptance of Incentive Award under Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan - 2017 Two-Year Performance Cycle
1-15759 10-Q(3/17) 10.4
10(e)(3) Form of Notice and Acceptance of Incentive Award under Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan - 2017 Three-Year Performance Cycle
1-15759 10-Q(3/17) 10.5
10(f) Form of Eighth Agreement to Extend the Board of Managers Services Agreement, effective as of May 1, 2024, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Manager
1-15759 10-Q(3/24)
10.1
10(g) 2017 Short-Term Incentive Plan, effective as of January 1, 2017
1-15759 10-Q(3/17) 10.6
10(h)
Note Purchase Agreement dated December 14, 2023 by and among Cleco Power LLC and the Purchasers listed on Schedule A thereto
1-15759 10-K(2023) 10(h)
*
19.1 Insider Trading Policy, effective March 22, 2004
* 21 Subsidiaries of the Registrant
* 24(a) Power of Attorney from each Manager of Cleco Corporate Holdings LLC and Cleco Power LLC whose signature is affixed to this Form 10-K for the fiscal year ended December 31, 2024
* 31.1 CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
* 31.2 CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
* 32.1 CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
* 32.2 CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
* 101.INS Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
* 101.SCH Inline XBRL Taxonomy Extension Schema
* 101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase
* 101.DEF Inline XBRL Taxonomy Extension Definition Linkbase
* 101.LAB Inline XBRL Taxonomy Extension Label Linkbase
* 101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase
* 104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
CLECO
CLECO POWER 2024 FORM 10-K
CLECO POWER SEC FILE OR
REGISTRATION
NUMBER REGISTRATION
STATEMENT OR
REPORT EXHIBIT
NUMBER
3(a) Second Amended and Restated Articles of Organization of Cleco Power LLC, dated as of April 13, 2016
1-05663 8-K(4/19/16) 3.3
3(b) Second Amended and Restated Articles Operating Agreement of Cleco Power LLC, dated as of April 13, 2016
1-05663 8-K(4/19/16) 3.4
4(a)(1) Indenture between the Company and Bankers Trust Company, as Trustee, dated as of October 1, 1988 33-24896 S-3(10/11/88) 4(b)
4(a)(2) Agreement Appointing Successor Trustee dated as of April 1, 1996, by and among Central Louisiana Electric Company, Inc., Bankers Trust Company, and The Bank of New York
333-02895 S-3(4/29/96) 4(a)(2)
4(a)(3) First Supplemental Indenture, dated as of December 1, 2000, between Cleco Utility Group Inc. and the Bank of New York
333-52540 S-3/A(1/26/01) 4(a)(2)
4(a)(4) Second Supplemental Indenture, dated as of January 1, 2001, between Cleco Power LLC and The Bank of New York
333-52540 S-3/A(1/26/01) 4(a)(3)
4(a)(5) Seventh Supplemental Indenture, dated as of July 6, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.
1-05663 8-K(7/6/05) 4.1
4(a)(6) Eighth Supplemental Indenture, dated as of November 30, 2005, between Cleco Power LLC and the Bank of New York Trust Company, N.A.
1-05663 8-K(11/28/05) 4.1
4(a)(7) Ninth Supplemental Indenture, dated as of June 3, 2008, between Cleco Power LLC and The Bank of New York Trust Company, N.A.
1-05663 8-K(6/2/08) 4.1
4(a)(8) Tenth Supplemental Indenture, dated as of November 13, 2009, between Cleco Power LLC and The Bank of New York Mellon Trust Company, N.A. (as successor trustee)
1-05663 8-K(11/12/09) 4.1
4(a)(9) Eleventh Supplemental Indenture, dated as of November 15, 2010, between Cleco Power LLC and The Bank of New York Mellon Trust Company, N.A. (as successor trustee)
1-05663 8-K(11/15/10) 4.1
4(b)
Loan Agreement, dated as of November 1, 2007, between Cleco Power LLC and the Rapides Finance Authority
1-05663 8-K(11/20/07) 4.1
4(c)
Loan Agreement, dated as of October 1, 2008, between Cleco Power LLC and the Rapides Finance Authority
1-05663 10-Q(3/10) 4.1
4(d)
Loan Agreement, dated as of December 1, 2008, between Cleco Power LLC and the Louisiana Public Facilities Authority
1-05663 10-Q(3/10) 4.2
4(e)(1)
Indenture, dated as of September 10, 2021, by and between Cleco Power LLC and Regions Bank, as trustee
1-05663 8-K(09/10/21) 4.1
4(e)(2)
Supplemental Indenture No. 1, dated as of September 10, 2021, by and between Cleco Power LLC and Regions Bank, as trustee
1-05663 8-K(09/10/21) 4.2
4(e)(3)
Form of Note (included in Supplemental Indenture No. 1, dated September 10, 2021, by and between Cleco Power LLC and Regions Bank, as trustee)
1-05663 8-K(09/10/21) 4.3
4(f)(1)
Indenture between Cleco Securitization I LLC and The Bank of New York Mellon Trust Company, National Association, as Trustee (including the form of the Storm Recovery Bonds and the Series Supplement), dated as of June 22, 2022
1-05663 8-K(6/22/22) 4.1
4(f)(2)
Series Supplement between Cleco Securitization I LLC and The Bank of New York Mellon Trust Company, National Association, as Trustee, dated as of June 22, 2022
1-05663 8-K(6/22/22) 4.2
** 10(a) Supplemental Executive Retirement Plan 1-05663 10-K(1992) 10(o)(1)
10(b)(1) Notes Purchase Agreement dated as of December 16, 2011 among Cleco Power LLC, various financial institutions and Credit Agricole Securities (USA) Inc., JPMorgan Securities Inc. and KeyBanc Capital Markets Inc., as agents.
1-05663 8-K(12/19/11) 10.1
10(b)(2) Note Purchase Agreement dated May 8, 2012 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(05/09/12) 10.1
10(b)(3) Note Purchase Agreement dated November 13, 2015 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(11/13/15) 10.1
10(b)(4) Note Purchase Agreement dated December 20, 2016 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(12/21/16) 10.1
10(b)(5) Note Purchase Agreement dated December 18, 2017 by and among Cleco Power LLC and the Purchasers listed on the signature pages thereto
1-05663 8-K(12/21/17) 10.1
10(b)(6
Credit Agreement, dated as of May 17, 2024, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent
1-15759 8-K(5/21/24) 10.1
10(b)(7
Term Agreement, dated as of May 17, 2024, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent
1-15759 8-K(5/21/24) 10.2
10(c) Staffing Agreement, dated as of April 13, 2016, by and between Cleco Power LLC and Co Issuer Corporate Staffing, LLC
1-05663 8-K(4/19/16) 10.4
** 10(d)(1) Cleco Corporate Holdings LLC Separation Agreement, dated effective March 23, 2017, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Darren J. Olagues
1-05663 8-K(3/28/17) 10.1
** 10(d)(2) Employment Agreement, effective as of January 1, 2018, by and between Cleco Corporate Holdings LLC, Cleco Group LLC and Cleco Power LLC and William G. Fontenot
1-05663 8-K(12/21/17) 10.1
10(e) Form of Eighth Agreement to Extend the Board of Managers Services Agreement, effective as of May 1, 2024, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Manager
1-05663 10-Q(3/24)
10.1
10(f)(1) Storm Recovery Property Servicing Agreement between Cleco Securitization I LLC and Cleco Power LLC, as Servicer, dated as of June 22, 2022
1-05663 8-K(6/22/22) 10.1
10(f)(2) Storm Recovery Property Sale Agreement between Cleco Securitization I LLC and Cleco Power LLC, as Seller, dated as of June 22, 2022
1-05663 8-K(6/22/22) 10.2
10(f)(3) Administrative Agreement between Cleco Securitization I LLC and Cleco Power LLC, as Administrator, dated as of June 22, 2022
1-05663 8-K(6/22/22) 10.3
10(h)
Note Purchase Agreement dated December 14, 2023 by and among Cleco Power LLC and the Purchasers listed on Schedule A thereto
1-15759 10-K(2023) 10(h)
* 24(a) Power of Attorney from each Manager of Cleco Corporate Holdings LLC and Cleco Power LLC whose signature is affixed to this Form 10-K for the fiscal year ended December 31, 2024
* 31.3 CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
* 31.4 CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
* 32.3 CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
* 32.4 CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
* 101.INS Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
* 101.SCH Inline XBRL Taxonomy Extension Schema
* 101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase
* 101.DEF Inline XBRL Taxonomy Extension Definition Linkbase
* 101.LAB Inline XBRL Taxonomy Extension Label Linkbase
CLECO
CLECO POWER 2024 FORM 10-K
CLECO POWER SEC FILE OR
REGISTRATION
NUMBER REGISTRATION
STATEMENT OR
REPORT EXHIBIT
NUMBER
* 101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase
* 104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)