UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549	

		FORM 10-Q			
 
ý      QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2025
 
☐         TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from          to          
 
Commission File Number: 001-36559
Via Renewables, Inc.
(Exact name of registrant as specified in its charter)
					
Delaware				46-5453215	
(State or other jurisdiction of
incorporation or organization)				(I.R.S. Employer
Identification No.)	
12140 Wickchester Ln, Suite 100 
Houston, Texas 77079

(Address of principal executive offices)
 
(713) 600-2600
                                                       (Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of each class	Trading Symbols(s)	Name of exchange on which registered	
8.75% Series A Fixed-to-Floating Rate
Cumulative Redeemable Perpetual Preferred Stock, par value $0.01 per share	VIASP	The NASDAQ Global Select Market	
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. 
Yes ý	No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this Chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes ý	No ☐

Large accelerated filer ☐ 	 Accelerated filer ☐ 
Non-accelerated filer ý   							 	 Smaller reporting company ☐
Emerging Growth Company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
    
	Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
		Yes ☐	No ý

There were 3,792,493 shares of Class A common stock, 3,530,836 shares of Class B common stock and 3,192,155 shares of Series A Preferred Stock outstanding as of July 29, 2025.

VIA RENEWABLES, INC.			
INDEX TO QUARTERLY REPORT ON FORM 10-Q			
For the Quarter Ended June 30, 2025			
		Page No.	
PART I. FINANCIAL INFORMATION			
ITEM 1. FINANCIAL STATEMENTS			
			
CONDENSED CONSOLIDATED BALANCE SHEETS AS OF JUNE 30, 2025 AND DECEMBER 31, 2024  (unaudited)		4	
			
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2025 AND 2024 (unaudited)		6	
			
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2025 AND 2024 (unaudited)		7	
			
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE SIX MONTHS ENDED JUNE 30, 2025 AND 2024 (unaudited)		11	
			
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited)		12	
			
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		42	
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		59	
ITEM 4. CONTROLS AND PROCEDURES		61	
PART II. OTHER INFORMATION		62	
ITEM 1. LEGAL PROCEEDINGS		62	
ITEM 1A. RISK FACTORS		62	
ITEM 6. EXHIBITS		63	
SIGNATURES		65	

Cautionary Note Regarding Forward Looking Statements 

This Quarterly Report on Form 10-Q (this “Report”) contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. These forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), can be identified by the use of forward-looking terminology including “may,” “should,” “could,” “likely,” “will,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” “plan,” “intend,” “project,” or other similar words. Forward-looking statements appear in a number of places in this Report. All statements, other than statements of historical fact, included in this Report are forward-looking statements. The forward-looking statements include statements regarding the impacts of Winter Storm Uri, cash flow generation and liquidity, business strategy, prospects for growth and acquisitions, outcomes of legal proceedings, the timing, availability, ability to pay and amount of cash dividends on our 8.75% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock, par value $0.01 per share (the "Series A Preferred Stock"), future operations, financial position, estimated revenues and losses, projected costs, prospects, plans, objectives, beliefs of management, availability and terms of capital, competition, government regulation and general economic conditions. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot give any assurance that such expectations will prove correct.

The forward-looking statements in this Report are subject to risks and uncertainties. Important factors that could cause actual results to materially differ from those projected in the forward-looking statements include, but are not limited to:

•	the ultimate impact of the Winter Storm Uri, including future benefits or costs related to ERCOT market securitization efforts, and any action by the State of Texas, ERCOT, the Railroad Commission of Texas, or the Public Utility Commission of Texas; 
•	changes in commodity prices, the margins we achieve, and interest rates;
•	the sufficiency of risk management and hedging policies and practices;
•	the impact of extreme and unpredictable weather conditions, including hurricanes, heat waves and other natural disasters;
•	federal, state and local regulations, including the industry’s ability to address or adapt to potentially restrictive new regulations that may be enacted by public utility commissions;
•	our ability to borrow funds and access credit markets;
•	restrictions and covenants in our debt agreements and collateral requirements;
•	credit risk with respect to suppliers and customers;
•	our ability to acquire customers and actual attrition rates;
•	changes in costs to acquire customers;
•	accuracy of billing systems;
•	our ability to successfully identify, complete, and efficiently integrate acquisitions into our operations;
•	significant changes in, or new changes by, the independent system operators (“ISOs”) in the regions we operate;
•	risks related to our recently completed Merger (as defined below) including the outcome of any legal proceedings, regulatory proceedings or enforcement matters that may be instituted against us and others relating to the Merger or otherwise, the impact of the Merger on our operations and the amount of the costs, fees, expenses and charges related to Merger; 
•	competition; and
•	the “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2024, in our Quarterly Reports on Form 10-Q in “Item 1A — Risk Factors” of this Report, and in our other public filings and press releases.

You should review the Risk Factors and other factors noted throughout or incorporated by reference in this Report that could cause our actual results to differ materially from those contained in any forward-looking statement. All forward-looking statements speak only as of the date of this Report. Unless required by law, we disclaim any obligation to publicly update or revise these statements whether as a result of new information, future events or otherwise. It is not possible for us to predict all risks, nor can we assess the impact of all factors on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements.

PART I. — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands, except share counts)
(unaudited)
	June 30, 2025		December 31, 2024	
Assets				
Current assets:				
Cash and cash equivalents	$	62,142			$	53,150		
Restricted cash		4,725				17,109		
Accounts receivable, net of allowance for credit losses of $2,606 at June 30, 2025 and $2,950 at December 31, 2024		47,972				65,442		
Accounts receivable—affiliates		3,941				4,119		
Inventory		1,805				2,137		
Fair value of derivative assets, net		2,606				8,685		
Customer acquisition costs, net		6,935				7,051		
Customer relationships, net		10,727				8,020		
Deposits		3,861				4,330		
Renewable energy credit asset		24,834				23,481		
Other current assets		8,555				10,247		
Total current assets		178,103				203,771		
Property and equipment, net		6,444				5,231		
Fair value of derivative assets, net		670				478		
Customer acquisition costs, net		2,216				2,141		
Customer relationships, net		669				3,500		
Deferred tax assets		4,848				6,088		
Goodwill		120,343				120,343		
Other assets		3,050				3,387		
Total assets	$	316,343			$	344,939		
				
Liabilities, Series A Preferred Stock and Stockholders' Equity				
Current liabilities:				
Accounts payable	$	26,067			$	37,176		
Accounts payable—affiliates		478				157		
Accrued liabilities		14,579				19,778		
Renewable energy credit liability		14,537				15,832		
Fair value of derivative liabilities, net (1)		375				1,701		
Other current liabilities		58				58		
Total current liabilities		56,094				74,702		
Long-term liabilities:				
Fair value of derivative liabilities, net		153				55		
Long-term portion of Senior Credit Facility		100,000				106,000		
Subordinated debt—affiliates		—				—		
Total liabilities		156,247				180,757		
Commitments and contingencies (Note 12)				
				
Series A Preferred Stock, par value $0.01 per share, 20,000,000 shares authorized, 3,192,155 shares issued and outstanding at June 30, 2025 and 3,380,440 shares issued and outstanding at  December 31, 2024		78,432				83,221		
				
Stockholders’ equity:				
       Common Stock:				
				
Class A common stock, par value $0.01 per share, 120,000,000 shares authorized, 3,792,493 shares outstanding at June 30, 2025 and 3,529,602 shares issued and outstanding at December 31, 2024		38				35		
Class B common stock, par value $0.01 per share, 60,000,000 shares authorized, 3,530,836 shares issued and outstanding at June 30, 2025 and 3,793,727 shares issued and outstanding December 31, 2024 		35				38		
				
       Additional paid-in capital		37,566				39,719		
       Accumulated other comprehensive loss		(40)			(40)	
       Retained earnings 		30,606				26,981		
     Total stockholders’ equity		68,205				66,733		
Non-controlling interest in Spark HoldCo, LLC		13,459				14,228		
       Total equity		81,664				80,961		
Total liabilities, Series A Preferred Stock and Stockholders’ equity	$	316,343			$	344,939		

(1) Fair value of derivative liabilities includes of less than $0.1 million and $0.3 million as of June 30, 2025 and December 31, 2024, respectively, related to affiliates.

The accompanying notes are an integral part of the condensed consolidated financial statements.

 VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS  
(in thousands, except per share data) 
(unaudited)
	Three Months Ended June 30,		Six Months Ended June 30,	
	2025		2024		2025		2024	
Revenues:								
Retail revenues	$	90,635			$	86,960			$	235,138			$	201,348		
Net asset optimization expense		(636)			(531)			(2,885)			(2,128)	
Other revenue		30				267				33				1,532		
Total Revenues		90,029				86,696				232,286				200,752		
Operating Expenses:								
Retail cost of revenues		63,055				42,997				158,448				111,959		
General and administrative 		15,631				20,862				32,623				38,195		
Depreciation and amortization		5,291				2,210				10,319				4,250		
Total Operating Expenses		83,977				66,069				201,390				154,404		
Operating income		6,052				20,627				30,896				46,348		
Other (expense):								
Interest expense		(1,539)			(1,743)			(3,357)			(3,672)	
Interest and other income 		19				19				56				43		
Total other expenses		(1,520)			(1,724)			(3,301)			(3,629)	
Income before income tax expense 		4,532				18,903				27,595				42,719		
Income tax expense		1,381				3,208				5,977				7,960		
Net income	$	3,151			$	15,695			$	21,618			$	34,759		
Less: Net income attributable to non-controlling interests		412				8,071				10,081				18,568		
Net income attributable to Via Renewables, Inc. stockholders	$	2,739			$	7,624			$	11,537			$	16,191		
Less: Dividend on Series A Preferred Stock		2,399				2,713				4,727				5,423		
Net income attributable to stockholders of Class A common stock	$	340			$	4,911			$	6,810			$	10,768		
								
Net income attributable to Via Renewables, Inc. per share of Class A common stock								
       Basic 	$	0.09			$	1.51			$	1.86			$	3.32		
       Diluted	$	0.09			$	1.51			$	1.86			$	3.32		
								
Weighted average shares of Class A common stock outstanding								
       Basic		3,792				3,261				3,663				3,247		
       Diluted		3,792				3,261				3,663				3,247		

The accompanying notes are an integral part of the condensed consolidated financial statements.

VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
(in thousands)
(unaudited)
Six Months Ended June 30, 2025	
	Issued Shares of Class A Common Stock	Issued Shares of Class B Common Stock	Class A Common Stock	Class B Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss	Additional Paid-in Capital	Retained Earnings	Total Stockholders' Equity	Non-controlling Interest	Total Equity	
Balance at December 31, 2024		3,530			3,794		$	35		$	38		$	—		$	(40)	$	39,719		$	26,981		$	66,733		$	14,228		$	80,961		
Consolidated net income 		—			—			—			—			—			—			—			11,537			11,537			10,081			21,618		
Distributions paid to non-controlling unit holders		—			—			—			—			—			—			—			—			—			(12,780)		(12,780)	
Distribution to controlling interest		263			(263)		3			(3)		—			—			(223)		(3,185)		(3,408)		—			(3,408)	
Dividends paid to Preferred Stockholders		—			—			—			—			—			—			—			(4,727)		(4,727)		—			(4,727)	
Changes in ownership interest		—			—			—			—			—			—			(1,930)		—			(1,930)		1,930			—		
Balance at June 30, 2025		3,793			3,531		$	38		$	35		$	—		$	(40)	$	37,566		$	30,606		$	68,205		$	13,459		$	81,664		

The accompanying notes are an integral part of the condensed consolidated financial statements.

Three Months Ended June 30, 2025	
	Issued Shares of Class A Common Stock	Issued Shares of Class B Common Stock	Class A Common Stock	Class B Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss	Additional Paid-in Capital	Retained Earnings 	Total Stockholders' Equity	Non-controlling Interest	Total Equity	
Balance at 3/31/2025	3,793	3,531	$	38		$	35		$	—		$	(40)	$	39,229		$	33,451		$	72,713		$	19,277		$	91,990		
Consolidated net income		—			—			—			—			—			—			—		2,739	2,739	412	3,151	
Distributions paid to non-controlling unit holders	—	—	—	—	—	—	—	—	—	(7,893)	(7,893)	
Distribution to controlling interest	—	—	—	—	—	—	—	(3,185)	(3,185)	—	(3,185)	
Dividends paid to Preferred Stockholders	—	—	—	—	—	—	—	(2,399)	(2,399)	—	(2,399)	
Changes in Ownership Interest	—	—	—	—	—	—	(1,663)	—	(1,663)	1,663	—	
Balance at June 30, 2025		3,793			3,531		$	38		$	35		$	—		$	(40)	$	37,566		$	30,606		$	68,205		$	13,459		$	81,664		

The accompanying notes are an integral part of the condensed consolidated financial statements.

Six Months Ended June 30, 2024	
	Issued Shares of Class A Common Stock	Issued Shares of Class B Common Stock	Treasury Stock	Class A Common Stock	Class B Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss	Additional Paid-in Capital	Retained Earnings 	Total Stockholders' Equity	Non-controlling Interest	Total Equity	
Balance at December 31, 2023		3,262			4,000			(29)	$	32		$	40		$	(2,406)	$	(40)	$	40,002		$	8,972		$	46,600		$	(7,881)	$	38,719		
Stock based compensation		—			—			—			—			—			—			—			1,720			—			1,720			—			1,720		
Restricted stock unit vesting		62			—			—			1			—			—			—			(287)		—			(286)		—			(286)	
Consolidated net income		—			—			—			—			—			—			—			—			16,191			16,191			18,568			34,759		
Contribution for cash settlement / merger		—			—			—			—			—			—			—			—			—			—			643			643		
Distributions paid to non-controlling unit holders		—			—			—			—			—			—			—			—			—			—			(4,495)		(4,495)	
Dividends paid to Preferred Stockholders		—			—			—			—			—			—			—			—			(5,423)		(5,423)		—			(5,423)	
Treasury Shares		—			—			29			—			—			2,406			—			(2,406)		—			—			—			—		
Changes in ownership interest		—			—			—			—			—			—			—			(541)		—			(541)		541			—		
Balance at June 30, 2024		3,324			4,000			—		$	33		$	40		$	—		$	(40)	$	38,488		$	19,740		$	58,261		$	7,376		$	65,637		

The accompanying notes are an integral part of the condensed consolidated financial statements.

Three Months Ended June 30, 2024	
	Issued Shares of Class A Common Stock	Issued Shares of Class B Common Stock	Treasury Stock	Class A Common Stock	Class B Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss	Additional Paid-in Capital	Retained Earnings 	Total Stockholders' Equity	Non-controlling Interest	Total Equity	
Balance at March 31, 2024		3,262			4,000			(29)		$	32		$	40		$	(2,406)		$	(40)		$	40,726		$	14,829		$	53,181		$	2,285		$	55,466		
Stock based compensation		—			—			—			—			—			—			—			1,234			—			1,234			—			1,234		
Restricted stock unit vesting		62			—			—			1			—			—			—			(287)			—			(286)		—			(286)	
Consolidated net income		—			—			—			—			—			—			—			—			7,624			7,624			8,071			15,695		
Distributions paid to non-controlling unit holders		—			—			—			—			—			—			—			—			—			—			(4,402)		(4,402)	
Dividends paid to Preferred Stockholders		—			—			—			—			—			—			—			—			(2,713)			(2,713)		—			(2,713)	
Treasury Shares		—			—			29			—			—			2,406			—			(2,406)			—			—			—			—		
Contribution for cash settlement / merger		—			—			—			—			—			—			—			—			—			—			643			643		
Changes in ownership interest		—			—			—			—			—			—			—			(779)			—			(779)		779			—		
Balance at June 30, 2024		3,324			4,000			—		$	33		$	40		$	—		$	(40)		$	38,488		$	19,740		$	58,261		$	7,376		$	65,637		

The accompanying notes are an integral part of the condensed consolidated financial statements.

VIA RENEWABLES, INC. 
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS 
(in thousands)
(unaudited)
	Six Months Ended June 30,	
  	2025		2024	
Cash flows from operating activities:				
Net income	$	21,618			$	34,759		
Adjustments to reconcile net income to net cash flows provided by operating activities:				
Depreciation and amortization expense		10,319				4,250		
Deferred income taxes		2,130				4,204		
Stock based compensation		—				2,442		
Amortization of deferred financing costs		334				518		
Bad debt expense		833				1,321		
Loss on derivatives, net		2,026				1,025		
Current period cash settlements on derivatives, net		2,612				(23,192)	
Other		125				123		
Changes in assets and liabilities:				
Decrease in accounts receivable		16,637				12,840		
Decrease (increase) in accounts receivable—affiliates		178				(113)	
Decrease in inventory		333				1,108		
Increase in customer acquisition costs		(4,078)			(5,026)	
Decrease in prepaid and other current assets		496				7,110		
Decrease (increase) in intangible assets—customer acquisition costs		7,719				(783)	
Decrease (increase) in other assets		135				(1,599)	
Decrease in accounts payable and accrued liabilities		(17,790)			(10,456)	
Increase (decrease) in accounts payable—affiliates		321				(204)	
Net cash provided by operating activities		43,948				28,327		
Cash flows from investing activities:				
Purchases of property and equipment		(1,989)			(730)	
Acquisition of Customers		(12,963)			—		
Net cash used in investing activities		(14,952)			(730)	
Cash flows from financing activities:				
Buyback of Series A Preferred Stock		(4,748)			—		
Borrowings on notes payable		248,425				253,000		
Payments on notes payable		(254,425)			(257,000)	
Restricted stock vesting		—				(1,013)	
Contribution for cash settlement of merger		—				643		
Payment of dividends to Class A common stockholders		(3,185)			—		
Payment of distributions to non-controlling unitholders		(13,686)			(4,495)	
Payment of Preferred Stock dividends		(4,769)			(5,438)	
Net cash used in financing activities		(32,388)			(14,303)	
Increase in Cash, cash equivalents and Restricted cash		(3,392)			13,294		
Cash, cash equivalents and Restricted cash—beginning of period		70,259				42,595		
Cash, cash equivalents and Restricted cash—end of period	$	66,867			$	55,889		
Supplemental Disclosure of Cash Flow Information:				
Non-cash items:				
        Property and equipment purchase accrual	$	(20)		$	31		
Cash paid during the period for:				
Interest 	$	3,050			$	3,919		
Taxes 	$	3,628			$	7,329		
                                                                                                                                                                                                                                                                                                  The accompanying notes are an integral part of the condensed consolidated financial statements.

VIA RENEWABLES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

1. Formation and Organization 

Organization

We are an independent retail energy services company that provides residential and commercial customers in competitive markets across the United States with an alternative choice for natural gas and electricity. The Company is a holding company whose primary asset consists of units in Spark HoldCo, LLC (“Spark HoldCo”). The Company is the sole managing member of Spark HoldCo, is responsible for all operational, management and administrative decisions relating to Spark HoldCo’s business and consolidates the financial results of Spark HoldCo and its subsidiaries. Spark HoldCo is the direct and indirect owner of the subsidiaries through which we operate. We conduct our business through several brands across our service areas, including Electricity Maine, Electricity N.H., Major Energy, Provider Power Massachusetts, Spark Energy, and Verde Energy. Via Energy Solutions (“VES”) is a wholly owned subsidiary of the Company that offers broker services for retail energy customers. Via Wireless is a wholly owned subsidiary of the Company that offers wireless services and equipment to wireless customers. 

2. Basis of Presentation and Summary of Significant Accounting Policies 

Basis of Presentation

The accompanying interim unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) as it applies to interim financial statements. This information should be read along with our consolidated financial statements and notes contained in our annual report on Form 10-K for the year ended December 31, 2024 (the “2024 Form 10-K”). Our unaudited condensed consolidated financial statements are presented on a consolidated basis and include all wholly-owned and controlled subsidiaries. We account for investments over which we have significant influence but not a controlling financial interest using the equity method of accounting. All significant intercompany transactions and balances have been eliminated in the unaudited condensed consolidated financial statements.

In the opinion of the Company's management, the accompanying condensed consolidated financial statements reflect all adjustments that are necessary to fairly present the financial position, the results of operations, the changes in equity and the cash flows of the Company for the respective periods. Such adjustments are of a normal recurring nature, unless otherwise disclosed.

Subsequent Events

Subsequent events have been evaluated through the date these financial statements are issued. Any material subsequent events that occurred prior to such date have been properly recognized or disclosed in the condensed consolidated financial statements. 

Use of Estimates and Assumptions

The preparation of our condensed consolidated financial statements requires estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the interim financial statements and the reported amounts of revenues and expenses during the period. Actual results could materially differ from those estimates.

Relationship with our Founder, Sole Common Stock Shareholder, and Chief Executive Officer

W. Keith Maxwell, III is the Chief Executive Officer, a director, and the owner of all of the voting power of our common stock through his ownership of  Retailco, LLC (“Retailco”). Retailco is a wholly owned subsidiary of TxEx Energy Investments, LLC (“TxEx”), which is wholly owned by Mr. Maxwell.

We enter into transactions with and pay certain costs on behalf of affiliates that are commonly controlled by Mr. Maxwell, and these affiliates enter into transactions with and pay certain costs on our behalf. We undertake these transactions in order to reduce risk, reduce administrative expense, create economies of scale, create strategic alliances and supply goods and services among these related parties.

These transactions include, but are not limited to, employee benefits provided through the Company’s benefit plans, insurance plans, leased office space, certain administrative salaries, management due diligence, recurring management consulting, and accounting, tax, legal, or technology services. Amounts billed under these arrangements are based on services provided, departmental usage, or headcount, which are considered reasonable by management. As such, the accompanying condensed consolidated financial statements include costs that have been incurred by the Company and then directly billed or allocated to affiliates, and costs that have been incurred by our affiliates and then directly billed or allocated to us, and are recorded net in general and administrative expense on the condensed consolidated statements of operations with a corresponding accounts receivable—affiliates or accounts payable —affiliates, respectively, recorded in the condensed consolidated balance sheets. Additionally, the Company enters into transactions with certain affiliates for sales or purchases of natural gas and electricity, which are recorded in retail revenues, retail cost of revenues, and net asset optimization revenues in the condensed consolidated statements of operations with a corresponding accounts receivable—affiliate or accounts payable—affiliate in the condensed consolidated balance sheets. The allocations and related estimates and assumptions are described more fully in Note 14 "Transactions with Affiliates."

On June 13, 2024, we consummated a previously announced merger pursuant to an agreement between the Company, Retailco, and wholly owned subsidiary of Retailco (the "Merger"), with the Company continuing as the surviving corporation in the Merger. As a result of the Merger, Mr. Maxwell and his affiliates became the owners of all of the issued and outstanding shares of our Class A common stock and Class B common stock. Effective as of the end of trading on June 13, 2024, the Class A common stock ceased to trade on NASDAQ.

New Accounting Standards Being Evaluated/Standards Not yet adopted

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The ASU requires enhanced income tax disclosures, particularly related to a reporting entity's effective tax rate reconciliation and income taxes paid. For the rate reconciliation, the update requires additional categories of information about federal, state, and foreign taxes and details about significant reconciling items, subject to a quantitative threshold. Income taxes paid must be similarly disaggregated by federal, state, and foreign based on a quantitative threshold. The ASU will be effective for annual periods beginning after December 15, 2024. The guidance will be applied on a prospective basis with the option to apply retrospectively. We are evaluating the impact of adoption on our condensed consolidated financial statements.

In November 2024, the FASB issued ASU 2024-03, Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40) (“ASU 2024-03”). ASU 2024-03 seeks to improve information about cost of sales and selling, general, and administrative expenses to assist investors in better understanding an entity’s cost structure and forecasting future cash flows. FASB issued 2025-01 by clarifying the effective date of ASU 2024-03. The updated guidance is effective for the Company for annual periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027, with early adoption permitted. The Company is currently evaluating the effect of this update on its condensed consolidated financial statements and related disclosures.

The Company considers the applicability and impact of all ASUs. New ASUs were assessed and determined to be either not applicable or are expected to have minimal impact on our condensed consolidated financial statements.

3. Revenues
Our revenues are derived primarily from the sale of natural gas and electricity to customers, including affiliates. Revenue is measured based upon the quantity of gas or power delivered at prices contained or referenced in the customer's contract, and excludes any sales incentives (e.g., rebates) and amounts collected on behalf of third parties (e.g., sales tax). 

Our revenues also include asset optimization activities. Asset optimization activities consist primarily of purchases and sales of gas that meet the definition of trading activities per FASB ASC Topic 815, Derivatives and Hedging. They are therefore excluded from the scope of FASB ASC Topic 606, Revenue from Contracts with Customers.

Other revenue is derived from contracts with customers through the provision of wireless and other services and the sale of wireless equipment.

Revenues for electricity and natural gas sales are recognized under the accrual method when our performance obligation to a customer is satisfied, which is the point in time when the product is delivered and control of the product passes to the customer. Electricity and natural gas products may be sold as fixed-price or variable-price products. The typical length of a contract to provide electricity and/or natural gas is 12 months. Customers are billed and typically pay at least monthly, based on usage. Electricity and natural gas sales that have been delivered but not billed by period end are estimated and recorded as accrued unbilled revenues based on estimates of customer usage since the date of the last meter read provided by the utility. Volume estimates are based on forecasted volumes and estimated residential and commercial customer usage. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class (residential or commercial). Estimated amounts are adjusted when actual usage is known and billed.

The following table discloses revenue by primary geographical market, customer type, and customer credit risk profile (in thousands). The table also includes a reconciliation of the disaggregated revenue to revenue by reportable segment (in thousands).
	Reportable Segments	
	Three Months Ended June 30, 2025		Three Months Ended June 30, 2024	
	Retail Electricity (c)		Retail Natural Gas		Total Reportable Segments		Retail Electricity (c)		Retail Natural Gas		Total Reportable Segments	
												
Primary markets (a)												
New England	$	15,919			$	1,682			$	17,601			$	21,271			$	1,572			$	22,843		
Mid-Atlantic		28,509				6,453				34,962				27,514				5,912				33,426		
Midwest		7,032				2,834				9,866				6,518				2,107				8,625		
Southwest		15,350				12,856				28,206				15,845				6,221				22,066		
	$	66,810			$	23,825			$	90,635			$	71,148			$	15,812			$	86,960		
												
Customer type												
Commercial	$	8,712			$	16,919			$	25,631			$	9,989			$	11,304			$	21,293		
Residential		52,996				11,231				64,227				56,956				8,703				65,659		
Unbilled revenue (b)		5,102				(4,325)			777				4,203				(4,195)				8		
	$	66,810			$	23,825			$	90,635			$	71,148			$	15,812			$	86,960		
												
Customer credit risk												
POR	$	42,956			$	10,371			$	53,327			$	44,080			$	7,177			$	51,257		
Non-POR		23,854				13,454				37,308				27,068				8,635				35,703		
	$	66,810			$	23,825			$	90,635			$	71,148			$	15,812			$	86,960		

	Reportable Segments	
	Six Months Ended June 30, 2025		Six Months Ended June 30, 2024	
	Retail Electricity (c)		Retail Natural Gas		Total Reportable Segments		Retail Electricity (c)		Retail Natural Gas		Total Reportable Segments	
												
Primary markets (a)												
New England	$	37,191			$	6,877			$	44,068			$	48,610			$	6,197			$	54,807		
Mid-Atlantic		67,369				26,677				94,046				58,213				21,167				79,380		
Midwest		15,151				15,053				30,204				13,827				9,478				23,305		
Southwest		27,819				39,001				66,820				27,827				16,029				43,856		
	$	147,530			$	87,608			$	235,138			$	148,477			$	52,871			$	201,348		
												
Customer type												
Commercial	$	19,513			$	51,965			$	71,478			$	21,354			$	32,018			$	53,372		
Residential		129,213				39,734				168,947				127,904				27,344				155,248		
Unbilled revenue (b)		(1,196)			(4,091)			(5,287)			(781)			(6,491)			(7,272)	
	$	147,530			$	87,608			$	235,138			$	148,477			$	52,871			$	201,348		
												
Customer credit risk												
POR	$	98,890			$	39,337			$	138,227			$	94,369			$	26,646			$	121,015		
Non-POR		48,640				48,271				96,911				54,108				26,225				80,333		
	$	147,530			$	87,608			$	235,138			$	148,477			$	52,871			$	201,348		

	Reportable Segments	
(a) The primary markets include the following states:
•	New England - Connecticut, Maine, Massachusetts, New Hampshire and Rhode Island;
•	Mid-Atlantic - Delaware, Maryland (including the District of Columbia), New Jersey, New York, Pennsylvania and Virginia;
•	Midwest - Illinois, Indiana, Michigan and Ohio; and
•	Southwest - Arizona, California, Colorado, Florida, Nevada and Texas.

(b) Unbilled revenue is recorded in total until it is actualized, at which time it is categorized between commercial and residential customers.

(c) Retail Electricity includes Services.

Reconciliation to Condensed Consolidated Financial Information

A reconciliation of the reportable segment operating revenues to consolidated revenues is as follows:

	Three Months Ended June 30,		Six Months Ended June 30,	
 	2025		2024		2025		2024	
Total Reportable Segments Revenue	$	90,635			$	86,960			$	235,138			$	201,348		
Net asset optimization expense		(636)			(531)			(2,885)				(2,128)	
Other Revenue		30				267				33				1,532		
Total Revenues	$	90,029			$	86,696			$	232,286			$	200,752		
We record gross receipts taxes on a gross basis in retail revenues and retail cost of revenues. During the three months ended June 30, 2025 and 2024, our retail revenues included gross receipts taxes of $0.2 million and $0.2 million, respectively, and our retail cost of revenues included gross receipts taxes of $1.5 million and $1.3 million, respectively. During the six months ended June 30, 2025 and 2024, our retail revenues included gross receipts taxes of $0.5 million and $0.6 million, respectively, and our retail cost of revenues included gross receipts taxes of $3.3 million and $2.7 million, respectively. 

Accounts receivables and Allowance for Credit Losses

The Company conducts business in many utility service markets where the local regulated utility purchases our receivables, and then becomes responsible for billing the customer and collecting payment from the customer (“POR programs”). These POR programs result in substantially all of the Company’s credit risk being linked to the applicable utility, which generally has an investment-grade rating, and not to the end-use customer. The Company monitors the financial condition of each utility and currently believes its receivables are collectible. 

In markets that do not offer POR programs or when the Company chooses to directly bill its customers, certain receivables are billed and collected by the Company. The Company bears the credit risk on these accounts and records an appropriate allowance for credit losses to reflect any losses due to non-payment by customers. The Company’s customers are individually insignificant and geographically dispersed in these markets. The Company writes off customer balances when it believes that amounts are no longer collectible and when it has exhausted all means to collect these receivables.

For trade accounts receivables, the Company accrues an allowance for credit losses by business segment by pooling customer accounts receivables based on similar risk characteristics, such as customer type, geography, aging analysis, payment terms, and related macro-economic factors. Expected credit loss exposure is evaluated for each of our accounts receivables pools. Expected credits losses are established using a model that considers historical collections experience, current information, and reasonable and supportable forecasts. The Company writes off accounts receivable balances against the allowance for credit losses accounts when the accounts receivable is deemed to be uncollectible.

The following table reflects the Company's beginning and ending balances of our account receivables.

		Three Months Ended June 30,	Six months ended June 30,	
		2025		2024	2025		2024	
Beginning balance accounts receivables		$	70,442			$	55,852		$	65,442			$	63,246		
Ending balance of accounts receivables		$	47,972			$	49,085		$	47,972			$	49,085		

We assess the adequacy of the allowance for credit losses through review of an aging of customer accounts receivable and general economic conditions in the markets that we serve. Bad debt expense of $0.8 million and $1.3 million was recorded in general and administrative expense in the condensed consolidated statements of operations for the six months ended June 30, 2025 and June 30, 2024, respectively.

A rollforward of our allowance for credit losses for the six months ended June 30, 2025 are presented in the table below (in thousands):
			
Balance at December 31, 2024		$	(2,950)	
Current period credit loss provision			(833)	
Write-offs			1,236		
Recovery of previous write-offs			(59)	
Balance at June 30, 2025		$	(2,606)	

4. Equity 

Non-controlling Interest

We hold an economic interest and are the sole managing member in Spark HoldCo, with affiliates of Mr. Maxwell  holding the remaining economic interests in Spark HoldCo. As a result, we consolidate the financial position and results of operations of Spark HoldCo, and reflect the economic interests owned by these affiliates as a non-controlling interest.

On December 31, 2024, Spark HoldCo distributed $5.0 million in cash to the non-controlling interest holder. As a result of this distribution, the non-controlling interest holder agreed to transfer 206,273 of its shares of Class B Common Stock (the non-controlling interest in Spark HoldCo) to the Company, and the Company modified those shares of Class B Common Stock to be shares of Class A Common Stock. After the distribution and the share transfer, the Company’s equity ownership in Spark HoldCo increased by 2.82%, whereas the equity ownership of the non-controlling interest holder decreased by 2.82%.

On March 31, 2025, Spark HoldCo distributed $6.0 million in cash to the non-controlling interest holder. As a result of this distribution, the non-controlling interest holder agreed to transfer 262,891 of its shares of Class B Common Stock (the non-controlling interest in Spark HoldCo) to the Company, and the Company modified those shares of Class B Common Stock to be shares of Class A Common Stock. After the distribution and the share transfer, the Company’s equity ownership in Spark HoldCo increased by 3.59%, whereas the equity ownership of the non-controlling interest holder decreased by 3.59%.

During the three months ended June 30, 2025, Spark HoldCo distributed $3.0 million in cash to the non-controlling interest holder and distributed pro-rated $3.2 million in cash to the controlling interest holder. The pro rated distribution during the three months ended June 30, 2025 did not result in share transfer and change in equity ownership. 

The Company and affiliates owned the following economic interests in Spark HoldCo at June 30, 2025 and December 31, 2024, respectively. 

The following table summarizes the effects of changes in the Company's ownership interest in Spark HoldCo's equity (in thousands):
	Three Months Ended June 30,		Six months ended June 30,	
	2025		2024		2025		2024	
Net income attributable to Via Renewables, Inc. stockholders	$	2,739			$	7,624			$	11,537			$	16,191		
Transfers (to) from the non-controlling interest		—				—				—				—		
Decrease in Via Renewables additional paid in capital from the equity shift		—				—				(223)			—		
Net transfers (to) from non-controlling interest		—				—				(223)			—		
Changes from net income attributable to Via Renewables stockholders and transfers (to) from non-controlling interest	$	2,739			$	7,624			$	11,314			$	16,191		

	The Company	Affiliated Owners	
June 30, 2025		51.79	%		48.21	%	
December 31, 2024		48.20	%		51.80	%	

The following table summarizes the portion of net income and income tax expense attributable to non-controlling interest (in thousands):
	Three Months Ended June 30,		Six Months Ended June 30,	
	2025		2024		2025		2024	
Net income before taxes allocated to non-controlling interest	$	1,187			$	8,860			$	11,472			$	20,220		
Less: Income tax expense allocated to non-controlling interest		775				789				1,391				1,652		
Net income attributable to non-controlling interests	$	412			$	8,071			$	10,081			$	18,568		

Class A Common Stock and Class B Common Stock

As a result of the Merger, on June 13, 2024, Mr. Maxwell and his affiliates became the owners of all of the issued and outstanding shares of the Company's Class A common stock and Class B common stock. Effective as of the end of trading on June 13, 2024, the Class A common stock ceased to trade on NASDAQ.

Earnings Per Share

Basic earnings per share (“EPS”) is computed by dividing net income attributable to stockholders (the numerator) by the weighted-average number of Class A common shares outstanding for the period (the denominator). Class B common shares are not included in the calculation of basic earnings per share because they are not participating securities and have no economic interests. Diluted earnings per share is similarly calculated except that the denominator is increased by potentially dilutive securities.

The following table presents the computation of basic and diluted income per share for the three and six months ended June 30, 2025 and 2024 (in thousands, except per share data):
	Three Months Ended June 30,		Six Months Ended June 30,	
	2025	2024		2025	2024		
Net income attributable to Via Renewables, Inc. stockholders	$	2,739		$	7,624			$	11,537		$	16,191			
Less: Dividend on Series A Preferred Stock		2,399			2,713				4,727			5,423			
Net income attributable to stockholders of Class A common stock	$	340		$	4,911			$	6,810		$	10,768			
							
Basic weighted average Class A common shares outstanding		3,792			3,261				3,663			3,247			
Basic earnings per share attributable to stockholders	$	0.09		$	1.51			$	1.86		$	3.32			
							
Net income attributable to stockholders of Class A common stock	$	340		$	4,911			$	6,810		$	10,768			
Effect of conversion of Class B common stock to shares of Class A common stock		—			—				—			—			
Diluted net income attributable to stockholders of Class A common stock	$	340		$	4,911			$	6,810		$	10,768			
							
Basic weighted average Class A common shares outstanding		3,792			3,261				3,663			3,247			
Effect of dilutive Class B common stock		—			—				—			—			
Diluted weighted average shares outstanding		3,792			3,261				3,663			3,247			
							
Diluted earnings per share attributable to stockholders	$	0.09		$	1.51			$	1.86		$	3.32			

The computation of diluted earnings per share for the three and six months ended June 30, 2025 and 2024, respectively, excludes 3.5 million shares of Class B common stock because the effect of their conversion was antidilutive. The Company’s outstanding shares of Series A Preferred Stock were not included in the calculation of diluted earnings per share because they contain only contingent redemption provisions that have not occurred.

Variable Interest Entity

Spark HoldCo is a variable interest entity due to its lack of rights to participate in significant financial and operating decisions and its inability to dissolve or otherwise remove its management. Spark HoldCo owns all of the outstanding membership interests in each of our operating subsidiaries. We are the sole managing member of Spark HoldCo, manage Spark HoldCo’s operating subsidiaries through this managing membership interest, and are considered the primary beneficiary of Spark HoldCo.

The assets of Spark HoldCo cannot be used to settle our obligations except through distributions to us, and the liabilities of Spark HoldCo cannot be settled by us except through contributions to Spark HoldCo. The following table includes the carrying amounts and classification of the assets and liabilities of Spark HoldCo that are included in our condensed consolidated balance sheet as of June 30, 2025 and December 31, 2024 (in thousands):
	June 30, 2025	December 31, 2024	
Assets			
Current assets:			
   Cash and cash equivalents	$	61,982		$	52,993		
   Accounts receivable		47,864			65,354		
   Other current assets		56,714			79,704		
   Total current assets		166,560			198,051		
Non-current assets:			
   Goodwill		120,343			120,343		
   Other assets		13,709			16,042		
   Total non-current assets		134,052			136,385		
   Total Assets	$	300,612		$	334,436		
			
Liabilities			
Current liabilities:			
   Accounts payable and accrued liabilities	$	40,012		$	56,560		
   Other current liabilities		53,622			61,069		
   Total current liabilities		93,634			117,629		
Long-term liabilities:			
   Long-term portion of Senior Credit Facility		100,000			106,000		
   Subordinated debt — affiliate		—			—		
   Other long-term liabilities		153			55		
   Total long-term liabilities		100,153			106,055		
   Total Liabilities	$	193,787		$	223,684		

5. Preferred Stock 

Holders of the Series A Preferred Stock have no voting rights, except in specific circumstances of delisting or in the case the dividends are in arrears as specified in the Series A Preferred Stock Certificate of Designations. The Series A Preferred Stock accrued dividends at an annual percentage rate of 8.75% through April 14, 2022. The floating rate period for the Series A Preferred Stock began on April 15, 2022. The dividend on the Series A Preferred Stock will accrue at an annual rate equal to the sum of (a) Three-Month LIBOR (if it then exists), or an alternative reference rate as of the applicable determination date and (b) 6.578%, based on the $25.00 liquidation preference per share of the Series A Preferred Stock. The liquidation preference provisions of the Series A Preferred Stock are considered contingent redemption provisions because there are rights granted to the holders of the Series A Preferred Stock that are not solely within our control upon a change in control of the Company. Accordingly, the Series A Preferred Stock is presented between liabilities and the equity sections in the accompanying condensed consolidated balance sheets. As of April 15, 2022, we have the option to redeem our Series A Preferred Stock. 

Following the cessation of the publication of U.S. LIBOR on June 30, 2023, we use Three Month CME Term SOFR plus a tenor spread of 0.26161 percent (or 26.161 bps) to calculate the dividend rate on the Series A Preferred Stock pursuant to the rules of the Adjustable Interest Rate (LIBOR) Act.

As a result of the Merger, holders of the Company’s Series A Preferred Stock were provided an optional limited change of control conversion right (the “Conversion Right”), available at the option of the holder, for $8.07 per share in cash. On June 27, 2024, the Company provided notice to the holders of the Series A Preferred Stock of the Conversion Right. Holders of the Series A Preferred Stock were entitled to exercise the Conversion Right through July 26, 2024. No holders of the Series A Preferred Stock exercised the Conversion Right.

During the three and six months ended June 30, 2025, we paid $2.3 million and $4.8 million, respectively, in dividends to holders of the Series A Preferred Stock. As of June 30, 2025, we had accrued $2.2 million related to dividends to holders of the Series A Preferred Stock. This dividend was paid on July 15, 2025.

On February 19, 2025, we purchased 6,353 shares of our Series A Preferred Stock at a purchase price of $22.50 per share, in cash, less applicable withholding taxes and without interest, pursuant to a tender offer for the Series A Preferred Stock commenced in January 2025.

On April 1, 2025, we purchased 13,924 shares of our Series A Preferred Stock at a purchase price of $24.00 per share, in cash, less applicable withholding taxes and without interest, pursuant to a tender offer for the Series A Preferred Stock commenced in February 2025.

On May 9, 2025, we announced the redemption of 168,008 shares of our Series A Preferred Stock, for a redemption price of $25.00 per share, plus any declared and unpaid dividends on the Series A Preferred Stock through and including the redemption date, which was June 9, 2025. We paid $4.3 million for the redemption of 168,008 shares of our Series A Preferred Stock on June 9, 2025. 

On July 16, 2025, we announced the redemption of 319,216 shares of our Series A Preferred Stock, for a redemption price of $25.00 per share, plus any declared and unpaid dividends on the Series A Preferred Stock through and including the redemption date of August 15, 2025.

On July 16, 2025, we declared a quarterly cash dividend in the amount of $0.69732 per share of Series A Preferred Stock. The dividend will be paid on October 15, 2025 to holders of record on October 1, 2025 of the Series A Preferred Stock.

A summary of our preferred equity balance for the six months ended June 30, 2025 is as follows:
		(In thousands)	
Balance at December 31, 2024		$	83,221		
Repurchase of Series A Preferred Stock			(493)	
Redemption of Series A Preferred Stock			(4,081)	
Accumulated dividends on Series A Preferred Stock			(215)	
Balance at June 30, 2025		$	78,432		

6. Derivative Instruments 

We are exposed to the impact of market fluctuations in the price of electricity and natural gas, basis differences in the price of natural gas, storage charges, renewable energy credits (“RECs”), and capacity charges from independent system operators. We use derivative instruments in an effort to manage our cash flow exposure to these risks. These instruments are not designated as hedges for accounting purposes, and accordingly, changes in the market value of these derivative instruments are recorded in the cost of revenues. As part of our strategy to optimize pricing in our natural gas related activities, we also manage a portfolio of commodity derivative instruments held for trading purposes. Our commodity trading activities are subject to limits within our Risk Management Policy. For these derivative instruments, changes in the fair value are recognized currently in earnings in net asset optimization revenues.

Derivative assets and liabilities are presented net in our condensed consolidated balance sheets when the derivative instruments are executed with the same counterparty under a master netting arrangement. Our derivative contracts include transactions that are executed both on an exchange and centrally cleared, as well as over-the-counter, bilateral contracts that are transacted directly with third parties. To the extent we have paid or received collateral related to the derivative assets or liabilities, such amounts would be presented net against the related derivative asset or liability’s fair value. As of June 30, 2025 and December 31, 2024, we offset $0.2 million and zero, respectively, in collateral to net against the related derivative asset/liability’s fair value. The specific types of derivative instruments we may execute to manage the commodity price risk include the following:

•	Forward contracts, which commit us to purchase or sell energy commodities in the future; 
•	Futures contracts, which are exchange-traded standardized commitments to purchase or sell a commodity or financial instrument; 
•	Swap agreements, which require payments to or from counterparties based upon the differential between two prices for a predetermined notional quantity; and 
•	Option contracts, which convey to the option holder the right but not the obligation to purchase or sell a commodity.

The Company has entered into other energy-related contracts that do not meet the definition of a derivative instrument or for which we made a normal purchase, normal sale election and are therefore not accounted for at fair value including the following:

•	Forward electricity and natural gas purchase contracts for retail customer load;
•	Renewable energy credits; and 
•	Natural gas transportation contracts and storage agreements.

Volumes Underlying Derivative Transactions

The following table summarizes the net notional volumes of our open derivative financial instruments accounted for at fair value by commodity. Positive amounts represent net buys while bracketed amounts are net sell transactions (in thousands):
Non-trading 
Commodity	Notional		June 30, 2025		December 31, 2024	
Natural Gas	MMBtu			5,634				5,716		
Electricity	MWh			937				987		
Trading
Commodity	Notional		June 30, 2025		December 31, 2024	
Natural Gas	MMBtu			1,194				2,988		

Gains (Losses) on Derivative Instruments

Gains (losses) on derivative instruments, net and current period settlements on derivative instruments were as follows for the periods indicated (in thousands):
	Three Months Ended June 30,		Six Months Ended June 30,	
  	2025		2024		2025		2024	
(Loss) gain on non-trading derivatives, net	$	(6,400)		$	3,160			$	154			$	(1,136)	
(Loss) gain on trading derivatives, net		(12)			20				(2,180)			111		
(Loss) gain on derivatives, net	$	(6,412)		$	3,180			$	(2,026)		$	(1,025)	
Current period settlements on non-trading derivatives		1,288				7,683				(2,612)			22,925		
Current period settlements on trading derivatives		—				84				—				267		
Total current period settlements on derivatives	$	1,288			$	7,767			$	(2,612)		$	23,192		

Gains (losses) on trading derivative instruments are recorded in net asset optimization revenues and gains (losses) on non-trading derivative instruments are recorded in retail cost of revenues on the condensed consolidated statements of operations.

Fair Value of Derivative Instruments

The following tables summarize the fair value and offsetting amounts of our derivative instruments by counterparty and collateral received or paid (in thousands):
  	June 30, 2025	
Description	Gross Assets		Gross
Amounts
Offset		Net Assets		Cash
Collateral
Offset		Net Amount
Presented	
Non-trading commodity derivatives 	$	6,839			$	(4,200)		$	2,639			$	(128)		$	2,511		
Trading commodity derivatives		96				(1)			95				—				95		
Total Current Derivative Assets		6,935				(4,201)			2,734				(128)			2,606		
Non-trading commodity derivatives		1,044				(381)			663				—				663		
Trading commodity derivatives		51				(44)			7				—				7		
Total Non-current Derivative Assets		1,095				(425)			670				—				670		
Total Derivative Assets	$	8,030			$	(4,626)		$	3,404			$	(128)		$	3,276		

Description	Gross 
Liabilities		Gross
Amounts
Offset		Net
Liabilities		Cash
Collateral
Offset		Net Amount
Presented	
Non-trading commodity derivatives	$	(2,169)		$	1,798			$	(371)		$	107			$	(264)	
Trading commodity derivatives		(171)			60				(111)			—				(111)	
Total Current Derivative Liabilities		(2,340)			1,858				(482)			107				(375)	
Non-trading commodity derivatives		(351)			198				(153)			—				(153)	
Trading commodity derivatives		—				—				—				—				—		
Total Non-current Derivative Liabilities		(351)			198				(153)			—				(153)	
Total Derivative Liabilities	$	(2,691)		$	2,056			$	(635)		$	107			$	(528)	

  	December 31, 2024	
Description	Gross Assets		Gross
Amounts
Offset		Net Assets		Cash
Collateral
Offset		Net Amount
Presented	
Non-trading commodity derivatives	$	12,100			$	(5,443)		$	6,657			$	—			$	6,657		
Trading commodity derivatives		2,538				(510)			2,028				—				2,028		
Total Current Derivative Assets		14,638				(5,953)			8,685				—				8,685		
Non-trading commodity derivatives		737				(259)			478				—				478		
Trading commodity derivatives		—				—				—				—				—		
Total Non-current Derivative Assets		737				(259)			478				—				478		
Total Derivative Assets	$	15,375			$	(6,212)		$	9,163			$	—			$	9,163		

Description	Gross 
Liabilities		Gross
Amounts
Offset		Net
Liabilities		Cash
Collateral
Offset		Net Amount
Presented	
Non-trading commodity derivatives	$	(3,036)		$	1,475			$	(1,561)		$	—			$	(1,561)	
Trading commodity derivatives		(634)			494				(140)			—				(140)	
Total Current Derivative Liabilities		(3,670)			1,969				(1,701)			—				(1,701)	
Non-trading commodity derivatives		(333)			282				(51)			—				(51)	
Trading commodity derivatives		(94)			90				(4)			—				(4)	
Total Non-current Derivative Liabilities		(427)			372				(55)			—				(55)	
Total Derivative Liabilities	$	(4,097)		$	2,341			$	(1,756)		$	—			$	(1,756)	

7. Property and Equipment 

Property and equipment consist of the following (in thousands):
	Estimated useful
lives (years)		June 30, 2025		December 31, 2024	
Information technology	2 – 5		$	10,108			$	8,141		
Other	 7			69				69		
Total				10,177				8,210		
Accumulated depreciation				(3,733)			(2,979)	
Property and equipment—net			$	6,444			$	5,231		

Information technology assets include software and consultant time used in the application, development and implementation of various systems including customer billing and resource management systems. As of June 30, 2025 and December 31, 2024, information technology includes $2.3 million and $2.3 million, respectively, of costs associated with assets not yet placed into service. 

Depreciation expense recorded in the condensed consolidated statements of operations was $0.4 million and $0.3 million for the three months ended June 30, 2025 and 2024, respectively, and $0.7 million and $0.6 million for the six months ended June 30, 2025 and 2024, respectively.

8. Intangible Assets
Goodwill, customer relationships and trademarks consist of the following amounts (in thousands):
	June 30, 2025		December 31, 2024	
Goodwill	$	120,343			$	120,343		
Customer relationships—Other 				
Cost	$	16,396			$	12,852		
Accumulated amortization		(5,000)			(1,332)	
Customer relationships—Other, net	$	11,396			$	11,520		
Cost	$	4,040			$	4,040		
Accumulated amortization		(2,222)			(2,020)	
Trademarks, net	$	1,818			$	2,020		

Changes in goodwill, customer relationships (including non-compete agreements) and trademarks consisted of the following (in thousands):
	Goodwill 			Customer Relationships— Other		Trademarks	
Balance at December 31, 2024	$	120,343				$	11,520			$	2,020		
Additions 		—					3,486				—		
Amortization 		—					(3,610)			(202)	
Balance at June 30, 2025	$	120,343				$	11,396			$	1,818		

Estimated future amortization expense for customer relationships and trademarks at June 30, 2025 is as follows (in thousands):
Year ending December 31,		
2025 (remaining six months)	$	5,772		
2026		6,230		
2027		404		
2028		404		
2029		404		
> 5 years		—		
Total	$	13,214		

9. Debt 
Debt consists of the following amounts as of June 30, 2025 and December 31, 2024 (in thousands):
	June 30, 2025	December 31, 2024	
Long-term debt:			
  Senior Credit Facility (1) (2)	$	100,000		$	106,000		
  Subordinated Debt 		—			—		
Total long-term debt		100,000			106,000		
Total debt	$	100,000		$	106,000		
(1) As of June 30, 2025 and December 31, 2024, the weighted average interest rate on the Senior Credit Facility was 7.58% and 7.59%, respectively.
(2) As of June 30, 2025 and December 31, 2024, we had $31.2 million and $25.6 million in letters of credit issued, respectively.

Capitalized financing costs associated with our Senior Credit Facility (as defined below under "Senior Credit Facility") were $1.8 million and $1.7 million as of June 30, 2025 and December 31, 2024, respectively. Of these amounts, $0.9 million and $0.7 million are recorded in other current assets, and $0.9 million and $1.0 million are recorded in other non-current assets in the condensed consolidated balance sheets as of June 30, 2025 and December 31, 2024, respectively.

Interest expense consists of the following components for the periods indicated (in thousands):
	Three Months Ended June 30,		Six Months Ended June 30,	
	2025		2024		2025		2024	
Senior Credit Facility	$	1,298			$	1,094			$	2,893			$	2,429		
Letters of credit fees and commitment fees		71				337				111				721		
Amortization of deferred financing costs 		167				312				334				518		
Other		3				—				19				4		
Interest Expense	$	1,539			$	1,743			$	3,357			$	3,672		

Senior Credit Facility 

The Company and Spark Holdco (together with certain subsidiaries of the Company and Spark Holdco, the “Co-Borrowers”) maintain a senior secured borrowing base credit facility with Woodforest National Bank, as administrative agent (the “Agent”), swing bank, swap bank, issuing bank, joint-lead arranger, sole bookrunner and syndication agent, and the other financial institutions party thereto as lenders. As further described below, on June 28, 2024, the Company entered into the First Amendment (the "First Amendment") to its senior credit facility (as amended by the First Amendment, the “Senior Credit Facility”). The Senior Credit Facility matures on June 30, 2027. As a result of the First Amendment, we wrote off $0.1 million in deferred financing costs. 

On June 25, 2025, the Co-Borrowers entered into new arrangements with the Agent and the financial institutions party thereto, and other additional financial institutions, to increase the borrowing capacity under the Senior Credit Facility to $250.0 million from $205.0 million. 

Borrowings under the Senior Credit Facility are available for working capital loans, loans to fund acquisitions, swingline loans, letters of credit and, following the First Amendment, for repurchases of Series A Preferred Stock (subject to the terms and conditions therein).  

Borrowings under the Senior Credit Facility bear interest at the following rates depending on the classification of the borrowing and provided further that at no time shall the interest rate be less than four percent (4.0%) per annum:

•	The Base Rate (a rate per annum equal to the greatest of (a) the prime rate, (b) the Federal Funds Rate plus ½ of 1% and (c) Term Secured Overnight Financing Rate (“SOFR”) for a one month tenor plus 1.0%, provided, that the Base Rate shall not at any time be less than 0%), plus an applicable margin of 2.25% to 3.50% depending on the type of borrowing and the average outstanding amount of loans and letters of credit under the Senior Credit Facility at the end of the prior fiscal quarter;

•	The Term SOFR (a rate equal to the forward looking secured overnight financing rate published by the SOFR administrator on the website of the Federal Reserve Bank of New York or any successor source with either a comparable tenor (for any calculation with respect to a SOFR loan) or a one month tenor (for any calculation with respect to a Base Rate loan)), plus an applicable margin of 3.25% to 4.50% depending on the type of borrowing and the average outstanding amount of loans and letters of credit under the Senior Credit Facility at the end of the prior fiscal quarter; or

•	The Daily Simple SOFR (a rate equal to the forward looking secured overnight financing rate published by the SOFR administrator on the website of the Federal Reserve Bank of New York or any successor source and applied on a daily basis by the Agent in accordance with rate recommendations for daily loans), plus an applicable margin of 3.25% to 4.50% depending on the type of borrowing and the average outstanding amount of loans and letters of credit under the Senior Credit Facility at the end of the prior fiscal quarter, plus a liquidity premium added by the Agent to each borrowing.

The Co-Borrowers are required to pay a non-utilization fee of 0.50% quarterly in arrears on the unused portion of the Senior Credit Facility. In addition, the Co-Borrowers are subject to additional fees including an upfront fee, an annual administrative agency fee, an arrangement fee and letter of credit fees.

The Senior Credit Facility contains covenants that, among other things, require the maintenance of specified ratios or conditions including:

•	Minimum Fixed Charge Coverage Ratio. The Company must maintain a minimum fixed charge coverage ratio of not less than 1.10 to 1.00. The Minimum Fixed Charge Coverage Ratio is defined as the ratio of (a) Adjusted EBITDA to (b) the sum of, among other things, consolidated interest expense, letter of credit fees, non-utilization fees, earn-out payments, certain restricted payments, taxes, and payments made on or after July 31, 2020 related to the settlement of civil and regulatory matters if not included in the calculation of Adjusted EBITDA. Our Minimum Fixed Charge Coverage Ratio as of June 30, 2025 was 1.54 to 1.00.

•	Maximum Total Leverage Ratio. The Company must maintain a ratio of (x) the sum of all consolidated indebtedness (excluding eligible subordinated debt and letter of credit obligations), plus (y) gross amounts reserved for civil and regulatory liabilities identified in filings with the SEC, to Adjusted EBITDA of no more than 3.00 to 1.00. Our Maximum Total Leverage Ratio as of June 30, 2025 was 1.51 to 1.00.

The First Amendment to the Senior Credit Facility eliminated the Maximum Senior Secured Leverage Ratio covenant and amended the Maximum Total Leverage Ratio covenant to no more than 3.00 to 1.00 from no more than 2.50 to 1.00. 

As of June 30, 2025, the Company was in compliance with financial covenants under the Senior Credit Facility. The Company continues to manage the impact of commodity costs on financial covenant compliance. Maintaining compliance with our covenants under our Senior Credit Facility may impact our ability to pay dividends on our Series A Preferred Stock.

The Senior Credit Facility contains various customary affirmative covenants that require, among other things, the Company to maintain insurance, pay its obligations and comply with law. The Senior Credit Facility also contains customary negative covenants that limit the Company’s ability to, among other things, incur certain additional indebtedness, grant certain liens, engage in certain asset dispositions, merge or consolidate, make certain payments, distributions and dividends, investments, acquisitions or loans, materially modify certain agreements, and enter into transactions with affiliates.

The Senior Credit Facility is secured by pledges of the equity of the portion of Spark HoldCo owned by the Company, the equity of Spark HoldCo’s subsidiaries, the Co-Borrowers’ present and future subsidiaries, and substantially all of the Co-Borrowers’ and their subsidiaries’ present and future property and assets, including intellectual property assets, accounts receivable, inventory and liquid investments, and control agreements relating to bank accounts.

The Company is entitled to pay cash dividends to the holders of its Series A Preferred Stock stock so long as: (a) no default exists or would result therefrom; (b) the Co-Borrowers are in pro forma compliance with all financial covenants before and after giving effect thereto; and (c) the outstanding amount of all loans and letters of credit do not exceed the borrowing base limits.

The Senior Credit Facility contains certain customary representations and warranties and events of default. Events of default include, among other things, payment defaults, breaches of representations and warranties, covenant defaults, cross-defaults and cross-acceleration to certain indebtedness, certain events of bankruptcy, certain events under ERISA, material judgments in excess of $5.0 million, certain events with respect to material contracts, and actual or asserted failure of any guaranty or security document supporting the Senior Credit Facility to be in full force and effect. A default will also occur if at any time W. Keith Maxwell III ceases to, directly or indirectly, beneficially own at least fifty-one percent (51%) of the Company’s outstanding Class A common stock and Class B common stock on a combined basis, and a controlling percentage of the voting equity interest of the Company, and certain other changes in control. If such an event of default occurs, the lenders under the Senior Credit Facility would be entitled to take various actions, including the acceleration of amounts due under the facility and all actions permitted to be taken by a secured creditor.

Subordinated Debt Facility

The Company maintains an Amended and Restated Subordinated Promissory Note in the principal amount of up to $25.0 million (the “Subordinated Debt Facility”), by and among the Company, Spark HoldCo and Retailco. The Subordinated Debt Facility allows the Company to draw advances in increments of no less than $1.0 million per advance up to $25.0 million. In connection with entering into the First Amendment to the Senior Credit Facility, the Company entered into an amended and restated subordinated promissory note with Spark HoldCo and Retailco, which extends the maturity date of the note to January 31, 2028.

Borrowings are at the discretion of Retailco. Advances thereunder accrue interest at an annual rate equal to the prime rate as published by the Wall Street Journal plus two percent (2.0%) from the date of the advance.

The Company has the right to capitalize interest payments under the Subordinated Debt Facility. The Subordinated Debt Facility is subordinated in certain respects to our Senior Credit Facility pursuant to a subordination agreement. The Company may pay interest and prepay principal on the Subordinated Debt Facility so long it is in compliance with the covenants under the Senior Credit Facility, is not in default under the Senior Credit Facility and has minimum availability of $5.0 million under the borrowing base under the Senior Credit Facility. Payment of principal and interest under the Subordinated Debt Facility is accelerated upon the occurrence of certain change of control or sale transactions.

As of June 30, 2025, and December 31, 2024, there were zero outstanding borrowings under the Subordinated Debt Facility. 

10. Fair Value Measurements 

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes the credit standing of counterparties involved and the impact of credit enhancements.

We apply fair value measurements to our commodity derivative instruments based on the following fair value hierarchy, which prioritizes the inputs to the valuation techniques used to measure fair value into three broad levels:

•	Level 1—Quoted prices in active markets for identical assets and liabilities. Instruments categorized in Level 1 primarily consist of financial instruments such as exchange-traded derivative instruments. 
•	Level 2—Inputs other than quoted prices recorded in Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 primarily include non-exchange traded derivatives such as over-the-counter commodity forwards and swaps and options. 
•	Level 3—Unobservable inputs for the asset or liability, including situations where there is little, if any, observable market activity for the asset or liability. The Level 3 category includes estimated earnout obligations related to our acquisitions.

As the fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3), the Company maximizes the use of observable inputs and minimizes the use of unobservable inputs when measuring fair value. These levels can change over time. In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following tables present assets and liabilities measured and recorded at fair value in our condensed consolidated balance sheets on a recurring basis by and their level within the fair value hierarchy (in thousands):

	Level 1		Level 2		Level 3		Total	
June 30, 2025								
Non-trading commodity derivative assets	$	567			$	2,607			$	—			$	3,174		
Trading commodity derivative assets		—				102				—				102		
Total commodity derivative assets	$	567			$	2,709			$	—			$	3,276		
Non-trading commodity derivative liabilities	$	—			$	(417)		$	—			$	(417)	
Trading commodity derivative liabilities		—				(111)			—				(111)	
Total commodity derivative liabilities	$	—			$	(528)		$	—			$	(528)	

	Level 1		Level 2		Level 3		Total	
December 31, 2024								
Non-trading commodity derivative assets	$	445			$	6,690			$	—			$	7,135		
Trading commodity derivative assets		—				2,028				—				2,028		
Total commodity derivative assets	$	445			$	8,718			$	—			$	9,163		
Non-trading commodity derivative liabilities	$	(180)		$	(1,432)		$	—			$	(1,612)	
Trading commodity derivative liabilities		—				(144)			—				(144)	
Total commodity derivative liabilities	$	(180)		$	(1,576)		$	—			$	(1,756)	

We had no transfers of assets or liabilities between any of the above levels during the six months ended June 30, 2025 and the year ended December 31, 2024.

Our derivative contracts include exchange-traded contracts valued utilizing readily available quoted market prices and non-exchange-traded contracts valued using market price quotations available through brokers or over-the-counter and on-line exchanges. In addition, in determining the fair value of our derivative contracts, we apply a credit risk valuation adjustment to reflect credit risk, which is calculated based on our or the counterparty’s historical credit risks. As of June 30, 2025 and December 31, 2024, the credit risk valuation adjustment was a reduction of derivative assets, net of less than $0.1 million and $0.1 million, respectively.

11. Income Taxes 

Income Taxes 

We and our subsidiaries, CenStar and Verde Energy USA, Inc. (“Verde Corp”) are each subject to U.S. federal income tax as corporations. CenStar and Verde Corp file consolidated tax returns in jurisdictions that allow combined reporting. Spark HoldCo and its subsidiaries, with the exception of CenStar and Verde Corp, are treated as flow-through entities for U.S. federal income tax purposes, and, as such, are generally not subject to U.S. federal income tax at the entity level. Rather, the tax liability with respect to their taxable income is passed through to their members or partners. Accordingly, we are subject to U.S. federal income taxation on our allocable share of Spark HoldCo’s net U.S. taxable income.

In our financial statements, we report federal and state income taxes for our share of the partnership income attributable to our ownership in Spark HoldCo and for the income taxes attributable to CenStar and Verde Corp. Net income attributable to non-controlling interest includes the provision for income taxes related to CenStar and Verde Corp.

We account for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and the tax bases of the assets and liabilities. We apply existing tax law and the tax rate that we expect to apply to taxable income in the years in which those differences are expected to be recovered or settled in calculating the deferred tax assets and liabilities. Effects of changes in tax rates on deferred tax assets and liabilities are recognized in income in the period of the tax rate enactment. A valuation allowance is recorded when it is not more likely than not that some or all of the benefit from the deferred tax asset will be realized.

We periodically assess whether it is more likely than not that we will generate sufficient taxable income to realize our deferred income tax assets. In making this determination, we consider all available positive and negative evidence and make certain assumptions. We consider, among other things, our deferred tax liabilities, the overall business environment, our historical earnings and losses, current industry trends, and our outlook for future years. We believe it is more likely than not that our deferred tax assets will be utilized, and accordingly have not recorded a valuation allowance on these assets.

As of June 30, 2025, we had a net deferred tax asset of $4.8 million, due in large part to the original step up in tax basis resulting from the initial purchase of Spark HoldCo units from NuDevco Retail and NuDevco Retail Holdings (predecessor to Retailco) in connection with our initial public offering.

The effective U.S. federal and state income tax rate for the three months ended June 30, 2025 and 2024 was 30.5% and 17.0%, respectively. The effective U.S. federal and state income tax rate for the six months ended June 30, 2025 and 2024 was 21.7% and 18.6%, respectively. The effective tax rate for three and six months ended June 30, 2025 differed from the U.S. federal statutory tax rate of 21% primarily due to state taxes and the benefit provided from Spark HoldCo operating as a limited liability company, which is treated as a partnership for federal and state income tax purposes and is not subject to federal and state income taxes. Accordingly, the portion of earnings attributable to non-controlling interest is subject to tax when reported as a component of the non-controlling interest holders’ taxable income.

12. Commitments and Contingencies

From time to time, we may be involved in legal, tax, regulatory and other proceedings in the ordinary course of business. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.

Legal Proceedings

Below is a summary of our currently pending material legal proceedings. We are subject to lawsuits and claims arising in the ordinary course of our business. The following legal proceedings are in various stages and are subject to substantial uncertainties concerning the outcome of material factual and legal issues. Accordingly, unless otherwise specifically noted, we cannot currently predict the manner and timing of the resolutions of these legal proceedings or estimate a range of possible losses or a minimum loss that could result from an adverse verdict in a potential lawsuit. While the lawsuits and claims are asserted for amounts that may be material should an unfavorable outcome occur, management does not currently expect that any currently pending matters will have a material adverse effect on our financial position or results of operations.

Consumer Lawsuits

Similar to other energy service companies (“ESCOs”) operating in the industry, from time-to-time, the Company is subject to class action lawsuits in various jurisdictions where the Company sells natural gas and electricity.

On January 14, 2021, Glikin, et al. v. Major Energy Electric Services, LLC, a purported variable rate class action was filed by a Maryland customer in the United States District Court, Southern District of New York, attempting to represent a class of all Major Energy customers (including customers of companies Major Energy acts as a successor to) in the United States charged a variable rate for electricity or gas by Major Energy during the applicable statute of limitations period up to and including the date of judgment. The Company moved this case to the United States District Court for the District of Maryland (Case No. 1:21-cv-03251-MJM) and in December 2023 filed a motion to dismiss the lawsuit. In September 2024, the Court granted the Company’s motion that argued that Glikin had failed to exhaust her administrative remedies and that, if she wishes to proceed, she must first go to the Maryland Public Service Commission (“Maryland PSC”). On November 6, 2024, Glikin filed a complaint with the Maryland PSC. The Company responded to her complaint on February 28, 2025.  On May 2025, the PSC ruled in favor of the Company, finding no fraudulent conduct. Plaintiff filed a motion to lift the federal court stay on June 16, 2025. The Company intends to seek dismissal based on the favorable PSC determination.

From time-to-time the Company and its operating subsidiaries receive TCPA-based lawsuits, which are without merit as the Company has a robust telemarketing compliance program in place. Three cases are pending, at early stages of litigation: (1) Clark v. Via Renewables, Inc. (filed January 30, 2024), and (2) Grant v. Via Renewables, Inc. (November 15, 2024).  The Company is vigorously defending these claims.

Corporate Matter Lawsuits

The Company may from time to time be subject to legal proceedings that arise in the ordinary course of business. Although there can be no assurance in this regard, the Company does not expect any of those legal proceedings to have a material adverse effect on the Company’s results of operations, cash flows or financial condition.

On July 19, 2024, Joshua Amburgey, a purported stockholder of the Company at the time of the Merger, filed a verified class action complaint, Joshua Amburgey, on behalf of himself and all others similarly situated v. Via Renewables, Inc., et al., Case No. 2024-0762-KSJM (Del. Ch.) (the “Amburgey Action”) in the Court of Chancery of the State of Delaware (“Delaware Court”) against the Company and Amanda E. Bush, Stephen Kennedy and Kenneth Hartwick in their capacities as members of the Company’s Special Transaction Committee of the Board of Directors (“Special Committee”), as well as Mr. Maxwell, Retailco, LLC, TxEx Energy Investments, LLC, Electric Holdco, LLC, NuDevco Retail Holdings, LLC and NuDevco Retail, LLC. Plaintiff alleges that the defendants breached their fiduciary duties owed to the Company’s public stockholders in connection with the Merger. This matter is pending before the Delaware Chancery Court.

On July 25, 2024, Bruce Taylor, a purported stockholder of the Company at the time of the Merger, filed a verified class action complaint, Bruce Taylor v. W. Keith Maxwell III, et al., Case No. 2024-0794 (Del. Ch.) (the “Taylor Action”) in the Delaware Court against the Special Committee, and Mike Barajas, in his capacity as the Company’s Chief Financial Officer, as well as Mr. Maxwell in his capacity as controlling stockholder of the Company. Plaintiff alleges that the defendants breached their fiduciary duties and participated in the provision of a materially untrue and misleading proxy statement to Company’s minority stockholders in connection with the Merger. This matter is pending before the Delaware Chancery Court.

Regulatory Matters

Many state regulators have increased scrutiny on retail energy providers, across all industry providers. We are subject to regular regulatory inquiries, license renewal reviews, and preliminary investigations in the ordinary course of our business. Below is a summary of our currently pending material state regulatory matters. The following state regulatory matters are in various stages and are subject to substantial uncertainties concerning the outcome of material factual and legal issues. Accordingly, we cannot currently predict the manner and timing of the resolution of these state regulatory matters or estimate a range of possible losses or a minimum loss that could result from an adverse action. Management does not currently expect that any currently pending state regulatory matters will have a material adverse effect on our financial position or results of operations.

Illinois. On July 26, 2023, Spark Energy, LLC received a demand letter from a law firm representing the Office of the Illinois Attorney General alleging that Spark Energy, LLC’s marketing and sales practices may have not been in compliance with Illinois law. The letter offered, in the interest of efficiency and minimizing litigation costs, a settlement demand to resolve the matter. The Company has agreed to engage in mediation with the law firm to try to resolve this matter. The Company met for an all-day mediation in August 2024 and several other virtual settlement discussions. The settlement discussions were unsuccessful, and the Attorney General commenced a lawsuit in Illinois against Spark Energy, LLC and Spark Energy Gas, LCC on January 16, 2025 (“IL AG State Action”). Spark filed a motion to dismiss (“MTD”) the IL AG State Action and simultaneously, proactively filed a federal action raising constitutional issues (“Federal Action”). The IL AG filed its reply to the MTD on June 17, 2025.  Spark responded to the IL AG’s early July 2025.  All actions are in the early stages, and the parties have resumed settlement negotiations.

Maine.  On February 9, 2023, Maine Commission’s Consumer Assistance and Safety Division (“Advocacy Staff”) filed a Request for Formal Investigation requesting that the Maine Commission open a formal, enforcement investigation to review whether Company’s subsidiary, Electricity Maine, LLC (EME), is in compliance with the Maine Commission’s Rules. During a special deliberative session, the same day, the Maine Commission announced it would proceed with a formal investigation of EME, which was noticed in a Notice of Enforcement Investigation issued February 10, 2023 (Docket No. 2023-00024). The Company met with Advocacy Staff over the course of several months to address concerns. As a result, the Company and the Advocacy Staff have agreed to a settlement in principle pursuant to which customers would receive certain limited refunds on their energy bill and the Company would be fined.  On October 18, 2024, the Maine Commission approved EME’s proposed settlement. The Company has paid the fine and has been making such refunds to customers which will conclude in 2025.

Maryland.  Maryland SB1, sponsored by Senator Augustine (D-Prince George’s County) and Delegate Crosby (D- St. Mary’s County), was signed into law in May 2024.  In addition to numerous green energy requirements, pricing restrictions, and burdensome new consumer protections, Maryland SB1 prohibits residential purchase of receivables (POR) for contracts executed or renewed after December 31, 2024. Maryland SB1's effect has been to largely make it extremely difficult for all retail energy providers to offer Maryland residential consumers energy choice. The Company is working to minimize economic impacts of Maryland SB1 to the Company.

Massachusetts. In February 2025, the Massachusetts Department of Public Utilities opened a new docket, DP 19-07, and has met twice with industry participants to address concerns it has in the retail energy market.  The focus of DP 19-07 is (i) limiting green energy offerings in Massachusetts to Class I Massachusetts renewable energy credits (i.e., renewable energy from projects built after 1997 and located within the New England region) and (ii) only permitting retail energy sales on the government’s consumer shopping website.  This proposal, if enacted, would affect all retail energy providers in Massachusetts, making it more costly to provide green energy offerings and extremely difficult to offer Massachusetts residential consumers energy choice. The Company is working to minimize economic impacts of the Massachusetts proposal to the Company.

Ohio.  On August 14, 2024, the Public Utility Commission of Ohio (“PUCO”) sent Major Energy a notice of probable non-compliance regarding approximately fifty-five consumer complaints during the time period January 3, 2023 through April 12, 2024. The Company has worked cooperatively with PUCO and the Ohio Office of Consumer Counsel to resolve this matter, and believes this matter will not have a material impact on the Company.

In addition to the matters disclosed above, in the ordinary course of business, the Company may from time to time be subject to regulators initiating informal reviews or issuing subpoenas for information as means to evaluate the Company and its subsidiaries’ compliance with applicable laws, rules, regulations and practices. Although there can be no assurance in this regard, the Company does not expect any of those regulatory reviews to have a material adverse effect on the Company’s results of operations, cash flows or financial condition.

Indirect Tax Audits

We are undergoing various types of indirect tax audits spanning from years 2023 to 2025 for which additional liabilities may arise. At the time of filing these consolidated financial statements, these indirect tax audits are at an early stage and subject to substantial uncertainties concerning the outcome of audit findings and corresponding responses.

As of June 30, 2025 and December 31, 2024, we had accrued $10.2 million and $11.9 million, respectively, related to litigation and regulatory matters and  zero and $0.8 million, respectively, related to indirect tax audits. The accrual for litigation and regulatory matters, and indirect tax audits is recorded in accrued liabilities on the balance sheet. The outcome of each of these may result in additional expense.

13. Transactions with Affiliates

Transactions with Affiliates

We enter into transactions with and pay certain costs on behalf of affiliates that are commonly controlled in order to reduce risk, reduce administrative expense, create economies of scale, create strategic alliances and supply goods and services to these related parties. We also sell and purchase natural gas and electricity with affiliates. We present receivables and payables with the same affiliate on a net basis in the condensed consolidated balance sheets as all affiliate activity is with parties under common control. Affiliated transactions include certain services to the affiliated companies associated with employee benefits provided through our benefit plans, insurance plans, leased office space, administrative salaries, due diligence work, recurring management consulting, and accounting, tax, legal, or technology services. Amounts billed are based on the services provided, departmental usage, or headcount, which are considered reasonable by management. As such, the accompanying condensed consolidated financial statements include costs that have been incurred by us and then directly billed or allocated to affiliates, as well as costs that have been incurred by our affiliates and then directly billed or allocated to us, and are recorded net in general and administrative expense on the condensed consolidated statements of operations with a corresponding accounts receivable—affiliates or accounts payable—affiliates, respectively recorded in the condensed consolidated balance sheets. Transactions with affiliates for sales or purchases of natural gas and electricity are recorded in retail revenues, retail cost of revenues, and net asset optimization revenues in the condensed consolidated statements of operations with a corresponding accounts receivable—affiliate or accounts payable—affiliate recorded in the condensed consolidated balance sheets.

The following tables presents asset and liability balances with affiliates (in thousands):

	June 30, 2025		December 31, 2024	
Assets				
Accounts Receivable - affiliates	$	3,941			$	4,119		
Total Assets - affiliates	$	3,941			$	4,119		

	June 30, 2025		December 31, 2024	
Liabilities				
Accounts Payable - affiliates	$	478			$	157		
Subordinated Debt - affiliates 		—				—		
Total Liabilities - affiliates	$	478			$	157		

The following table presents revenues and cost of revenues recorded in net asset optimization revenue associated with affiliates for the periods indicated (in thousands):

	Three Months Ended June 30,		Six Months Ended June 30,	
	2025		2024		2025		2024	
Revenue NAO - affiliates 	$	102			$	126			$	760			$	608		
Less: Cost of Revenue NAO - affiliates 		—				—				—				1		
Net NAO - affiliates	$	102			$	126			$	760			$	607		

The Company's retail cost of revenue includes gains/(losses) related to derivative instruments transactions with affiliates. For the three months ended June 30, 2025 and June 30, 2024, respectively, we recognized a gain of less than $0.1 million and gain of $0.1 million, respectively, in retail cost of revenue related to derivative instrument settlements. For the six months ended June 30, 2025 and June 30, 2024, respectively, we recognized a loss of $0.1 million and a gain of $0.8 million, respectively, in retail cost of revenue related to derivative instrument settlements.

Cost Allocations

Where costs incurred on behalf of the affiliate or us cannot be determined by specific identification for direct billing, the costs are allocated to the affiliated entities or us based on estimates of percentage of departmental usage, wages or headcount. The total net amount direct billed and allocated to/(from) affiliates was $(0.5) million and $(4.5) million for the three months ended June 30, 2025 and 2024, respectively. The total net amount direct billed and allocated to/(from) affiliates was $(1.0) million and $(4.1) million for the six months ended June 30, 2025 and 2024, respectively. The Company would have incurred incremental costs of $0.5 million and $0.3 million for the  three months ended June 30, 2025 and 2024, respectively, operating on a stand-alone basis. The Company would have incurred incremental costs of $0.9 million and $0.6 million for the six months ended June 30, 2025 and 2024, respectively, operating on a stand-alone basis.

Distributions to and Contributions from Affiliates

During the three months ended June 30, 2025 and 2024, Spark HoldCo made distributions to these affiliates for gross-up distributions of $4.9 million and $4.4 million, respectively, in connection with distributions made between Spark HoldCo and Via Renewables, Inc. for payment of income taxes incurred by us. 

During the six months ended June 30, 2025 and 2024, Spark HoldCo made distributions to these affiliates for gross-up distributions of $4.9 million and $4.5 million, respectively, in connection with distributions made between Spark HoldCo and Via Renewables, Inc. for payment of income taxes incurred by us.

As discussed in Note 4 – Equity, on December 31, 2024, Spark HoldCo distributed $5.0 million in cash to the non-controlling interest holder, and the non-controlling interest holder transferred 206,273 shares of Class B common stock to the Company. On March 31, 2025, Spark HoldCo distributed $6.0 million in cash to the non-controlling interest holder, and the non-controlling interest holder transferred 262,891 shares of Class B common stock to the Company. 

During the three months ended June 30, 2025, Spark HoldCo distributed $3.0 million in cash to the non-controlling interest holder.

Membership Interest Purchase Agreement with NGE Holdco, LLC and Spark Holdco, LLC

On May 23, 2025, we entered into an agreement to acquire 100% of the membership interests in NGE Texas, LLC (“NGE Texas”) for a nominal purchase price of $1 and a working capital payment of approximately $1.0 million, consisting entirely of restricted cash in the form of a Letter of Credit and ERCOT collateral. The primary purpose of the transaction was to obtain NGE Texas’s existing Texas retail electricity license, which is required to operate as a retail electricity provider in the state of Texas.

Subordinated Debt Facility 

The Company maintains an Amended and Restated Subordinated Promissory Note in the principal amount of up to $25.0 million (the “Subordinated Debt Facility”), by and among the Company, Spark HoldCo and Retailco. The Subordinated Debt Facility allows the Company to draw advances in increments of no less than $1.0 million per advance up to $25.0 million through January 31, 2028. In connection with entering into the First Amendment to the Senior Credit Facility, the Company entered into an amended and restated subordinated promissory note with Spark HoldCo and Retailco, which extends the maturity date of the note to January 31, 2028. Borrowings are at the discretion of Retailco. Advances thereunder accrue interest at an annual rate equal to the prime rate as published by the Wall Street Journal plus two percent (2.0%) from the date of the advance.

As of June 30, 2025 and  December 31, 2024, there were zero outstanding borrowings under the Subordinated Debt Facility. See Note 9 “Debt” for a further description of terms and conditions of the Subordinated Debt Facility.

14. Segment Reporting 

Our reportable business segments are retail electricity and retail natural gas. The retail electricity segment consists of electricity sales and transmission to residential and commercial customers. The retail natural gas segment consists of natural gas sales to, and natural gas transportation and distribution for, residential and commercial customers. The Chief Executive Officer, who is also the Chief Operating Decision Maker (“CODM”), determines the reportable business segments by considering the strategic operating units used to make financial decisions, allocate resources and assess performance of our business.

The primary metric used by the CODM in managing the Company, assessing segment performance, and allocating resources is retail gross margin. We use retail gross margin to assess the performance of our operating segments. We define retail gross margin as gross profit less (i) net asset optimization (expenses) revenues, (ii) net (losses) gains on non-trading derivative instruments, (iii) net current period cash settlements on non-trading derivative instruments, and (iv) gains (losses) from non-recurring events (including non-recurring market volatility).

We deduct net gains (losses) on non-trading derivative instruments, excluding current period cash settlements, from the retail gross margin calculation in order to remove the non-cash impact of net gains and losses on these derivative instruments. We deduct net gains (losses) from non-recurring events (including non-recurring market volatility) to ensure retail gross margin reflects operating performance that is not distorted by non-recurring events or extreme market volatility. Retail gross margin should not be considered an alternative to, or more meaningful than, operating income (loss), as determined in accordance with GAAP.

The Company’s CODM reviews significant expenses on a consolidated level.

  	30,	

Financial data for business segments are as follows (in thousands):
Three Months Ended June 30, 2025	
	Retail
Electricity (1)		Retail
Natural Gas		Corporate
and Other		Eliminations		Consolidated	
Total revenues	$	66,810			$	23,825			$	(606)		$	—			$	90,029		
Retail cost of revenues		46,607				16,439				9				—				63,055		
Less:										
Net asset optimization expense(2)		—				—				(636)			—				(636)	
Net, loss on non-trading derivative instruments		(4,842)			(1,558)			—				—				(6,400)	
Current period settlements on non-trading derivatives		1,514				(226)			—				—				1,288		
Retail Gross Margin	$	23,531			$	9,170			$	21			$	—			$	32,722		
Add: Reconciling items (3)										(5,748)	
Gross Profit									$	26,974		
Total Assets at June 30, 2025	$	2,062,179			$	197,693			$	334,443			$	(2,277,972)		$	316,343		
Goodwill at June 30, 2025	$	117,813			$	2,530			$	—			$	—			$	120,343		
(1) Retail Electricity includes related services.
(2) For the three months ended June 30, 2025 we recorded asset optimization revenues of $2.8 million and asset optimization cost of revenues of $3.4 million, which are presented on a net basis in asset optimization revenues.
(3) Reconciling item includes net asset optimization expenses, net loss and gain on non-trading derivative instruments and current period settlements on non-trading activities.

Three Months Ended June 30, 2024	
	Retail
Electricity(1)		Retail
Natural Gas		Corporate
and Other		Eliminations		Consolidated	
Total revenues	$	71,148			$	15,812			$	(264)		$	—			$	86,696		
Retail cost of revenues		37,127				5,663				207				—				42,997		
Less:										
Net asset optimization expense (2)		—				—				(531)			—				(531)	
Net, loss on non-trading derivative instruments		2,607				553				—				—				3,160		
Current period settlements on non-trading derivatives		6,103				1,580				—				—				7,683		
Retail Gross Margin	$	25,311			$	8,016			$	60			$	—			$	33,387		
Add: Reconciling items (3)										10,312		
Gross Profit									$	43,699		
Total Assets at December 31, 2024	$	1,867,055			$	126,911			$	317,408			$	(1,966,435)		$	344,939		
Goodwill at December 31, 2024	$	117,813			$	2,530			$	—			$	—			$	120,343		

(1) Retail Electricity includes related services.
(2) For the three months ended June 30, 2024, we recorded asset optimization revenues of  $3.2 million and asset optimization cost of revenues and $3.7 million, respectively, which are presented on a net basis in asset optimization revenues.
(3) Reconciling item includes net asset optimization expenses, net loss and gain on non-trading derivative instruments and current period settlements on non-trading activities.

Six Months Ended June 30, 2025	
	Retail
Electricity(1)		Retail
Natural Gas		Corporate
and Other		Eliminations		Consolidated	
Total revenues	$	147,530			$	87,608			$	(2,852)		$	—			$	232,286		
Retail cost of revenues		104,809				53,628				11				—				158,448		
Less:										
Net asset optimization expense (2)		—				—				(2,885)			—				(2,885)	
Net, gain on non-trading derivatives		21				133				—				—				154		
Current period settlements on non-trading derivatives		(2,245)			(367)			—				—				(2,612)	
Retail Gross Margin	$	44,945			$	34,214			$	22			$	—			$	79,181		
Add: Reconciling items (3)										(5,343)	
Gross Profit									$	73,838		
Total Assets at June 30, 2025	$	2,062,179			$	197,693			$	334,443			$	(2,277,972)		$	316,343		
Goodwill at June 30, 2025	$	117,813			$	2,530			$	—			$	—			$	120,343		
(1) Retail Electricity includes related services.
(2) For the six months ended June 30, 2025, we recorded asset optimization revenues of $22.8 million and asset optimization cost of revenues of  $25.7 million, which are presented on a net basis in asset optimization revenues.
(3) Reconciling item includes net asset optimization expenses, net loss and gain on non-trading derivative instruments, and current period settlements on non-trading activities.

Six Months Ended June 30, 2024	
	Retail
Electricity(1)		Retail
Natural Gas		Corporate
and Other		Eliminations		Consolidated	
Total revenues	$	148,477			$	52,871			$	(596)		$	—			$	200,752		
Retail cost of revenues		86,258				24,866				835				—				111,959		
Less:										
Net asset optimization expense (2)		—				—				(2,128)			—				(2,128)	
Net, loss on non-trading derivatives		(1,229)			93				—				—				(1,136)	
Current period settlements on non-trading derivatives		19,226				3,699				—				—				22,925		
Retail Gross Margin	$	44,222			$	24,213			$	697			$	—			$	69,132		
Add: Reconciling items (3)										19,661		
Gross Profit									$	88,793		
Total Assets at December 31, 2024	$	1,867,055			$	126,911			$	317,408			$	(1,966,435)		$	344,939		
Goodwill at December 31, 2024	$	117,813			$	2,530			$	—			$	—			$	120,343		
(1) Reconciling item includes net asset optimization expenses, net loss and gain on non-trading derivative instruments, and current period settlements on non-trading activities.
(2) For the six months ended June 30, 2024, we recorded asset optimization revenues of $14.7 million and asset optimization cost of revenues of $16.8 million, which are presented on a net basis in net asset optimization revenues.
(3) Reconciling item includes net asset optimization expenses, net loss and gain on non-trading derivative instruments, and current period settlements on non-trading activities.

15. Customer Acquisitions 
Acquisition of Customer Books 

In April 2024, we entered into an asset purchase agreement to acquire up to approximately 12,556 residential customer equivalents ("RCEs") for a cash purchase price of up to a maximum of $2.3 million. These customers began transferring in June of 2024, and were in our existing markets. As part of the acquisition, we funded an escrow account, the balance of which was reflected as restricted cash in our condensed consolidated balance sheet. As we acquired customers, we made payments to the sellers from the escrow account. As of December 31, 2024, we completed this acquisition and approximately 9,300 RCEs were transferred. The balance of $0.4 million in the escrow account as of December 31, 2024, was returned to the Company in the first quarter of 2025. As of June 30, 2025, the balance in the escrow account was zero. 

In October 2024, we entered into two asset purchase agreements to acquire up to 100,600 RCEs for a cash purchase price of up to a maximum $16.9 million paid in cash or funded into escrow accounts. These customers are located in our existing markets and began transferring in December 2024 and January 2025. As we acquired customers under these acquisition agreements, we made payments to the sellers from the escrow accounts. Funds from the escrow account were released to the sellers as acquired customers transferred from the sellers to the Company in accordance with the asset purchase agreement, and any unallocated balance will be returned to the Company once the acquisitions are complete. As of December 31, 2024, approximately 72,700 RCEs were transferred. During the six months ended June 30, 2025, approximately 26,300 RCEs were transferred for a total of approximately 99,000 RCEs as of June 30, 2025 related to customer book acquisitions. As of June 30, 2025 and December 31, 2024, the balance is the escrow accounts was $1.0 million and $15.5 million, respectively.

In April and May 2025, we entered into two asset purchase agreements to acquire up to 16,800 RCEs for a cash purchase price of up to a maximum $1.8 million paid in cash or funded into escrow accounts. These gas customers are located in our existing markets and began transferring in May 2025 and June 2025. As we acquired customers under these acquisition agreements, we will make payments to the sellers from the escrow accounts. Funds from the escrow account will be released to the sellers as acquired customers transfer from the sellers to the Company in accordance with the asset purchase agreement, and any unallocated balance will be returned to the Company once the acquisitions are complete. During the six months ended June 30, 2025, approximately 9,300 RCEs were transferred related to customer book acquisitions, and we paid $0.4 million to the sellers. As of June 30, 2025, the balance is the escrow accounts was $1.4 million.

16. Subsequent Events

Declaration of Dividends

On July 16, 2025 we declared a quarterly cash dividend in the amount of $0.69732 per share to holders of record of the Series A Preferred Stock on October 1, 2025. The dividend will be paid on October 15, 2025.

Partial Redemption of Series A Preferred Stock

On July 16, 2025, we announced the redemption of 319,216 shares of our Series A Preferred Stock for a redemption price of $25.00 per share, plus any declared and unpaid dividends on the Series A Preferred Stock through and including the redemption date, which will be August 15, 2025.     

One Big Beautiful Bill Act

On July 4th, 2025, the One Big Beautiful Bill Act (“OBBB”) was signed into law. The OBBB makes changes to U.S. tax law and includes provisions that beginning in January 2025, make permanent full expensing of tangible personal property, restores EBITDA-based calculations for purposes of the business interest deduction and allows for current expensing of R&D expenditures. ASC 740-10 requires the impact of changes to tax law to be recorded during the period of enactment, which will be reflected in our third quarter financial statements. We expect that OBBB will provide some reductions in cash taxes, however we do not anticipate the OBBB to materially impact income tax expense.  

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the unaudited condensed consolidated financial statements and the related notes thereto included elsewhere in this Report and the audited consolidated financial statements and notes thereto and management’s discussion and analysis of financial condition and results of operations included in our 2024 Form 10-K filed with the Securities and Exchange Commission (“SEC”) on March 6, 2025. Results of operations and cash flows for the three and six months ended June 30, 2025 are not necessarily indicative of results to be attained for any other period. See “Cautionary Note Regarding Forward-Looking Statements” and “Risk Factors.”

Overview

We are an independent retail energy services company founded in 1999 and are organized as a Delaware corporation that provides residential and commercial customers in competitive markets across the United States with an alternative choice for natural gas and electricity. We purchase our electricity and natural gas supply from a variety of wholesale providers and bill our customers monthly for the delivery of electricity and natural gas based on their consumption at either a fixed or variable price. Electricity and natural gas are then distributed to our customers by local regulated utility companies through their existing infrastructure. As of June 30, 2025, we operated in 106 utility service territories across 21 states and the District of Columbia.

Our business consists of two operating segments:

•	Retail Electricity Segment. In this segment, we purchase electricity supply through physical and financial transactions with market counterparties and ISOs and supply electricity to residential and commercial consumers pursuant to fixed-price and variable-price contracts. For the three months ended June 30, 2025 and 2024, approximately 74% and 82%, respectively, of our retail revenues were derived from the sale of electricity.

•	Retail Natural Gas Segment. In this segment, we purchase natural gas supply through physical and financial transactions with market counterparties and supply natural gas to residential and commercial consumers pursuant to fixed-price and variable-price contracts. For the three months ended June 30, 2025 and 2024, approximately 26% and 18%, respectively, of our retail revenues were derived from the sale of natural gas.

Recent Developments

Partial Redemption of Series A Preferred Stock

On May 9, 2025, we announced the redemption of 168,008 shares of our Series A Preferred Stock for a redemption price of $25.00 per share, plus any declared and unpaid dividends on the Series A Preferred Stock through and including the redemption date, which was June 9, 2025. 

On July 16, 2025, we announced the redemption of 319,216 shares of our Series A Preferred Stock for a redemption price of $25.00 per share, plus any declared and unpaid dividends on the Series A Preferred Stock through and including the redemption date, which will be August 15, 2025.

Membership Interest Purchase Agreement with NGE Holdco, LLC and Spark Holdco, LLC

On May 23, 2025, we entered into an agreement to acquire 100% of the membership interests in NGE Texas, LLC (“NGE Texas”) for a nominal purchase price of $1 and a working capital payment of approximately $1.0 million, consisting entirely of restricted cash in the form of a Letter of Credit and ERCOT collateral. The primary purpose of the transaction was to obtain NGE Texas’s existing Texas retail electricity license, which is required to operate as a retail electricity provider in the state of Texas.

Senior Credit Facility.

On June 25, 2025, the Co-Borrowers entered into new arrangements with the Agent and the financial institutions party thereto,and other additional financial institutions, to increase the borrowing capacity under the Senior Credit Facility to $250.0 million from $205.0 million.

Acquisition of Customer Books 

In April and May 2025, we entered into two asset purchase agreements to acquire up to 16,800 RCEs for a cash purchase price of up to a maximum $1.8 million paid in cash or funded into escrow accounts. These gas customers are located in our existing markets and began transferring in May 2025 and June 2025. As of June 30, 2025, approximately 9,300 RCEs were transferred as a result of the asset purchase agreement.

Residential Customer Equivalents

We measure our number of customers using residential customer equivalents (“RCEs”). The following table shows our RCEs by segment during the three and six months ended June 30, 2025:
RCEs:						
(In thousands)	March 31, 2025	Additions	Attrition	June 30, 2025	% Increase (Decrease)	
Retail Electricity	212	29	29	212	—%	
Retail Natural Gas	195	8	13	190	(3)%	
Total Retail	407	37	42	402	(1)%	

RCEs:						
(In thousands)	December 31, 2024	Additions	Attrition	June 30, 2025	% Increase (Decrease) 	
Retail Electricity	232	48	68	212	(9)%	
Retail Natural Gas 	156	59	25	190	22%	
Total Retail 	388	107	93	402	4%	

						
The following table details our count of RCEs by geographical location as of June 30, 2025:
RCEs by Geographic Location:							
(In thousands)	Electricity	 % of Total	Natural Gas	 % of Total	Total	 % of Total 	
New England	47	22%	14	7%	61	15%	
Mid-Atlantic	107	50%	51	27%	158	39%	
Midwest	25	12%	33	17%	58	14%	
Southwest	33	16%	92	49%	125	32%	
Total	212	100%	190	100%	402	100%	

The geographical locations noted above include the following states:

•	New England - Connecticut, Maine, Massachusetts, New Hampshire and Rhode Island; 
•	Mid-Atlantic - Delaware, Maryland (including the District of Columbia), New Jersey, New York, Pennsylvania and Virginia;
•	Midwest - Illinois, Indiana, Michigan and Ohio; and
•	Southwest - Arizona, California, Colorado, Florida, Nevada and Texas.

Across our market areas, we have operated under a number of different retail brands. We currently operate under six retail brands.

Drivers of Our Business

The success of our business and our profitability are impacted by a number of drivers, the most significant of which are discussed below.

Customer Growth

Customer growth is a key driver of our operations. Our ability to acquire customers organically or by acquisition is important to our success as we experience ongoing customer attrition. Our customer growth strategy includes growing organically through traditional sales channels complemented by customer portfolio and business acquisitions.

During the three months ended June 30, 2025, we added approximately 27,700 RCEs primarily through our various organic sales channels. Although we expect to continue to acquire customers organically in the future, our sales rate is dependent on market conditions and may slow in future periods.

In April and May 2025, we entered into two asset purchase agreements to acquire up to 16,800 RCEs for a cash purchase price of up to a maximum $1.8 million paid in cash or funded into escrow accounts. These gas customers are located in our existing markets and began transferring in May 2025 and June 2025. As of June 30, 2025, approximately 9,300 RCEs were transferred as a result of the asset purchase agreement.

While we remain focused on organic sales and identifying customer portfolio and business acquisitions, we cannot ensure that our RCE count will remain at current levels or grow. Our RCE count, as well as the margins we earn on our customers, contribute to our overall profitability, cash flow and ability to pay dividends.

Customer Acquisition Costs 

Managing customer acquisition costs is a key component of our profitability. Customer acquisition costs are those costs related to obtaining customers organically and do not include the cost of acquiring customers through acquisitions, which are recorded as customer relationships.

Customer Attrition

Customer attrition occurs primarily as a result of: (i) customer initiated switches; (ii) residential moves; (iii) disconnection resulting from customer payment defaults; and (iv) proactive non-renewal of contracts. Average monthly customer attrition for the three months ended June 30, 2025 and 2024 was 3.5% and 3.4%, respectively.

Customer Credit Risk

Our credit loss expense for the three months ended June 30, 2025 and 2024 was 0.4% and 2.1%, respectively, for non-purchase of receivable market ("non-POR") revenues. Our credit loss expense for the six months ended June 30, 2025 and 2024 was 0.8% and 1.4%, respectively, for non-purchase of receivable market ("non-POR") revenues. As the Company has decreased sales activities in non-POR markets and focused on collection efforts, we have experienced a decrease in credit loss expense during the three months ended June 30, 2025.

Gross Profit

The profit earned between the price we are able to charge customers for retail electricity and natural gas and the cost to serve customers is a key component of the results of our operations. Prices we are able to charge customers for retail electricity and natural gas vary with market conditions, and are subject to regulatory restrictions in many of the markets we serve. Costs to serve customers are tied closely to gas and power commodity markets, which exposes us to significant variability and uncertainties.

Weather Conditions 

Weather conditions directly influence the demand for natural gas and electricity and affect the prices of energy commodities. Our hedging strategy is based on forecasted customer energy usage, which can vary substantially as a result of weather patterns deviating from historical norms. We are particularly sensitive to this variability in our residential customer segment where energy usage is highly sensitive to weather conditions that impact heating and cooling demand.

Our risk management policies direct that we hedge substantially all of our forecasted demand, which is typically hedged to long-term normal weather patterns. We also attempt to add additional protection through hedging from time to time to protect us from potential volatility in markets where we have historically experienced higher exposure to extreme weather conditions. Because we attempt to match commodity purchases to anticipated demand, unanticipated changes in weather patterns can have a significant impact on our operating results and cash flows from period to period.

Asset Optimization

Our asset optimization opportunities primarily arise during the winter heating season when demand for natural gas is typically at its highest. Given the opportunistic nature of these activities and because we account for these activities using the mark to market method of accounting, we experience variability in our earnings from our asset optimization activities from year to year.

Net asset optimization resulted in a loss of $0.6 million and a loss of $0.5 million for the three months ended June 30, 2025 and 2024 , respectively. Net asset optimization resulted in a loss of $2.9 million and a loss of $2.1 million for the six months ended June 30, 2025 and 2024, respectively.

Non-GAAP Performance Measures

We use the Non-GAAP performance measures of Adjusted EBITDA and Retail Gross Margin to evaluate and measure our operating results as follows:
 	Three Months Ended June 30,		Six Months Ended June 30,	
(in thousands)	2025		2024		2025		2024	
Adjusted EBITDA (1)	$	13,960			$	12,363			$	41,674			$	27,431		
Retail Gross Margin 	$	32,722			$	33,387			$	79,181			$	69,132		
(1) Adjusted EBITDA for  three and six months ended June 30, 2025 includes an add back of less than $0.1 million and of $(0.2) million, respectively, related to merger agreement expense.

Adjusted EBITDA. We define “Adjusted EBITDA” as EBITDA less (i) customer acquisition costs incurred in the current period, plus or minus (ii) net (loss) gain on derivative instruments, and (iii) net current period cash settlements on derivative instruments, plus (iv) non-cash compensation expense, and (v) other non-cash and non-recurring operating items. EBITDA is defined as net income (loss) before the provision for income taxes, interest expense and depreciation and amortization. This conforms to the calculation of Adjusted EBITDA in our Senior Credit Facility.

We deduct all current period customer acquisition costs (representing spending for organic customer acquisitions) in the Adjusted EBITDA calculation because such costs reflect a cash outlay in the period in which they are incurred, even though we capitalize and amortize such costs over two years. We do not deduct the cost of customer acquisitions through acquisitions of businesses or portfolios of customers in calculating Adjusted EBITDA.

We deduct our net gains (losses) on derivative instruments, excluding current period cash settlements, from the Adjusted EBITDA calculation in order to remove the non-cash impact of net gains and losses on these instruments. We also deduct non-cash compensation expense that results from the issuance of restricted stock units under our long-term incentive plan due to the non-cash nature of the expense.

We adjust from time to time other non-cash or unusual and/or infrequent charges due to either their non-cash nature or their infrequency. We have historically included the financial impact of weather variability in the calculation of Adjusted EBITDA.

We believe that the presentation of Adjusted EBITDA provides information useful to investors in assessing our liquidity and financial condition and results of operations and that Adjusted EBITDA is also useful to investors as a financial indicator of our ability to incur and service debt, pay dividends and fund capital expenditures. Adjusted EBITDA is a supplemental financial measure that management and external users of our consolidated financial statements, such as industry analysts, investors, commercial banks and rating agencies, use to assess the following:

•	our operating performance as compared to other publicly traded companies in the retail energy industry, without regard to financing methods, capital structure or historical cost basis; 
•	the ability of our assets to generate earnings sufficient to support our proposed cash dividends; 
•	our ability to fund capital expenditures (including customer acquisition costs) and incur and service debt; and
•	our compliance with financial debt covenants. (Refer to Note 9 “Debt” to Part I, Item 1 of this Report for discussion of the material terms of our Senior Credit Facility, including the covenant requirements for our Minimum Fixed Charge Coverage Ratio and Maximum Total Leverage Ratio) 

The GAAP measures most directly comparable to Adjusted EBITDA are net income (loss) and net cash provided by (used in) operating activities. The following table presents a reconciliation of Adjusted EBITDA to these GAAP measures for each of the periods indicated.
  	Three Months Ended June 30,		Six Months Ended June 30,	
(in thousands)	2025		2024		2025		2024	
Reconciliation of Adjusted EBITDA to net income:								
Net income	$	3,151			$	15,695			$	21,618			$	34,759		
Depreciation and amortization		5,291				2,210				10,319				4,250		
Interest expense		1,539				1,743				3,357				3,672		
Income tax expense		1,381				3,208				5,977				7,960		
EBITDA 		11,362				22,856				41,271				50,641		
Less:								
Loss (gain) on derivative instruments		(6,412)			3,180				(2,026)			(1,025)	
Cash settlements on derivative instruments		1,288				7,767				(2,612)			23,192		
Customer acquisition costs		2,578				2,582				4,078				5,026		
       Plus:								
       Non-cash compensation expense		—				1,928				—				2,442		
Merger agreement expense		52				1,108				(157)			1,541		
Adjusted EBITDA	$	13,960			$	12,363			$	41,674			$	27,431		
 
The following table presents a reconciliation of Adjusted EBITDA to net cash provided by operating activities for each of the periods indicated.

  	Three Months Ended June 30,		Six Months Ended June 30,	
(in thousands)	2025		2024		2025		2024	
Reconciliation of Adjusted EBITDA to net cash provided by operating activities:								
Net cash provided by operating activities	$	18,998			$	11,228			$	43,948			$	28,327		
Amortization of deferred financing costs		(167)			(312)			(334)			(518)	
Bad debt expense		(145)			(1,017)			(833)			(1,321)	
Interest expense		1,539				1,743				3,357				3,672		
Income tax expense		1,381				3,208				5,977				7,960		
Merger agreement expense		52				1,108				(157)			1,541		
Changes in operating working capital								
Accounts receivable, prepaids and current assets		(23,739)			(12,564)			(17,311)			(19,837)	
Inventory		1,054				653				(333)			(1,108)	
Accounts payable and accrued liabilities		15,117				8,444				17,469				10,660		
Other		(130)			(128)			(10,109)			(1,945)	
Adjusted EBITDA	$	13,960			$	12,363			$	41,674			$	27,431		
Cash Flow Data:								
Net cash provided by operating activities	$	18,998			$	11,228			$	43,948			$	28,327		
Net cash used in investing activities	$	(947)		$	(280)		$	(14,952)		$	(730)	
Net cash used in financing activities	$	(18,816)		$	(5,482)		$	(32,388)		$	(14,303)	

Retail Gross Margin. We define retail gross margin as gross profit less (i) net asset optimization revenues (expenses), (ii) net gains (losses) on non-trading derivative instruments, (iii) net current period cash settlements on non-trading derivative instruments and (iv) gains (losses) from non-recurring events (including non-recurring market volatility). Retail gross margin is included as a supplemental disclosure because it is a primary performance measure used by our management to determine the performance of our retail natural gas and electricity segments as a result of recurring operations. As an indicator of our retail energy business’s operating performance, retail gross margin should not be considered an alternative to, or more meaningful than, gross profit, its most directly comparable financial measure calculated and presented in accordance with GAAP.

We believe retail gross margin provides information useful to investors as an indicator of our retail energy business’s operating performance.

The GAAP measure most directly comparable to Retail Gross Margin is gross profit. The following table presents a reconciliation of Retail Gross Margin to gross profit for each of the periods indicated.
  	Three Months Ended June 30,		Six Months Ended June 30,	
(in thousands)	2025		2024		2025		2024	
Reconciliation of Retail Gross Margin to Gross Profit								
Total Revenue	$	90,029			$	86,696			$	232,286			$	200,752		
Less:								
Retail cost of revenues		63,055				42,997				158,448				111,959		
Gross Profit	$	26,974			$	43,699			$	73,838			$	88,793		
Less:								
Net asset optimization expense		(636)			(531)			(2,885)			(2,128)	
(Loss) gain on non-trading derivative instruments		(6,400)			3,160				154				(1,136)	
Cash settlements on non-trading derivative instruments		1,288				7,683				(2,612)			22,925		
Retail Gross Margin	$	32,722			$	33,387			$	79,181			$	69,132		
Retail Gross Margin - Retail Electricity Segment 	$	23,531			$	25,311			$	44,945			$	44,222		
Retail Gross Margin - Retail Natural Gas Segment	$	9,170			$	8,016			$	34,214			$	24,213		
Retail Gross Margin - Other	$	21			$	60			$	22			$	697		

Our non-GAAP financial measures of Adjusted EBITDA and Retail Gross Margin should not be considered as alternatives to gross profit. Adjusted EBITDA and Retail Gross Margin are not presentations made in accordance with GAAP and have limitations as analytical tools. You should not consider Adjusted EBITDA or Retail Gross Margin in isolation or as a substitute for analysis of our results as reported under GAAP. Because Adjusted EBITDA and Retail Gross Margin exclude some, but not all, items that affect gross profit, and are defined differently by different companies in our industry, our definition of Adjusted EBITDA and Retail Gross Margin may not be comparable to similarly titled measures of other companies.

Management compensates for the limitations of Adjusted EBITDA and Retail Gross Margin as analytical tools by reviewing the comparable GAAP measures, understanding the differences between the measures and incorporating these data points into management’s decision-making process.

Consolidated Results of Operations

Three Months Ended June 30, 2025 Compared to Three Months Ended June 30, 2024 
(In Thousands)	Three Months Ended June 30,		Six Months Ended June 30,	
	2025		2024		2025		2024	
Revenues:								
Retail revenues	$	90,635			$	86,960			$	235,138			$	201,348		
Net asset optimization expense		(636)				(531)				(2,885)				(2,128)		
Other revenue		30				267				33				1,532		
Total Revenues		90,029				86,696				232,286				200,752		
Operating Expenses:								
Retail cost of revenues		63,055				42,997				158,448				111,959		
General and administrative expense		15,631				20,862				32,623				38,195		
Depreciation and amortization		5,291				2,210				10,319				4,250		
Total Operating Expenses		83,977				66,069				201,390				154,404		
Operating income		6,052				20,627				30,896				46,348		
Other (expense)/income:								
Interest expense		(1,539)				(1,743)				(3,357)				(3,672)		
Interest and other income		19				19				56				43		
Total other expense		(1,520)				(1,724)				(3,301)				(3,629)		
Income before income tax expense 		4,532				18,903				27,595				42,719		
Income tax expense		1,381				3,208				5,977				7,960		
Net income	$	3,151			$	15,695			$	21,618			$	34,759		
Other Performance Metrics:								
  Adjusted EBITDA (1) (2)	$	13,960			$	12,363			$	41,674			$	27,431		
  Retail Gross Margin (1)	$	32,722			$	33,387			$	79,181			$	69,132		
  Customer Acquisition Costs	$	2,578			$	2,582			$	4,078			$	5,026		
  Average Monthly RCE Attrition		3.5	%			3.4	%			3.9	%			3.6	%	
(1) Adjusted EBITDA and Retail Gross Margin are non-GAAP financial measures. See “ — Non-GAAP Performance Measures” for a reconciliation of Adjusted EBITDA and Retail Gross Margin to their most directly comparable GAAP financial measures.
(2) Adjusted EBITDA for the three and six months ended June 30, 2025 includes an add back of less than  $0.1 million and $(0.2) million, respectively, related to merger agreement expense.

Total Revenues. Total revenues for the three months ended June 30, 2025 were approximately $90.0 million, an increase of approximately $3.3 million, or 4%, from approximately $86.7 million from the three months ended June 30, 2024, as indicated in the table below (in millions). This increase was primarily due to higher gas volumes sold due to larger gas customer book as a result of customer book purchases and higher electricity and gas rates in the second quarter of 2025 as compared to the second quarter of 2024. This was offset by lower electricity volumes sold in the second quarter of 2025 as compared to 2024. 
Change in electricity volumes sold	$	(6.0)	
Change in natural gas volumes sold		6.9		
Change in electricity unit revenue per MWh		1.7		
Change in natural gas unit revenue per MMBtu		1.1		
Change in other revenue		(0.3)	
Change in net asset optimization expense		(0.1)	
Change in total revenues	$	3.3		

Retail Cost of Revenues. Total retail cost of revenues for the three months ended June 30, 2025 was approximately $63.1 million, an increase of approximately $20.1 million, or 47%, from approximately $43.0 million for the three months ended June 30, 2024, as indicated in the table below (in millions). This increase was primarily due to change in value of  retail derivative portfolio, higher gas volumes sold due to larger gas customer book and higher natural gas and electricity costs in the second quarter of 2025 as compared to the second quarter of 2024. This was partially offset by lower electricity volumes sold in the second quarter of 2025 compared to the second quarter of 2024.

Change in electricity volumes sold	$	(3.8)	
Change in natural gas volumes sold		3.4		
Change in electricity unit cost per MWh		1.3		
Change in natural gas unit cost per MMBtu		3.4		
Change in other costs 		(0.1)	
Change in value of retail derivative portfolio		15.9		
Change in retail cost of revenues	$	20.1		

General and Administrative Expense. General and administrative expense for the three months ended June 30, 2025 was approximately $15.6 million, a decrease of approximately $5.3 million, or 25%, as compared to $20.9 million for the three months ended June 30, 2024. This decrease was primarily attributable to a decrease in bad debt expense and legal expenses in the second quarter of 2025 as compared to the second quarter of 2024, and stock compensation expenses related to the Merger in the second quarter of 2024 that did not reoccur in 2025. 

Depreciation and Amortization Expense. Depreciation and amortization expense for the three months ended June 30, 2025 was approximately $5.3 million, an increase of approximately $3.1 million, or 141%, from approximately $2.2 million for the three months ended June 30, 2024. This increase was primarily due to higher amortization expense associated with customer relationship intangibles as result of customer book purchases.

Customer Acquisition Cost. Customer acquisition cost for the three months ended June 30, 2025 was approximately $2.6 million, an increase of approximately less than $0.1 million, or 2% from approximately $2.6 million three months ended June 30, 2024, primarily due to a slight increase in the sales activity in the second quarter of 2025 as compared to the second quarter of 2024.

Six months ended June 30, 2025 Compared to Six months ended June 30, 2024

Total Revenues. Total revenues for the six months ended June 30, 2025 were approximately $232.3 million, an increase of approximately $31.5 million, or 16%, from approximately $200.8 million for the six months ended June 30, 2024, as indicated in the table below (in millions). This increase was primarily due to higher gas and electricity volumes sold due to a larger customer book as a result of book purchases, partially offset by lower electricity rates during the first half of 2025 as compared to the first half of 2024.
Change in electricity volumes sold	$	1.7		
Change in natural gas volumes sold		34.3		
Change in electricity unit revenue per MWh		(2.7)	
Change in natural gas unit revenue per MMBtu		0.5		
Change in other revenue		(1.5)	
Change in net asset optimization expense		(0.8)	
Change in total revenues	$	31.5		

Retail Cost of Revenues. Total retail cost of revenues for the six months ended June 30, 2025 was approximately $158.4 million, an increase of approximately $46.4 million, or 41%, from approximately $112.0 million for the six months ended June 30, 2024, as indicated in the table below (in millions). This increase was primarily due to change in value of derivative portfolio, higher gas and electricity volumes sold due to larger customer book and higher natural gas costs gas costs during the first half of 2025 as compared to the first half of 2024.

Change in electricity volumes sold	$	1.2		
Change in natural gas volumes sold		18.6		
Change in electricity unit cost per MWh		(2.9)	
Change in natural gas unit cost per MMBtu		6.2		
Change in other costs		(0.9)	
Change in value of retail derivative portfolio		24.2		
Change in retail cost of revenues	$	46.4		

General and Administrative Expense. General and administrative expense for the six months ended June 30, 2025 was approximately $32.6 million, a decrease of approximately $5.6 million, or 15%, as compared to $38.2 million for the six months ended June 30, 2024. This decrease was primarily attributable to a decrease in bad debt expense and legal expenses during the first half of the 2025 as compared to first half of 2024, and stock compensation expense related to the Merger in 2024 that did not reoccur in 2025.

Depreciation and Amortization Expense. Depreciation and amortization expense for the six months ended June 30, 2025 was approximately $10.3 million, an increase of approximately $6.0 million, or 140%, from approximately $4.3 million for the six months ended June 30, 2024. This increase was primarily due to higher amortization expense associated with customer relationship intangibles as result of customer book purchases.

Customer Acquisition Cost. Customer acquisition cost for the six months ended June 30, 2025 was approximately $4.1 million, a decrease of approximately $0.9 million, or 18%, from approximately $5.0 million for the six months ended June 30, 2024. This decrease was primarily due to decrease in the sales activity in the first half of 2025 as compared to the first half of 2024.

Operating Segment Results
(in thousands, except volume and per unit operating data)	Three Months Ended June 30,		Six Months Ended June 30,	
  	2025		2024		2025		2024	
								
Retail Electricity Segment								
Total Revenues	$	66,810			$	71,148			$	147,530			$	148,477		
Retail Cost of Revenues		46,607				37,127				104,809				86,258		
Less: Loss on non-trading derivatives, net of cash settlements		(3,328)			8,710				(2,224)			17,997		
Retail Gross Margin (1)  — Electricity	$	23,531			$	25,311			$	44,945			$	44,222		
Volumes — Electricity (MWhs)		447,662				489,369				1,005,279				993,676		
Retail Gross Margin (2) — Electricity per MWh	$	52.56			$	51.72			$	44.71			$	44.50		
								
Retail Natural Gas Segment								
Total Revenues	$	23,825			$	15,812			$	87,608			$	52,871		
Retail Cost of Revenues		16,439				5,663				53,628				24,866		
Less: Loss on non-trading derivatives, net of cash settlements		(1,784)			2,133				(234)			3,792		
Retail Gross Margin (1) — Gas	$	9,170			$	8,016			$	34,214			$	24,213		
Volumes — Gas (MMBtus)		2,975,132				2,074,924				10,429,207				6,327,869		
Retail Gross Margin (2) — Gas per MMBtu	$	3.08			$	3.86			$	3.28			$	3.83		
(1) Reflects the Retail Gross Margin attributable to our Retail Electricity Segment or Retail Natural Gas Segment, as applicable. Retail Gross Margin is a non-GAAP financial measure. See “Non-GAAP Performance Measures” for a reconciliation of Retail Gross Margin to most directly comparable financial measures presented in accordance with GAAP.
(2) Reflects the Retail Gross Margin for the Retail Electricity Segment or Retail Natural Gas Segment, as applicable, divided by the total volumes in MWh or MMBtu, respectively.

Three Months Ended June 30, 2025 Compared to Three Months Ended June 30, 2024
Retail Electricity Segment  

Total revenues for the Retail Electricity Segment for the three months ended June 30, 2025 were approximately $66.8 million, a decrease of approximately $4.3 million, or 6%, from approximately $71.1 million for the three months ended June 30, 2024. This decrease was largely due to lower electricity volumes of $6.0 million as a result of a smaller electricity customer book as compared to the second quarter of 2024 offset by higher electricity rates, which resulted in a increase of $1.7 million.

Retail cost of revenues for the Retail Electricity Segment for the three months ended June 30, 2025 were approximately $46.6 million, an increase of approximately $9.5 million, or 26%, from approximately $37.1 million for the three months ended June 30, 2024. This increase was primarily due to change in the fair value of our retail derivative portfolio used for hedging, which resulted in an increase of $12.0 million and higher electricity costs, resulting in a increase of $1.3 million offset by lower electricity volumes due to a smaller electricity customer book, resulting in decrease of $3.8 million.

Retail gross margin for the Retail Electricity Segment for the three months ended June 30, 2025 was approximately $23.5 million, a decrease of approximately $1.8 million, or 7%, from approximately $25.3 million for the three months ended June 30, 2024, as indicated in the table below (in millions).
Change in volumes sold	$	(2.2)	
Change in unit margin per MWh		0.4		
Change in retail electricity segment retail gross margin	$	(1.8)	
Retail Natural Gas Segment 

Total revenues for the Retail Natural Gas Segment for the three months ended June 30, 2025 were approximately $23.8 million, an increase of approximately $8.0 million, or 51%, from approximately $15.8 million for the three months ended June 30, 2024. This increase was attributable to higher gas volumes due to a larger gas customer book, resulting in an increase of $6.9 million and higher natural gas rates, which increased total revenues by $1.1 million.

Retail cost of revenues for the Retail Natural Gas Segment for the three months ended June 30, 2025 were approximately $16.4 million, an increase of $10.7 million, or 188%, from approximately $5.7 million for the three months ended June 30, 2024. This increase was primarily due to higher natural gas volumes due to a larger gas customer book, resulting in an increase of $3.4 million, and higher natural gas cost, resulting in an increase of $3.4 million and a change in the fair value of our retail derivative portfolio used for hedging, which resulted in an increase of $3.9 million.

Retail gross margin for the Retail Natural Gas Segment for the three months ended June 30, 2025 was approximately $9.2 million, an increase of approximately $1.2 million, or 14%, from approximately $8.0 million for the three months ended June 30, 2024, as indicated in the table below (in millions).
Change in volumes sold	$	3.5		
Change in unit margin per MMBtu		(2.3)	
Change in retail natural gas segment retail gross margin	$	1.2		

Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Retail Electricity Segment

Total revenues for the Retail Electricity Segment for the six months ended June 30, 2025 were approximately $147.5 million, a decrease of approximately $1.0 million, or 1%, from approximately $148.5 million for the six months ended June 30, 2024. This decrease was largely due to lower electricity prices, resulting in a decrease of $2.7 million, offset by higher volumes, resulting in an increase of $1.7 million.

Retail cost of revenues for the Retail Electricity Segment for the six months ended June 30, 2025 was approximately $104.8 million, an increase of approximately $18.5 million, or 21%, from approximately $86.3 million for the six months ended June 30, 2024. This increase was primarily due to a change in the value of our derivative portfolio used for hedging resulting in an increase of $20.2 million, an increase in electricity volumes sold resulting in an increase of $1.2 million, partially offset by lower electricity costs of $2.9 million.

Retail gross margin for the Retail Electricity Segment for the six months ended June 30, 2025 was approximately $44.9 million, an increase of approximately $0.7 million, or 2%, from approximately $44.2 million for the six months ended June 30, 2024, as indicated in the table below (in millions).
Change in volumes sold	$	0.5		
Change in unit margin per MWh		0.2		
Change in retail electricity segment retail gross margin	$	0.7		
Retail Natural Gas Segment

Total revenues for the Retail Natural Gas Segment for the six months ended June 30, 2025 were approximately $87.6 million, an increase of approximately $34.8 million, or 66%, from approximately $52.8 million for the six months ended June 30, 2024. This increase was attributable to higher gas volumes due to a larger gas customer book, resulting in an increase of $34.3 million and higher rates, which resulted in an increase in total revenues of $0.5 million. 

Retail cost of revenues for the Retail Natural Gas Segment for the six months ended June 30, 2025 was approximately $53.6 million, an increase of approximately $28.8 million, or 116%, from approximately $24.8 million for the six months ended June 30, 2024. The increase was primarily attributable to an increase in volumes sold resulting in an increase of $18.6 million, an increase in natural gas cost of $6.2 million, and a change in the value of our derivative portfolio used for hedging, which resulted in an increase of $4.0 million.

Retail gross margin for the Retail Natural Gas Segment for the six months ended June 30, 2025 was approximately $34.2 million, an increase of approximately $10.0 million, or 41%, from approximately $24.2 million for the six months ended June 30, 2024, as indicated in the table below (in millions).
Change in volumes sold	$	15.7		
Change in unit margin per MMBtu		(5.7)	
Change in retail natural gas segment retail gross margin	$	10.0		

Liquidity and Capital Resources

Overview 

Our primary sources of liquidity are cash generated from operations and borrowings under our Senior Credit Facility. Our principal liquidity requirements are to meet our financial commitments, finance current operations, fund organic growth and/or acquisitions and service debt and pay dividends. Our liquidity requirements fluctuate with our level of customer acquisition costs, acquisitions, collateral posting requirements on our derivative instruments portfolio, distributions, the effects of the timing between the settlement of payables and receivables, including the effect of bad debts, weather conditions, and our general working capital needs for ongoing operations. Estimating our liquidity requirements is highly dependent on then-current market conditions, forward prices for natural gas and electricity, market volatility and our then existing capital structure and requirements.

We believe that cash generated from operations and our available liquidity sources will be sufficient to sustain current operations and to pay required taxes. Our ability to pay dividends to the holders of the Series A Preferred Stock in the future will ultimately depend on our RCE count, margins, profitability and cash flow, and the covenants under our Senior Credit Facility.

Liquidity Position

The following table details our available liquidity as of June 30, 2025:
($ in thousands)	June 30, 2025	
Cash and cash equivalents	$	62,142		
Senior Credit Facility Availability (1)		61,276		
Subordinated Debt Facility Availability (2) 		25,000		
Total Liquidity	$	148,418		
(1) Reflects amount of Letters of Credit that could be issued based on existing covenants as of June 30, 2025.
(2) The availability of the Subordinated Facility is dependent on Mr. Maxwell’s willingness and ability to lend. See “—Sources of Liquidity —Subordinated Debt Facility.”

Borrowings and related posting of letters of credit under our Senior Credit Facility are subject to material variations on a seasonal basis due to the timing of commodity purchases to satisfy natural gas inventory requirements and to meet customer demands during periods of peak usage. Additionally, borrowings are subject to borrowing base and covenant restrictions.

Cash Flows

Our cash flows were as follows for the respective periods (in thousands):
  	Six Months Ended June 30,	
  	2025		2024	
Net cash provided by operating activities	$	43,948			$	28,327		
Net cash used in investing activities	$	(14,952)		$	(730)	
Net cash used in financing activities	$	(32,388)		$	(14,303)	

Six Months Ended June 30, 2025 Compared to the Six Months Ended June 30, 2024

Cash Flows Provided by Operating Activities. Cash flows provided by operating activities for the six months ended June 30, 2025 increased by $15.6 million compared to the six months ended June 30, 2024. The increase was primarily the result of changes in working capital for the six months ended June 30, 2025.

Cash Flows Used in Investing Activities. Cash flows used in investing activities increased by $14.2 million for the six months ended June 30, 2025. The increase was primarily the result of payments for the customers that came on flow during the six months ended June 30, 2025 related to customer book acquisitions in 2024, and payments related to customers book acquisitions during the six months ended June 30, 2025.

Cash Flows Used in Financing Activities. Cash flows used in financing activities increased by $18.1 million for the six months ended June 30, 2025, primarily due to an increase in distribution to our non-controlling interest of  $9.2 million, an increase in net paydown of our Senior Credit Facility of $2.0 million, an increase of $4.7 million due to Series A Preferred Stock buyback, increase in distribution to controlling interest of $3.2 million, partially offset by decrease of $0.7 million dividends to Series A Preferred Stock holder during the six months ended June 30, 2025 compared to the six months ended June 30, 2024. 

Sources of Liquidity and Capital Resources

The Co-Borrowers maintain the Senior Credit Facility with the Agent. The Senior Credit Facility matures on June 30, 2027 and has a borrowing capacity of $250.0 million.

As of June 30, 2025, we had total commitments of $250.0 million under our Senior Credit Facility, of which $131.2 million was outstanding, including $31.2 million of outstanding letters of credit.

For a description of the terms and conditions of our Senior Credit Facility, including descriptions of the interest rate, commitment fee, covenants and terms of default, please see Note 9 “Debt” in the notes to our condensed consolidated financial statements.

As of June 30, 2025, we were in compliance with the covenants under our Senior Credit Facility. Based upon existing covenants as of June 30, 2025, we had availability to borrow up to $61.3 million under the Senior Credit Facility. 

Maintaining compliance with our covenants under our Senior Credit Facility may impact our ability to pay dividends on our Series A Preferred Stock.

Amended and Restated Subordinated Debt Facility

In connection with entering into the Senior Credit Facility, we entered into an amended and restated subordinated promissory note (the “Subordinated Debt Facility”), which allows us to draw advances in increments of no less than $1.0 million per advance up to $25.0 million through January 31, 2028. 

See Note 9 “Debt” for further information regarding the Subordinated Debt Facility.

Uses of Liquidity and Capital Resources

Repayment of Current Portion of Senior Credit Facility

Our Senior Credit Facility matures in June 2027, and no amounts are due currently. However, due to the revolving nature of the facility, excess cash available is generally used to reduce the balance outstanding, which at June 30, 2025 was $131.2 million, including $31.2 million of outstanding letters of credit. The current variable interest rate on the facility at June 30, 2025 was 7.58%.

Customer Acquisitions

Our customer acquisition strategy consists of customer growth obtained through organic customer additions as well as opportunistic acquisitions. During the three months ended June 30, 2025 and 2024, we spent a total of $2.6 million and $2.6 million, respectively, on organic customer acquisitions.

Capital Expenditures

Our capital requirements each year are relatively low and generally consist of minor purchases of equipment or information system upgrades and improvements. Capital expenditures for the six months ended June 30, 2025 and 2024 included $2.0 million and $0.7 million, respectively, related to information systems improvements.

Dividends and Distributions

For the three and six months ended June 30, 2025 we paid $2.3 million and $4.8 million in dividends to holders of the Series A Preferred Stock. As of June 30, 2025, we had accrued $2.2 million related to dividends to holders of the Series A Preferred Stock. This dividend was paid on July 15, 2025. For a more detailed explanation of the Company's Series A Preferred Stock, please see Note 5 "Preferred Stock" in the notes to our condensed consolidated financial statements.

For the full year ended December 31, 2025, taking into consideration the amount of dividends already paid and estimating future dividends using the stated most recent dividend rate paid on the Series A Preferred Stock, we would be required to pay dividends of $9.0 million in the aggregate based on the Series A Preferred Stock outstanding as of June 30, 2025.

On July 16, 2025, we declared a dividend in the amount of $0.69732 per share for the Series A Preferred Stock for the second quarter of 2025. Dividends on Series A Preferred Stock will be paid on October 15, 2025 to holders of record on October 1, 2025.

Future dividends are within the discretion of our Board of Directors, which may be required to reduce, eliminate or suspend quarterly cash dividends to the holders of the Series A Preferred Stock. Any future dividends will depend upon our operations, our financial condition, capital requirements and investment opportunities, the performance of our business, cash flows, RCE counts and the margins we receive, as well as restrictions under our Senior Credit Facility. A dividend penalty event would occur if dividends on the Series A Preferred Stock are in arrears for six or more quarterly dividend periods, in which case the dividend rate on the Series A Preferred Stock would increase by 2.00% per annum, and the holders of the Series A Preferred Stock would be entitled to elect two members to our Board of Directors, until the dividend penalty event is cured.

Off-Balance Sheet Arrangements

As of June 30, 2025, we had no material “off-balance sheet arrangements.”

Related Party Transactions

For a discussion of related party transactions, see Note 13 “Transactions with Affiliates” to Part I, Item 1 of this Report.

Critical Accounting Policies and Estimates

Our critical accounting policies and estimates are described in “Management's Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates” in our 2024 Form 10-K. There have been no changes to these policies and estimates since the date of our 2024 Form 10-K.

Refer to Note 2 “Basis of Presentation and Summary of Significant Accounting Policies” to Part I, Item 1 of this Report for a discussion on recent accounting pronouncements.

Contingencies

In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including regulatory and other matters. Liabilities for loss contingencies arising from claims, assessments, litigation, fines, penalties and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. For a discussion of the status of current legal and regulatory matters, see Note 12 “Commitments and Contingencies” to Part I, Item 1 of this Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market risks relating to our operations result primarily from changes in commodity prices and interest rates, as well as counterparty credit risk. We employ established risk management policies and procedures to manage, measure, and limit our exposure to these risks.

Commodity Price Risk

We hedge and procure our energy requirements from various wholesale energy markets, including both physical and financial markets and through short and long-term contracts. Our financial results are largely dependent on the margin we are able to realize between the wholesale purchase price of natural gas and electricity plus related costs and the retail sales price we charge our customers for these commodities. We actively manage our commodity price risk by entering into various derivative or non-derivative instruments to hedge the variability in future cash flows from fixed-price forecasted sales and purchases of natural gas and electricity in connection with our retail energy operations. These instruments include forwards, futures, swaps, and option contracts traded on various exchanges, such as NYMEX and Intercontinental Exchange, or ICE, as well as over-the-counter markets. These contracts have varying terms and durations, which range from a few days to several years, depending on the instrument. We also utilize similar derivative contracts in connection with our asset optimization activities to attempt to generate incremental gross margin by effecting transactions in markets where we have a retail presence. Generally, any such instruments that are entered into to support our retail electricity and natural gas business are categorized as having been entered into for non-trading purposes, and instruments entered into for any other purpose are categorized as having been entered into for trading purposes.

Our net (loss)/gain on our non-trading derivative instruments, net of cash settlements, was $(5.1) million and $10.8 million for the three months ended June 30, 2025 and 2024, and $(2.5) million and $21.8 million for the six months ended June 30, 2025 and 2024, respectively. 

We have adopted risk management policies to measure and limit market risk associated with our fixed-price portfolio and our hedging activities. For additional information regarding our commodity price risk and our risk management policies, see “Item 1A—Risk Factors” in our 2024 Form 10-K.

We measure the commodity risk of our non-trading energy derivatives using a sensitivity analysis on our net open position. As of June 30, 2025, our Gas Non-Trading Fixed Price Open Position (hedges net of retail load) was a short position of 589,814 MMBtu. An increase of 10% in the market prices (NYMEX) from their June 30, 2025, levels would have decreased the fair market value of our net non-trading energy portfolio by $0.1 million. Likewise, a decrease of 10% in the market prices (NYMEX) from their June 30, 2025, levels would have increased the fair market value of our non-trading energy derivatives by $0.1 million. As of June 30, 2025, our Electricity Non-Trading Fixed Price Open Position (hedges net of retail load) was a short position of 50,196 MWhs. An increase of 10% in the forward market prices from their June 30, 2025, levels would have increased the fair market value of our net non-trading energy portfolio by less than $0.1 million. Likewise, a decrease of 10% in the forward market prices from their June 30, 2025, levels would have decreased the fair market value of our non-trading energy derivatives by less than $0.1 million.

Credit Risk 

In many of the utility services territories where we conduct business, Purchase of Receivables (“POR”) programs have been established, whereby the local regulated utility purchases our receivables, and becomes responsible for billing the customer and collecting payment from the customer. This service results in substantially all of our credit risk being with the utility and not to our end-use customer in these territories. Approximately 56% and 59% of our retail revenues were derived from territories in which substantially all of our credit risk was with local regulated utility companies for the three months ended June 30, 2025 and 2024, respectively, and 58% and 60% for the six months ended June 30, 2025 and 2024, respectively, all of which had investment grade ratings as of such date. We paid these local regulated utilities a weighted average discount of 1.3% and 1.2% for the three months ended June 30, 2025 and 2024, respectively, and 1.3% and 1.2% for the six months ended June 30, 2025 and 2024, respectively, of total revenues for customer credit risk protection. In certain of the POR markets in which we operate, the utilities limit their collections exposure by retaining the ability to transfer a delinquent account back to us for collection when collections are past due for a specified period.

If our collection efforts are unsuccessful, we return the account to the local regulated utility for termination of service. Under these service programs, we are exposed to credit risk related to payment for services rendered during the time between when the customer is transferred to us by the local regulated utility and the time we return the customer to the utility for termination of service, which is generally one to two billing periods. We may also realize a loss on fixed-price customers in this scenario due to the fact that we will have already fully hedged the customer’s expected commodity usage for the life of the contract.

In non-POR markets (and in POR markets where we may choose to direct bill our customers), we manage customer credit risk through formal credit review in the case of commercial customers, and credit score screening, deposits and disconnection for non-payment, in the case of residential customers. Economic conditions may affect our customers’ ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in bad debt expense. Our bad debt expense for the three months ended June 30, 2025 and 2024 was 0.4% and 2.1% of non-POR market retail revenues, respectively, and our bad debt expense for the six months ended June 30, 2025 and 2024 was 0.8% and 1.4% of non-POR market retail revenues, respectively. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Drivers of Our Business—Customer Credit Risk” for an analysis of our bad debt expense related to non-POR markets during the six months ended June 30, 2025.

We are exposed to wholesale counterparty credit risk in our retail and asset optimization activities. We manage this risk at a counterparty level and secure our exposure with collateral or guarantees when needed. At June 30, 2025, approximately $0.9 million of our total exposure of $2.2 million was either with a non-investment grade counterparty or otherwise not secured with collateral or a guarantee. The credit worthiness of the remaining exposure with other customers was evaluated with no material allowance recorded at June 30, 2025.

Interest Rate Risk

We are exposed to fluctuations in interest rates under our Senior Credit Facility and our Series A Preferred Stock. 

At June 30, 2025, we were co-borrowers under the Senior Credit Facility, under which $100.0 million of variable rate indebtedness was outstanding. Based on the average amount of our variable rate indebtedness outstanding during the three months ended June 30, 2025, a 1.0% increase in interest rates would have resulted in additional annual interest expense of approximately $1.0 million.

On July 16, 2025, our Board of Directors declared a quarterly cash dividend in the amount of $0.69732 per share for the Series A Preferred Stock for the second quarter of 2025 for an aggregate amount of $2.2 million for the quarter. Based on the Series A Preferred Stock outstanding on June 30, 2025, a 1.0% increase in interest rates would have resulted in additional dividends of $0.2 million for the quarter.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our Chief Executive Officer and our Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10-Q. The term “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, means controls and other procedures of a company that are designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving their objectives, and management necessarily applies its judgment in evaluating the cost benefit relationship of possible controls and procedures. Based on this evaluation, management concluded that our disclosure controls and procedures were effective as of June 30, 2025.

Changes in Internal Control over Financial Reporting

There was no change in our internal control over financial reporting identified in connection with the evaluation required by Rule 13a-15(d) and 15d-15(d) of the Exchange Act that occurred during the three months ended June 30, 2025 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

See Note 12 “Commitments and Contingencies” to Part I, Item 1 of this Report, which is incorporated by reference into this Part II, Item 1, for a description of certain ligation, legal proceedings, and regulatory matters.

Item 1A. Risk Factors. 

Holders of Series A Preferred Stock should carefully consider the risk factors under “Item 1A— Risk Factors” in our 2024 Form 10-K. There has been no material change in our risk factors from those described in the 2024 Form 10-K. Our description of risks are not the sole risks for investors in Series A Preferred Stock. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or results of operations.

Item 6. Exhibits	

The exhibits required to be filed by Item 6 are set forth in the Exhibit Index included below.

INDEX TO EXHIBITS	
  		Incorporated by Reference	
Exhibit	Exhibit Description	Form	Exhibit Number	Filing Date	SEC File No.	
2.1#	Membership Interest Purchase Agreement, by and among Spark Energy, Inc., Spark HoldCo, LLC, Provider Power, LLC, Kevin B. Dean and Emile L. Clavet, dated as of May 3, 2016.
	10-Q	2.1	5/5/2016	001-36559	
2.2#	Membership Interest Purchase Agreement, by and among Spark Energy, Inc., Spark HoldCo, LLC, Retailco, LLC and National Gas & Electric, LLC, dated as of May 3, 2016.	10-Q	2.2	5/5/2016	001-36559	
2.3#	Amendment No. 1 to the Membership Interest Purchase Agreement, dated as of July 26, 2016, by and among Spark Energy, Inc., Spark HoldCo, LLC, Provider Power, LLC, Kevin B. Dean and Emile L. Clavet.	8-K	2.1	8/1/2016	001-36559	
2.4#	Membership Interest and Stock Purchase Agreement, by and among Spark Energy, Inc., CenStar Energy Corp. and Verde Energy USA Holdings, LLC, dated as of May 5, 2017.	10-Q	2.4	5/8/2017	001-36559	
2.5	First Amendment to the Membership Interest and Stock Purchase Agreement, dated July 1, 2017, by and among Spark Energy, Inc., CenStar Energy Corp., and Verde Energy USA Holdings, LLC.
	8-K	2.1	7/6/2017	001-36559	
2.6#	Agreement to Terminate Earnout Payments, effective January 12, 2018, by and among Spark Energy, Inc., CenStar Energy Corp., Woden Holdings, LLC (fka Verde Energy USA Holdings, LLC), Verde Energy USA, Inc., Thomas FitzGerald, and Anthony Menchaca.	8-K	2.1	1/16/2018	001-36559	
2.7#	Asset Purchase Agreement, dated March 7, 2018, by and between Spark HoldCo, LLC and National Gas & Electric, LLC.	10-K	2.7	3/9/2018	001-36559	
2.8#	Asset Purchase Agreement, by and between Spark HoldCo, LLC, Starion Energy Inc., Starion Energy NY Inc., and Starion Energy PA Inc., dated October 19, 2018.	8-K	2.1	10/25/2018	001-36559	
2.9	First Amendment to Asset Purchase Agreement, by and between Spark HoldCo, LLC, Starion Energy Inc., Starion Energy NY Inc., and Starion Energy PA, Inc., effective May 1, 2020.	10-Q	2.9	8/5/2020	001-36559	
2.10^	
Agreement and Plan of Merger, dated as of December 29, 2023, by and among Retailco, LLC, NuRetailco LLC and Via Renewables, Inc.	8-K	2.1	1/2/2024	001-36559	
3.1	Composite Amended and Restated Certificate of Incorporation of Via Renewables, Inc., as amended through March 21, 2023	10-K	3.1	2/29/2024	001-36559	
3.2	Second Amended and Restated Bylaws of Via Renewables, Inc	8-K	3.2	8/9/2021	001-36559	
3.3	Certificate of Designations of Rights and Preferences of 8.75% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock	8-A	5	3/14/2017	001-36559	
4.1	Description of Securities	10-Q	4.1	8/1/2024	001-36559	
10.1	Credit Agreement, dated June 30, 2022, by and among Via Renewables, Inc., Spark HoldCo, LLC, and the other subsidiaries of Via Renewables, Inc. and Spark HoldCo, LLC party thereto, as co-borrowers, Woodforest National Bank, as administrative agent, swing bank, swap bank, issuing bank, joint-lead arranger, sole bookrunner and syndication agent, BOKF, NA (d/b/a/ Bank of Texas), as joint-lead arranger and issuing bank, and the other financial institutions party thereto. 	8-K	10.1	7/7/2022	001-36559	
10.2#	First Amendment to Credit Agreement, dated June 28, 2024, by and among Via Renewables, Inc., Spark HoldCo, LLC, and the other subsidiaries of Via Renewables, Inc. and Spark HoldCo, LLC party thereto, as co-borrowers, Woodforest National Bank, as administrative agent, swing bank, swap bank, issuing bank, joint-lead arranger, sole bookrunner and syndication agent, and the other financial institutions party thereto, amending June 20, 2022 Credit Agreement	8-K	10.1	6/28/2024	001-36559	
10.3	Amended and Restated Subordinated Promissory Note (Note No. 8), dated June 28, 2024, by and among Via Renewables, Inc., Spark HoldCo, LLC and Retailco, LLC.	8-K	10.2	6/28/2024	001-36559	
10.4	Asset Purchase Agreement by and between Tomorrow Energy Corp, as Seller, and Spark HoldCo, LLC, as Buyer, dated as of October 22, 2024	8-K	2.1	10/25/2024	001-36559	
10.5	Amendment No. 3 to the Third Amended and Restated Limited Liability Company Agreement of Spark Holdco, LLC, dated as of October 30, 2024, by and between Via Renewables, Inc., Spark HoldCo, LLC, and Retailco, LLC.	10-Q	10.4	10/31/2024	001-36559	
31.1*	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.					
31.2*	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.					
32**	Certifications pursuant to 18 U.S.C. Section 1350.					
101.INS*	XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL					
101.SCH*	Inline XBRL Taxonomy Extension Schema Document.					
101.CAL*	Inline XBRL Taxonomy Extension Calculation Linkbase Document.					
101.LAB*	Inline XBRL Taxonomy Extension Label Linkbase Document.					
101.PRE*	Inline XBRL Taxonomy Extension Presentation Linkbase Document.					
101.DEF*	Inline XBRL Taxonomy Extension Definition Linkbase Document.					
104* 	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101.INS)					

* Filed herewith
** Furnished herewith
^ The disclosure letters contemplated by this Agreement and Plan of Merger and the Exhibits to this Agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The registrant hereby agrees to supplementally furnish to the SEC upon request any omitted disclosure letters or exhibits to the Agreement and Plan of Merger.
# Certain schedules, exhibits and annexes have been omitted in reliance on Item 601 (a)(5) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted schedule, exhibit or annex to the Commission upon request

 SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.
						
	Via Renewables, Inc.	

July 31, 2025			/s/ Mike Barajas	
			Mike Barajas	
			Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)