spke-20230930


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

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2023

☐ 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
Class A common stock, par value $0.01 per share	VIA	The NASDAQ Global Select Market
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 ☒ 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 ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ☐ Accelerated filer ☒

Non-accelerated filer ☐ 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 ☒

There were 3,232,701 shares of Class A common stock, 4,000,000 shares of Class B common stock and 3,567,543 shares of Series A Preferred Stock outstanding as of October 31, 2023.


VIA RENEWABLES, INC.
INDEX TO QUARTERLY REPORT ON FORM 10-Q
For the Quarter Ended September 30, 2023
						Page No.
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED BALANCE SHEETS AS OF SEPTEMBER 30, 2023 AND DECEMBER 31, 2022 (unaudited)						5

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2023 AND 2022 (unaudited)						6

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2023 AND 2022 (unaudited)						7

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2023 AND 2022 (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						38
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK						56
ITEM 4. CONTROLS AND PROCEDURES						58
PART II. OTHER INFORMATION						60
ITEM 1. LEGAL PROCEEDINGS						60
ITEM 1A. RISK FACTORS						60




ITEM 6. EXHIBITS						61

SIGNATURES						63

Table of Contents

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 implied amount of cash dividends and distributions on our Class A common stock and 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:

•our ability to remediate the material weakness in our internal control over financial reporting, the identification of any additional material weakness in the future or otherwise failing to maintain an effective system of internal controls;

•the ultimate impact of the Winter Storm Uri, including future benefits or costs related to ERCOT market securitization efforts, and any corrective 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;

•competition; and

•the “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2022, 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

Table of Contents

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.

Table of Contents

PART I. — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Table of Contents

VIA RENEWABLES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share counts)

(unaudited)


	September 30, 2023		December 31, 2022
Assets
Current assets:
Cash and cash equivalents	$	45,137	$	33,658
Restricted cash	—		1,693
Accounts receivable, net of allowance for credit losses of $4,935 at September 30, 2023 and $4,335 at December 31, 2022	51,275		81,466
Accounts receivable—affiliates	4,569		6,455
Inventory	3,027		4,405
Fair value of derivative assets, net	166		1,632
Customer acquisition costs, net	5,005		3,530
Customer relationships, net	342		2,520

Deposits	8,230		10,568
Renewable energy credit asset	24,871		24,251

Other current assets	7,524		8,749
Total current assets	150,146		178,927
Property and equipment, net	4,758		4,691
Fair value of derivative assets, net	—		666
Customer acquisition costs, net	1,729		1,683
Customer relationships, net	225		481
Deferred tax assets	17,100		20,437
Goodwill	120,343		120,343
Other assets	2,775		3,722
Total assets	$	297,076	$	330,950

Liabilities, Series A Preferred Stock and Stockholders' Equity
Current liabilities:
Accounts payable	$	22,548	$	53,296
Accounts payable—affiliates	1,062		265
Accrued liabilities	10,413		8,431
Renewable energy credit liability	13,173		13,722
Fair value of derivative liabilities, net	13,497		16,132






Other current liabilities	58		322
Total current liabilities	60,751		92,168
Long-term liabilities:
Fair value of derivative liabilities, net	1,451		2,715

Long-term portion of Senior Credit Facility	105,000		100,000
Subordinated debt—affiliates	—		20,000




Other long-term liabilities	—		18
Total liabilities	167,202		214,901
Commitments and contingencies (Note 12)

Series A Preferred Stock, par value $0.01 per share, 20,000,000 shares authorized, 3,567,543 shares issued and outstanding at September 30, 2023 and December 31, 2022	88,045		87,713

Stockholders' equity:
Common Stock:

Class A common stock, par value $0.01 per share, 120,000,000 shares authorized, 3,261,620 shares issued and 3,232,701 shares outstanding at September 30, 2023 and 3,200,472 shares issued and 3,171,553 shares outstanding at December 31, 2022	32		32
Class B common stock, par value $0.01 per share, 60,000,000 shares authorized, 4,000,000 shares issued and outstanding at September 30, 2023 and December 31, 2022	40		40


Additional paid-in capital	39,230		42,871
Accumulated other comprehensive loss	(40)		(40)
Retained earnings	12,038		2,073
Treasury stock, at cost, 28,919 shares at September 30, 2023 and December 31, 2022	(2,406)		(2,406)
Total stockholders' equity	48,894		42,570
Non-controlling interest in Spark HoldCo, LLC	(7,065)		(14,234)
Total equity	41,829		28,336
Total liabilities, Series A Preferred Stock and Stockholders' equity	$	297,076	$	330,950

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

Table of Contents

VIA RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

(unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

Revenues:
Retail revenues	$	109,753	$	117,187	$	337,499	$	343,592
Net asset optimization (expense) revenue	(936)		1,672		(5,568)		(480)
Other revenue	1,422		—		1,559		—
Total Revenues	110,239		118,859		333,490		343,112
Operating Expenses:
Retail cost of revenues	71,050		102,212		234,417		232,621
General and administrative	17,135		16,302		51,073		44,820
Depreciation and amortization	1,816		3,270		7,146		13,390
Total Operating Expenses	90,001		121,784		292,636		290,831
Operating income (loss)	20,238		(2,925)		40,854		52,281
Other (expense) income:
Interest expense	(2,233)		(2,002)		(7,377)		(5,129)
Interest and other income	9		11		96		265
Total other expenses	(2,224)		(1,991)		(7,281)		(4,864)
Income (loss) before income tax expense	18,014		(4,916)		33,573		47,417
Income tax expense (benefit)	3,355		(48)		6,599		8,726
Net income (loss)	$	14,659	$	(4,868)	$	26,974	$	38,691
Less: Net income (loss) attributable to non-controlling interests	7,140		(3,987)		11,661		21,981
Net income (loss) attributable to Via Renewables, Inc. stockholders	$	7,519	$	(881)	$	15,313	$	16,710
Less: Dividend on Series A Preferred Stock	2,708		2,026		7,892		5,677
Net income (loss) attributable to stockholders of Class A common stock	$	4,811	$	(2,907)	$	7,421	$	11,033







Net income (loss) attributable to Via Renewables, Inc. per share of Class A common stock
Basic	$	1.49	$	(0.92)	$	2.32	$	3.50
Diluted	$	1.47	$	(0.92)	$	2.29	$	3.48

Weighted average shares of Class A common stock outstanding
Basic	3,232		3,172		3,204		3,151
Diluted	7,232		3,172		7,204		3,173

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

Table of Contents

VIA RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

(in thousands)

(unaudited)


Nine Months Ended September 30, 2023
	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, 2022	3,201	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	42,871	$	2,073	$	42,570	$	(14,234)	$	28,336
Stock based compensation	—	—	—			—		—		—		1,779		—		1,779		—		1,779
Restricted stock unit vesting	47		—	—		—		—		—		(186)		—		(186)		—		(186)
Consolidated net income	—	—	—	—		—		—		—		—		15,313		15,313		11,661		26,974
Stock issued - reverse stock split	14	—	—	—		—		—		—		—		—		—		—		—

Distributions paid to non-controlling unit holders	—	—	—	—		—		—		—		—		—		—		(4,308)		(4,308)
Dividends paid to Class A common stockholders ($0.90625 per share)	—	—	—	—		—		—		—		(2,874)		—		(2,874)		—		(2,874)
Dividends paid to Preferred Stockholders	—	—	—	—		—		—		—		(2,544)		(5,348)		(7,892)		—		(7,892)



Changes in ownership interest	—	—	—	—		—		—		—		184		—		184		(184)		—
Balance at September 30, 2023	3,262	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	39,230	$	12,038	$	48,894	$	(7,065)	$	41,829

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

Table of Contents


Three Months Ended September 30, 2023
	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 June 30, 2023	3,260	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	38,559	$	7,227	$	43,412	$	(13,944)	$	29,468


Stock based compensation	—	—	—	—		—		—		—		485		—		485		—		485
Restricted stock unit vesting	2	—	—	—		—		—		—		—		—		—		—		—
Consolidated net income	—	—	—	—		—		—		—		—		7,519		7,519		7,140		14,659
Distributions paid to non-controlling unit holders	—	—	—	—		—		—		—		—		—		—		(75)		(75)

Dividends paid to Preferred Stockholders	—	—	—	—		—		—		—		—		(2,708)		(2,708)		—		(2,708)


Changes in Ownership Interest	—	—	—	—		—		—		—		186		—		186		(186)		—
Balance at September 30, 2023	3,262	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	39,230	$	12,038	$	48,894	$	(7,065)	$	41,829

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

Table of Contents


Nine Months Ended September 30, 2022
	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 (Deficit)		Total Stockholders' Equity		Non-controlling Interest		Total Equity
Balance at December 31, 2021	3,159	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	53,918	$	173	$	51,717	$	(3,168)	$	48,549


Stock based compensation	—	—	—	—		—		—		—		2,478		—		2,478		—		2,478
Restricted stock unit vesting	42		—	—		—		—		—		(471)		—		(471)		—		(471)
Consolidated net income	—	—	—	—		—		—		—		—		16,710		16,710		21,981		38,691

Distributions paid to non-controlling unit holders	—	—	—	—		—		—		—		—		—		—		(10,928)		(10,928)
Dividends paid to Class A common stockholders ($2.71875 per share)	—	—	—	—		—		—		—		—		(8,587)		(8,587)		—		(8,587)
Dividends paid to Preferred Stockholders	—	—	—	—		—		—		—		—		(5,677)		(5,677)		—		(5,677)



Changes in ownership interest	—	—	—	—		—		—		—		213		—		213		(213)		—
Balance at September 30, 2022	3,201	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	56,138	$	2,619	$	56,383	$	7,672	$	64,055

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

Table of Contents


Three Months Ended September 30, 2022
	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 (Deficit)		Total Stockholders' Equity		Non-controlling Interest		Total Equity
Balance at June 30, 2022	3,201	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	55,702	$	8,401	$	61,729	$	15,099	$	76,828


Stock based compensation	—	—	—	—		—		—		—		621		—		621		—		621

Consolidated net loss	—	—	—	—		—		—		—		—		(881)		(881)		(3,987)		(4,868)

Distributions paid to non-controlling unit holders	—	—	—	—		—		—		—		—		—		—		(3,625)		(3,625)
Dividends paid to Class A common stockholders ($0.90625 per share)	—	—	—	—		—		—		—		—		(2,874)		(2,874)		—		(2,874)
Dividends paid to Preferred Stockholders	—	—	—	—		—		—		—		—		(2,027)		(2,027)		—		(2,027)


Changes in ownership interest	—	—	—	—		—		—		—		(185)		—		(185)		185		—
Balance at September 30, 2022	3,201	4,000	(29)	$	32	$	40	$	(2,406)	$	(40)	$	56,138	$	2,619	$	56,383	$	7,672	$	64,055

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

Table of Contents

VIA RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)


	Nine Months Ended September 30,
	2023		2022
Cash flows from operating activities:
Net income	$	26,974	$	38,691
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization expense	7,146		13,390
Deferred income taxes	3,337		5,048

Stock based compensation	1,784		2,590
Amortization of deferred financing costs	619		919


Bad debt expense	2,717		2,895
Loss (gain) on derivatives, net	50,428		(55,815)
Current period cash settlements on derivatives, net	(51,767)		35,922

Other	126		43
Changes in assets and liabilities:
Decrease in accounts receivable	27,473		7,075
Decrease (increase) in accounts receivable—affiliates	1,886		(1,824)
Decrease (increase) in inventory	1,378		(3,292)
Increase in customer acquisition costs	(4,961)		(4,274)
Decrease in prepaid and other current assets	1,895		1,978

Decrease (increase) in other assets	641		(722)
Decrease in accounts payable and accrued liabilities	(29,334)		(19,771)
Increase (decrease) in accounts payable—affiliates	797		(60)
Decrease in other current liabilities	(264)		(1,475)
Decrease in other non-current liabilities	(18)		(107)
Net cash provided by operating activities	40,857		21,211
Cash flows from investing activities:
Purchases of property and equipment	(1,144)		(1,940)
Acquisition of Customers	—		(4,460)

Net cash used in investing activities	(1,144)		(6,400)
Cash flows from financing activities:

Borrowings on notes payable	258,000		229,000
Payments on notes payable	(253,000)		(271,000)
Net (paydown) borrowings on subordinated debt facility	(20,000)		20,000



Restricted stock vesting	(186)		(663)


Payment of dividends to Class A common stockholders	(2,874)		(8,587)
Payment of distributions to non-controlling unitholders	(4,308)		(10,928)
Payment of Preferred Stock dividends	(7,559)		(5,602)

Net cash used in financing activities	(29,927)		(47,780)
Increase (decrease) in Cash, cash equivalents and Restricted cash	9,786		(32,969)
Cash, cash equivalents and Restricted cash—beginning of period	35,351		75,320
Cash, cash equivalents and Restricted cash—end of period	$	45,137	$	42,351
Supplemental Disclosure of Cash Flow Information:
Non-cash items:
Property and equipment purchase accrual	$	15	$	(8)



Cash paid during the period for:
Interest	$	6,736	$	3,347
Taxes	$	2,671	$	280

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

Table of Contents

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 our retail energy services. We conduct our retail energy services 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, 2022 (the “2022 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.

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, Majority Shareholder, and Chief Executive Officer

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

Table of Contents

Holdings LLC ("NuDevco Retail Holdings"), which is a wholly owned subsidiary of Electric HoldCo, LLC, which is also a wholly owned subsidiary of TxEx.

ERCOT Securitization Proceeds

In June 2022, the Company received $9.6 million from Electric Reliability Council of Texas ("ERCOT") related to Public Utility Regulatory Act ("PURA") Subchapter N Securitization financing. The Company accounted for the proceeds received as the recovery of costs of sales and services from a vendor under FASB ASC Topic 705, Cost of Sales and Services reflected as a reduction of retail cost of revenues within our consolidated statements of operations for the nine months ended September 30, 2022, as that is where the initial costs related to the impact of Winter Storm Uri were recorded.

New Accounting Standards Recently Adopted

There have been no changes to our significant accounting policies as disclosed in our 2022 Form 10-K.

Standards Being Evaluated/Standards Not Yet Adopted

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 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, natural gas, and related services are recognized as the Company transfers the promised goods and services 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 twelve months. Customers are billed and generally 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 for our reportable segments 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).

Table of Contents


	Reportable Segments
	Three Months Ended September 30, 2023				Three Months Ended September 30, 2022
	Retail Electricity (a)		Retail Natural Gas		Total Reportable Segments		Retail Electricity (a)		Retail Natural Gas		Total Reportable Segments

Primary markets (b)
New England	$	30,119	$	993	$	31,112	$	31,366	$	821	$	32,187
Mid-Atlantic	32,858		3,478		36,336		33,761		5,281		39,042
Midwest	9,384		1,089		10,473		12,165		1,617		13,782
Southwest	25,494		6,338		31,832		27,678		4,498		32,176
	$	97,855	$	11,898	$	109,753	$	104,970	$	12,217	$	117,187

Customer type
Commercial	$	11,655	$	6,577	$	18,232	$	12,560	$	6,661	$	19,221
Residential	87,012		5,411		92,423		97,177		5,047		102,224
Unbilled revenue (c)	(812)		(90)		(902)		(4,767)		509		(4,258)
	$	97,855	$	11,898	$	109,753	$	104,970	$	12,217	$	117,187

Customer credit risk
POR	$	55,603	$	4,078	$	59,681	$	63,444	$	6,202	$	69,646
Non-POR	42,252		7,820		50,072		41,526		6,015		47,541
	$	97,855	$	11,898	$	109,753	$	104,970	$	12,217	$	117,187


	Reportable Segments
	Nine Months Ended September 30, 2023				Nine Months Ended September 30, 2022
	Retail Electricity (a)		Retail Natural Gas		Total Reportable Segments		Retail Electricity (a)		Retail Natural Gas		Total Reportable Segments

Primary markets (b)
New England	$	89,268	$	6,060	$	95,328	$	84,463	$	7,331	$	91,794
Mid-Atlantic	84,548		28,753		113,301		89,304		32,396		121,700
Midwest	24,342		13,409		37,751		31,396		14,358		45,754
Southwest	57,289		33,830		91,119		70,138		14,206		84,344
	$	255,447	$	82,052	$	337,499	$	275,301	$	68,291	$	343,592

Customer type
Commercial	$	31,301	$	47,021	$	78,322	$	33,119	$	37,854	$	70,973
Residential	227,669		49,158		276,827		246,662		36,392		283,054
Unbilled revenue (c)	(3,523)		(14,127)		(17,650)		(4,480)		(5,955)		(10,435)
	$	255,447	$	82,052	$	337,499	$	275,301	$	68,291	$	343,592

Customer credit risk
POR	$	146,826	$	36,432	$	183,258	$	166,346	$	41,147	$	207,493
Non-POR	108,621		45,620		154,241		108,955		27,144		136,099
	$	255,447	$	82,052	$	337,499	$	275,301	$	68,291	$	343,592

(a) Retail Electricity includes Services

Table of Contents

(b) The primary markets include the following states:

•New England - Connecticut, Maine, Massachusetts and New Hampshire;

•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.

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

Reconciliation to Consolidated Financial Information

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Total Reportable Segments Revenue	$	109,753	$	117,187	$	337,499	$	343,592
Net asset optimization (expense) revenue	(936)		1,672		(5,568)		(480)
Other Revenue	1,422		—		1,559		—
Total Revenues	$	110,239	$	118,859	$	333,490	$	343,112

We record gross receipts taxes on a gross basis in retail revenues and retail cost of revenues. During the three months ended September 30, 2023 and 2022, our retail revenues included gross receipts taxes of $0.3 million and $0.4 million, respectively, and our retail cost of revenues included gross receipts taxes of $1.5 million and $1.4 million, respectively. During the nine months ended September 30, 2023 and 2022, our retail revenues included gross receipt taxes of $0.8 million and $1.0 million, respectively, and our retail cost of revenues included gross receipts taxes of $4.1 million and $4.0 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 doubtful accounts 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 when the accounts receivable is deemed to be uncollectible.

Table of Contents

A rollforward of our allowance for credit losses for the nine months ended September 30, 2023 are presented in the table below (in thousands):




Balance at December 31, 2022	$	(4,335)

Current period credit loss provision	(2,717)
Write-offs	2,200
Recovery of previous write-offs	(83)
Balance at September 30, 2023	$	(4,935)

4. Equity

Non-controlling Interest

We hold an economic interest and are the sole managing member in Spark HoldCo, with affiliates of our Founder 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. The Company and affiliates owned the following economic interests in Spark HoldCo at September 30, 2023 and December 31, 2022, respectively.


	The Company		Affiliated Owners
September 30, 2023	44.92	%	55.08	%
December 31, 2022	44.45	%	55.55	%

The following table summarizes the portion of net income and income tax expense attributable to non-controlling interest (in thousands):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

Net income (loss) before taxes allocated to non-controlling interest	$	8,398	$	(3,909)	$	14,021	$	23,432
Less: Income tax expense allocated to non-controlling interest	1,258		78		2,360		1,451



Net income (loss) attributable to non-controlling interests	$	7,140	$	(3,987)	$	11,661	$	21,981

Class A Common Stock and Class B Common Stock

Holders of the Company's Class A common stock and Class B common stock vote together as a single class on all matters presented to our stockholders for their vote or approval, except as otherwise required by applicable law or by our certificate of incorporation.

Reverse Stock Split

On March 20, 2023, the Company’s shareholders approved at a special meeting a proposal by the Company’s Board of Directors to consummate a reverse stock split of the Company’s Class A common stock at a ratio between 1 for 2 to 1 for 5 and (ii) Class B common stock at a ratio between 1 for 2 to 1 for 5, with such ratios to be determined by the Chief Executive Officer or the Chief Financial Officer, or to determine not to proceed with the reverse stock split, during a period of time not to exceed the one-year anniversary of the special meeting date (the “Reverse Stock Split”).

On March 20, 2023, the Company filed a Certificate of Amendment to the Company’s Amended and Restated Certificate of Incorporation with the Delaware Secretary of State to effect the Reverse Stock Split at a ratio of 1 to 5

Table of Contents

for each issued and outstanding share of Class A common stock and Class B common stock as of March 21, 2023 at 5:30 PM ET. The Class A common stock began trading on a post-split basis on March 22, 2023.

No fractional shares were issued as a result of the Reverse Stock Split and it did not impact the par value of the Class A common stock or Class B common stock. Any fractional shares that would otherwise have resulted from the Reverse Stock Split were rounded up to the next whole number. The number of authorized shares of Common Stock remained unchanged at 120,000,000 shares of Class A common stock and 60,000,000 shares of Class B common stock.

All shares of Class A common stock and Class B common stock and per share amounts in the accompanying consolidated financial statements and related notes have been retrospectively restated to reflect the effect of the Reverse Stock Split effective March 21, 2023.

Dividends on Class A Common Stock

Dividends declared for the Company's Class A common stock are reported as a reduction of retained earnings, or a reduction of additional paid in capital to the extent retained earnings are exhausted. During the three and nine months ended September 30, 2023, we paid zero and $2.9 million in dividends to the holders of the Company's Class A common stock.

If we pay our stated dividends to holders of our Class A common stock, our subsidiary, Spark HoldCo is required to make corresponding distributions to holders of its units, including those holders that own our Class B common stock (our non-controlling interest holder). As a result, during the three and nine months ended September 30, 2023, Spark HoldCo made corresponding distributions of zero and $3.6 million to our non-controlling interest holders.

In April 2023, we announced that our Board of Directors elected to temporarily suspend the quarterly cash dividend on the Class A common stock. During the three months ended September 30, 2023, we did not pay dividends to the holders of the Company's Class A common stock and did not make corresponding distributions to our non-controlling interest holders.

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 nine months ended September 30, 2023 and 2022 (in thousands, except per share data):

Table of Contents


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income (loss) attributable to Via Renewables, Inc. stockholders	$	7,519	$	(881)	$	15,313	$	16,710
Less: Dividend on Series A Preferred Stock	2,708		2,026		7,892		5,677
Net income (loss) attributable to stockholders of Class A common stock	$	4,811	$	(2,907)	$	7,421	$	11,033

Basic weighted average Class A common shares outstanding	3,232		3,172		3,204		3,151
Basic income (loss) per share attributable to stockholders	$	1.49	$	(0.92)	$	2.32	$	3.50

Net income (loss) attributable to stockholders of Class A common stock	$	4,811	$	(2,907)	$	7,421	$	11,033
Effect of conversion of Class B common stock to shares of Class A common stock	5,803		—		9,088		—

Diluted net income (loss) attributable to stockholders of Class A common stock	$	10,614	$	(2,907)	$	16,509	$	11,033

Basic weighted average Class A common shares outstanding	3,232		3,172		3,204		3,151
Effect of dilutive Class B common stock	4,000		—		4,000		—

Effect of dilutive restricted stock units	—		—		—		22
Diluted weighted average shares outstanding	7,232		3,172		7,204		3,173

Diluted income (loss) per share attributable to stockholders	$	1.47	$	(0.92)	$	2.29	$	3.48

The computation of diluted earnings per share for the three and nine months ended September 30, 2022, excludes 4.0 million and 4.0 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 except VES. 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 September 30, 2023 and December 31, 2022 (in thousands):

Table of Contents


	September 30, 2023		December 31, 2022
Assets
Current assets:
Cash and cash equivalents	$	44,539	$	33,267
Accounts receivable	50,689		81,363

Other current assets	50,812		61,162
Total current assets	146,040		175,792
Non-current assets:
Goodwill	120,343		120,343

Other assets	11,106		13,675
Total non-current assets	131,449		134,018
Total Assets	$	277,489	$	309,810

Liabilities
Current liabilities:
Accounts payable and accrued liabilities	$	32,503	$	61,367



Other current liabilities	63,369		63,673
Total current liabilities	95,872		125,040
Long-term liabilities:
Long-term portion of Senior Credit Facility	105,000		100,000
Subordinated debt — affiliate	—		20,000

Other long-term liabilities	1,451		2,733
Total long-term liabilities	106,451		122,733
Total Liabilities	$	202,323	$	247,773

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, the Company uses 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.

A summary of our preferred equity balance for the nine months ended September 30, 2023 is as follows:

Table of Contents


	(in thousands)






Balance at December 31, 2022	$	87,713

Accumulated dividends on Series A Preferred Stock	332
Balance at September 30, 2023	$	88,045

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 September 30, 2023 and December 31, 2022, we offset $2.5 million and $2.7 million, respectively, in collateral to net against the related derivative 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

Table of Contents

Commodity

Notional

September 30, 2023

December 31, 2022

Natural Gas

MMBtu

6,049

5,984

Electricity

MWh

1,017

1,380

Trading

Commodity

Notional

September 30, 2023

December 31, 2022

Natural Gas

MMBtu

830

957

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 September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
(Loss) gain on non-trading derivatives, net	$	(6,193)	$	(1,413)	$	(49,002)	$	54,570
(Loss) gain on trading derivatives, net	(798)		(232)		(1,426)		1,245
(Loss) gain on derivatives, net	(6,991)		(1,645)		(50,428)		55,815
Current period settlements on non-trading derivatives	$	14,430	$	(14,068)	$	50,699	$	(36,067)
Current period settlements on trading derivatives	670		(10)		1,068		145
Total current period settlements on derivatives	$	15,100	$	(14,078)	$	51,767	$	(35,922)

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):


	September 30, 2023
Description	Gross Assets		Gross Amounts Offset		Net Assets		Cash Collateral Offset		Net Amount Presented
Non-trading commodity derivatives	$	262	$	(98)	$	164	$	—	$	164
Trading commodity derivatives	2		—		2		—		2
Total Current Derivative Assets	264		(98)		166		—		166
Non-trading commodity derivatives	—		—		—		—		—

Total Non-current Derivative Assets	—		—		—		—		—
Total Derivative Assets	$	264	$	(98)	$	166	$	—	$	166


Description	Gross Liabilities		Gross Amounts Offset		Net Liabilities		Cash Collateral Offset		Net Amount Presented
Non-trading commodity derivatives	$	(27,916)	$	12,569	$	(15,347)	$	2,363	$	(12,984)
Trading commodity derivatives	(514)		1		(513)		—		(513)
Total Current Derivative Liabilities	(28,430)		12,570		(15,860)		2,363		(13,497)
Non-trading commodity derivatives	(2,626)		991		(1,635)		184		(1,451)
Trading commodity derivatives	—		—		—		—		—
Total Non-current Derivative Liabilities	(2,626)		991		(1,635)		184		(1,451)
Total Derivative Liabilities	$	(31,056)	$	13,561	$	(17,495)	$	2,547	$	(14,948)


	December 31, 2022
Description	Gross Assets		Gross Amounts Offset		Net Assets		Cash Collateral Offset		Net Amount Presented
Non-trading commodity derivatives	$	709	$	(154)	$	555	$	—	$	555
Trading commodity derivatives	1,267		(190)		1,077		—		1,077
Total Current Derivative Assets	1,976		(344)		1,632		—		1,632
Non-trading commodity derivatives	1,364		(698)		666		—		666
Trading commodity derivatives	—		—		—		—		—
Total Non-current Derivative Assets	1,364		(698)		666		—		666
Total Derivative Assets	$	3,340	$	(1,042)	$	2,298	$	—	$	2,298


Description	Gross Liabilities		Gross Amounts Offset		Net Liabilities		Cash Collateral Offset		Net Amount Presented
Non-trading commodity derivatives	$	(42,586)	$	24,969	$	(17,617)	$	2,715	$	(14,902)
Trading commodity derivatives	(1,831)		601		(1,230)		—		(1,230)
Total Current Derivative Liabilities	(44,417)		25,570		(18,847)		2,715		(16,132)
Non-trading commodity derivatives	(2,907)		192		(2,715)		—		(2,715)
Trading commodity derivatives	—		—		—		—		—
Total Non-current Derivative Liabilities	(2,907)		192		(2,715)		—		(2,715)
Total Derivative Liabilities	$	(47,324)	$	25,762	$	(21,562)	$	2,715	$	(18,847)

7. Property and Equipment

Property and equipment consist of the following (in thousands):


	Estimated useful lives (years)	September 30, 2023		December 31, 2022

Information technology	2 – 5	$	7,412	$	7,680

Furniture and fixtures	2 – 5	—		20
Total		7,412		7,700
Accumulated depreciation		(2,654)		(3,009)
Property and equipment—net		$	4,758	$	4,691

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 September 30, 2023 and December 31, 2022, information technology includes $1.2 million and $0.9 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 $0.4 million for the three months ended September 30, 2023 and 2022, respectively, and $1.1 million and $1.3 million for the nine months ended September 30, 2023 and 2022, respectively.

8. Intangible Assets

Goodwill, customer relationships and trademarks consist of the following amounts (in thousands):


	September 30, 2023		December 31, 2022
Goodwill	$	120,343	$	120,343
Customer relationships—Acquired
Cost	$	—	$	5,026
Accumulated amortization	—		(4,825)
Customer relationships—Acquired	$	—	$	201
Customer relationships—Other
Cost	$	961	$	7,886
Accumulated amortization	(394)		(5,086)
Customer relationships—Other, net	$	567	$	2,800
Trademarks
Cost	$	4,040	$	4,041
Accumulated amortization	(1,515)		(1,213)
Trademarks, net	$	2,525	$	2,828

Changes in goodwill, customer relationships and trademarks consisted of the following (in thousands):


	Goodwill		Customer Relationships— Acquired		Customer Relationships— Other		Trademarks
Balance at December 31, 2022	$	120,343	$	201	$	2,800	$	2,828
Additions	—		—		—		—

Amortization	—		(201)		(2,233)		(303)
Balance at September 30, 2023	$	120,343	$	—	$	567	$	2,525

During the three months ended March 31, 2022, the Company changed the estimated average life for Customer Relationships – Other from three years to eighteen months, resulting in approximately $0.9 million of additional amortization recorded in the three months ended March 31, 2022.

Estimated future amortization expense for customer relationships and trademarks at September 30, 2023 is as follows (in thousands):


Year ending December 31,

2023 (remaining three months)	$	186
2024	746
2025	543
2026	404
2027	404
> 5 years	809
Total	$	3,092

9. Debt

Debt consists of the following amounts as of September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023		December 31, 2022








Long-term debt:
Senior Credit Facility (1) (2)	$	105,000	$	100,000
Subordinated Debt	—		20,000

Total long-term debt	105,000		120,000
Total debt	$	105,000	$	120,000

(1) As of September 30, 2023 and December 31, 2022, the weighted average interest rate on the Senior Credit Facility was 8.81% and 7.83%, respectively.

(2) As of September 30, 2023 and December 31, 2022, we had $29.0 million and $34.4 million in letters of credit issued, respectively.

Capitalized financing costs associated with our Senior Credit Facility were $1.4 million and $2.1 million as of September 30, 2023 and December 31, 2022, respectively. Of these amounts, $0.8 million and $0.8 million are recorded in other current assets, and $0.6 million and $1.3 million are recorded in other non-current assets in the condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022, respectively.

Interest expense consists of the following components for the periods indicated (in thousands):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022			2023		2022
Senior Credit Facility	$	1,593	$	1,270		$	5,394	$	2,849

Letters of credit fees and commitment fees	435		504			1,299		1,266
Amortization of deferred financing costs	206		206			619		919
Other	(1)		22			65		95
Interest Expense	$	2,233	$	2,002		$	7,377	$	5,129

Senior Credit Facility

The Company and Spark HoldCo, and together with certain subsidiaries of the Company and Spark Holdco, (the “Co-Borrowers”) maintain a senior secured credit facility (the “Senior Credit Facility”), which allows the Co-Borrowers to borrow up to $195.0 million on a revolving basis. The Senior Credit Facility provides for working capital loans, loans to fund acquisitions, swingline loans and letters of credit. The Senior Credit Facility expires on June 30, 2025, and all amounts outstanding thereunder are payable on the expiration date.

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 3.25% to 4.50% depending on the type of borrowing and the average outstanding amount of loans and letters of credit under the Credit Agreement 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 Credit Agreement 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 Credit Agreement 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 Credit Agreement 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 September 30, 2023 was 1.63 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 filings with the Securities and Exchange Commission, to Adjusted EBITDA of no more than 2.50 to 1.00. Our Maximum Total Leverage Ratio as of September 30, 2023 was 1.94 to 1.00.

•Maximum Senior Secured Leverage Ratio. The Company must maintain a Senior Secured Leverage Ratio of no more than 2.00 to 1.00. The Senior Secured Leverage Ratio is defined as the ratio of (a) all consolidated indebtedness that is secured by a lien on any property of any loan party (including the effective amount of all loans then outstanding under the Senior Credit Facility but excluding eligible subordinated debt and letter of credit obligations) to (b) Adjusted EBITDA for the most recent twelve month period then ended. Our Maximum Senior Secured Leverage Ratio as of September 30, 2023 was 1.87 to 1.00.

As of September 30, 2023, the Company was in compliance with financial covenants under the Senior Credit Facility. The Company experienced compressed gross profit due to an extreme elevation of commodity costs during 2022, impacting calculated Adjusted EBITDA, a primary component of the financial covenants described above. The Company is actively working to manage the impact of gross profit compression due to market volatility on financial covenant compliance. Maintaining compliance with our covenants under our Senior Credit Facility may impact our ability to pay dividends.

The Credit Agreement contains various customary affirmative covenants that require, among other things, the Company to maintain insurance, pay its obligations and comply with law. The Credit Agreement 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 and Class A common 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 Credit Agreement 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 through January 31, 2026. 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 September 30, 2023, and December 31, 2022, there were zero and $20.0 million, respectively, of 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.

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
September 30, 2023
Non-trading commodity derivative assets	$	—	$	164	$	—	$	164
Trading commodity derivative assets	—		2		—		2
Total commodity derivative assets	$	—	$	166	$	—	$	166
Non-trading commodity derivative liabilities	$	—	$	(14,435)	$	—	$	(14,435)
Trading commodity derivative liabilities	—		(513)		—		(513)
Total commodity derivative liabilities	$	—	$	(14,948)	$	—	$	(14,948)


	Level 1		Level 2		Level 3		Total
December 31, 2022
Non-trading commodity derivative assets	$	72	$	1,149	$	—	$	1,221
Trading commodity derivative assets	—		1,077		—		1,077
Total commodity derivative assets	$	72	$	2,226	$	—	$	2,298
Non-trading commodity derivative liabilities	$	—	$	(17,617)	$	—	$	(17,617)
Trading commodity derivative liabilities	—		(1,230)		—		(1,230)
Total commodity derivative liabilities	$	—	$	(18,847)	$	—	$	(18,847)

We had no transfers of assets or liabilities between any of the above levels during the nine months ended September 30, 2023 and the year ended December 31, 2022.

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 September 30, 2023 and December 31, 2022, the credit risk valuation adjustment was a reduction of derivative liabilities, net of $0.3 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 September 30, 2023, we had a net deferred tax asset of $17.1 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 September 30, 2023 and 2022 was 18.6% and 1.0%, respectively. The effective U.S. federal and state income tax rate for the nine months ended September 30, 2023 and 2022 was 19.7% and 18.4%, respectively. The effective tax rate for the three and nine months ended September 30, 2023 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 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 is vigorously defending this matter; however, given the current early stage of this matter, we cannot predict the outcome of this case at this time.

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.

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.

Maine. On February 9, 2023, Maine Commission 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. The Company is working with the Commission and believes this matter will not have a material impact on the Company.

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 is voluntarily working with the firm, however, if settlement is unsuccessful, the Attorney General could commence a lawsuit in Illinois against Spark Energy, LLC.

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, rule, 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 2020 to 2023 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 September 30, 2023 and December 31, 2022, we had accrued $4.1 million and $3.7 million, respectively, related to litigation and regulatory matters and $0.7 million and $0.2 million, respectively, related to indirect tax audits. 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 and pay an affiliate to perform telemarketing activities. 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 are recorded in the condensed consolidated balance sheets.

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


	September 30, 2023		December 31, 2022








Assets
Accounts Receivable - affiliates	$	4,569	$	6,455
Total Assets - affiliates	$	4,569	$	6,455


	September 30, 2023		December 31, 2022








Liabilities
Accounts Payable - affiliates	$	1,062	$	265
Subordinated Debt - affiliates (1)	—		20,000
Total Liabilities - affiliates	$	1,062	$	20,265

(1) The Subordinated Debt Facility allows us to draw advances in increments of no less than $1.0 million per advance up to the maximum principal amount of the Subordinated Debt Facility, subject to Retailco’s discretion. 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. See Note 9 "Debt" for a further description of terms and conditions of the Subordinated Debt Facility.

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 September 30,				Nine Months Ended September 30,
	2023		2022			2023		2022









Revenue NAO - affiliates	$	194	$	739		$	2,811	$	2,316
Less: Cost of Revenue NAO - affiliates	1		110			333		143

Net NAO - affiliates	$	193	$	629		$	2,478	$	2,173

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 $0.1 million for the three months ended September 30, 2023 and 2022, respectively. The total net amount direct billed and allocated to/(from) affiliates was $1.4 million and $1.7 million for the nine months ended September 30, 2023 and 2022, respectively. The Company would have incurred incremental costs of $0.4 million and $0.4 million for the three months ended September 30, 2023 and 2022, respectively, operating on a stand-alone basis. The Company would have incurred incremental costs of $1.2 million and $1.2 million for the nine months ended September 30, 2023 and 2022, respectively, operating on a stand-alone basis.

Distributions to and Contributions from Affiliates

During three months ended September 30, 2023 and 2022, Spark HoldCo made distributions to affiliates of our Founder of zero and $3.6 million, respectively, for the payments of quarterly distribution on their respective Spark HoldCo units. During the three months ended September 30, 2023 and 2022, Spark HoldCo also made distributions to these affiliates for gross-up distributions of $0.1 million and zero, respectively, in connection with distributions made between Spark HoldCo and Via Renewables, Inc. for payment of income taxes incurred by us.

During the nine months ended September 30, 2023 and 2022, Spark HoldCo made distributions to affiliates of our Founder of $3.6 million and $10.8 million, respectively, for the payments of quarterly distribution on their respective Spark HoldCo units. During the nine months ended September 30, 2023 and 2022, Spark HoldCo also made distributions to these affiliates for gross-up distributions of $0.7 million and $0.1 million, respectively, in connection with distributions made between Spark HoldCo and Via Renewables, Inc. for payment of income taxes incurred by us.

14. Segment Reporting

Our determination of reportable business segments considers the strategic operating units under which we make financial decisions, allocate resources and assess performance of our business. 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, and related services. The retail natural gas segment consists of natural gas sales to, and natural gas transportation and distribution for, residential and commercial customers. Corporate and other consists of expenses and assets of the retail electricity and natural gas segments that are managed at a consolidated level such as general and administrative expenses, wireless data and device programs, and asset optimization activities.

For the three months ended September 30, 2023 and 2022, we recorded asset optimization revenues of $2.9 million and $22.6 million and asset optimization cost of revenues of $3.8 million and $20.9 million, respectively, and for the nine months ended September 30, 2023 and 2022, we recorded asset optimization revenues of $17.3 million and $68.4 million and asset optimization cost of revenues of $22.9 million and $68.9 million, respectively, which are presented on a net basis in asset optimization revenues.

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 (losses) gains 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, gross profit, its most directly comparable financial measure calculated and presented in accordance with GAAP.

Below is a reconciliation of retail gross margin to gross profit (in thousands):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Reconciliation of Retail Gross Margin to Gross Profit






Total Revenue	$	110,239	$	118,859	$	333,490	$	343,112
Less:
Retail cost of revenues	71,050		102,212		234,417		232,621
Gross Profit	39,189		16,647		99,073		110,491
Less:
Net asset optimization (expense) revenue	(936)		1,672		(5,568)		(480)
Net, (loss) gain on non-trading derivative instruments	(6,193)		(1,413)		(49,002)		54,570
Net, Cash settlements on non-trading derivative instruments	14,430		(14,068)		50,699		(36,067)
Non-recurring event - Winter Storm Uri	—		—		—		9,565
Retail Gross Margin	$	31,888	$	30,456	$	102,944	$	82,903

Financial data for business segments are as follows (in thousands):


Three Months Ended September 30, 2023
	Retail Electricity (a)		Retail Natural Gas		Corporate and Other		Eliminations		Consolidated
Total revenues	$	97,855	$	11,898	$	486	$	—	$	110,239
Retail cost of revenues	64,575		5,790		685		—		71,050
Gross Profit	$	33,280	$	6,108	$	(199)	$	—	$	39,189
Less:
Net asset optimization expense	—		—		(936)		—		(936)
Net, loss on non-trading derivative instruments	(6,143)		(50)		—		—		(6,193)
Current period settlements on non-trading derivatives	13,432		998		—		—		14,430

Retail Gross Margin	$	25,991	$	5,160	$	737	$	—	$	31,888
Total Assets at September 30, 2023	$	2,052,268	$	164,076	$	299,577	$	(2,218,845)	$	297,076
Goodwill at September 30, 2023	$	117,813	$	2,530	$	—	$	—	$	120,343

(a) Retail Electricity includes related services.


Three Months Ended September 30, 2022
	Retail Electricity		Retail Natural Gas		Corporate and Other		Eliminations		Consolidated
Total revenues	$	104,970	$	12,217	$	1,672	$	—	$	118,859
Retail cost of revenues	92,816		9,396		—		—		102,212
Gross Profit	$	12,154	$	2,821	$	1,672	$	—	$	16,647
Less:
Net asset optimization revenue	—		—		1,672		—		1,672
Net, (loss) gain on non-trading derivative instruments	(5,290)		3,877		—		—		(1,413)
Current period settlements on non-trading derivatives	(11,063)		(3,005)		—		—		(14,068)
Non-recurring event - Winter Storm Uri	—		—		—		—		—
Retail Gross Margin	$	28,507	$	1,949	$	—	$	—	$	30,456
Total Assets at December 31, 2022	$	1,802,649	$	123,490	$	313,490	$	(1,908,679)	$	330,950
Goodwill at December 31, 2022	$	117,813	$	2,530	$	—	$	—	$	120,343


Nine Months Ended September 30, 2023
	Retail Electricity		Retail Natural Gas		Corporate and Other		Eliminations		Consolidated
Total revenues	$	255,447	$	82,052	$	(4,009)	$	—	$	333,490
Retail cost of revenues	183,017		50,664		736		—		234,417
Gross Profit	$	72,430	$	31,388	$	(4,745)	$	—	$	99,073
Less:
Net asset optimization expense	—		—		(5,568)		—		(5,568)
Net loss on non-trading derivatives	(41,984)		(7,018)		—		—		(49,002)
Current period settlements on non-trading derivatives	44,960		5,739		—		—		50,699

Retail Gross Margin	$	69,454	$	32,667	$	823	$	—	$	102,944
Total Assets at September 30, 2023	$	2,052,268	$	164,076	$	299,577	$	(2,218,845)	$	297,076
Goodwill at September 30, 2023	$	117,813	$	2,530	$	—	$	—	$	120,343


Nine Months Ended September 30, 2022
	Retail Electricity		Retail Natural Gas		Corporate and Other		Eliminations		Consolidated
Total revenues	$	275,301	$	68,291	$	(480)	$	—	$	343,112
Retail cost of revenues	189,092		43,529		—		—		232,621
Gross Profit	$	86,209	$	24,762	$	(480)	$	—	$	110,491
Less:
Net asset optimization expense	—		—		(480)		—		(480)
Net gain on non-trading derivatives	42,557		12,013		—		—		54,570
Current period settlements on non-trading derivatives	(28,317)		(7,750)		—		—		(36,067)
Non-recurring event - Winter Storm Uri	9,565		—		—		—		9,565
Retail Gross Margin	$	62,404	$	20,499	$	—	$	—	$	82,903
Total Assets at December 31, 2022	$	1,802,649	$	123,490	$	313,490	$	(1,908,679)	$	330,950
Goodwill at December 31, 2022	$	117,813	$	2,530	$	—	$	—	$	120,343

15. Customer Acquisitions

Acquisition of Customer Books

In August 2022, we entered into an agreement to acquire up to approximately 18,700 RCEs and derivatives related to the customer load under a five-year contingent fee structure based on gas volumes billed and collected for the acquired customer contracts. These customers began transferring in the fourth quarter of 2022 and are located in our existing markets. Due to the contingent fee structure, the cost of the RCEs will be recognized when probable and reasonably estimable.

Acquisition of Broker Books

In January 2022, we entered into an asset purchase agreement and agreed to acquire the rights to broker contracts for approximately 1,000 customer meters for a cash price of $0.4 million, which was paid upon execution of the contract.

In January 2022, we entered into an asset purchase agreement to acquire the rights to broker contracts for approximately 900 customer meters for a cash price of $0.6 million, pending certain conditions to close. We paid approximately $0.3 million as a deposit at the time the asset purchase agreement was executed. The conditions to close were met in June 2022, at which time approximately $0.3 million was paid to the seller.

16. Subsequent Events

On October 18, 2023, we declared a quarterly cash dividend in the amount of $0.76459 per share to holders of record of the Series A Preferred Stock on January 1, 2024. The dividend will be paid on January 16, 2024.

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 2022 Form 10-K filed with the Securities and Exchange Commission (“SEC”) on March 29, 2023. Results of operations and cash flows for the three and nine months ended September 30, 2023 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 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 natural gas and electricity supply from a variety of wholesale providers and bill our customers monthly for the delivery of natural gas and electricity based on their consumption at either a fixed or variable price. Natural gas and electricity are then distributed to our customers by local regulated utility companies through their existing infrastructure. As of September 30, 2023, we operated in 103 utility service territories across 20 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 September 30, 2023 and 2022, approximately 89% and 90%, 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 September 30, 2023 and 2022, approximately 11% and 10%, respectively, of our retail revenues were derived from the sale of natural gas.

Recent Developments

Dividend Actions

On April 19, 2023, we announced that our Board of Directors has elected to temporarily suspend the quarterly cash dividend on the Class A common stock in order for the Company to seek to enhance its financial flexibility and improve its ability to manage market volatility while focusing on strengthening its balance sheet and investing in both organic and inorganic customer growth.

We believe the decision to temporarily suspend the quarterly dividend on the Class A common stock provides near-term benefits to our cash flow management while allowing us to seek to enhance our balance sheet. We remain dedicated to prioritizing our shareholders’ interests and adhering to a company goal of distributing a meaningful portion of available cash through dividends on Class A common stock and Series A Preferred Stock. We will closely monitor market conditions and thoughtfully evaluate when and if to reinstate dividends on the Class A common stock.

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 nine months ended September 30, 2023:


RCEs:
(In thousands)	June 30, 2023	Additions	Attrition	September 30, 2023	% Increase (Decrease)
Retail Electricity	224	19	24	219	(2)%
Retail Natural Gas	122	5	9	118	(3)%
Total Retail	346	24	33	337	(3)%


RCEs:
(In thousands)	December 31, 2022	Additions	Attrition	September 30, 2023	% Increase (Decrease)
Retail Electricity	201	96	78	219	9%
Retail Natural Gas	130	15	27	118	(9)%
Total Retail	331	111	105	337	2%

The following table details our count of RCEs by geographical location as of September 30, 2023:


RCEs by Geographic Location:
(In thousands)	Electricity	% of Total	Natural Gas	% of Total	Total	% of Total
New England	61	28%	12	10%	73	22%
Mid-Atlantic	97	44%	52	44%	149	44%
Midwest	20	9%	20	17%	40	12%
Southwest	41	19%	34	29%	75	22%
Total	219	100%	118	100%	337	100%

The geographical locations noted above include the following states:

•New England - Connecticut, Maine, Massachusetts and New Hampshire;

•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 Acquisition

Customer acquisition 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.

Our organic sales strategies are designed to offer competitive pricing, price certainty, and/or green product offerings to residential and commercial customers. We manage growth on a market-by-market basis by developing price curves in each of the markets we serve and comparing the market prices to the price offered by the local regulated utility. We then determine if there is an opportunity in a particular market based on our ability to create a competitive product on economic terms that provides customer value and satisfies our profitability objectives. We develop marketing campaigns using a combination of sales channels. Our marketing team continuously evaluates the effectiveness of each customer acquisition channel and makes adjustments in order to achieve desired targets.

During the three months ended September 30, 2023, we added approximately 24,000 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.

During the three months ended September 30, 2023, we did not add any RCEs as a result of asset purchase agreements. Our ability to realize returns from acquisitions that are acceptable to us is dependent on our ability to successfully identify, negotiate, finance and integrate acquisitions. We will continue to evaluate potential acquisitions during the remainder of 2023.

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.

We strive to maintain a disciplined approach to recovery of our customer acquisition costs within a 12-month period. We capitalize and amortize our customer acquisition costs over a two-year period, which is based on our estimate of the expected average length of a customer relationship. We factor in the recovery of customer acquisition costs in determining which markets we enter and the pricing of our products in those markets. Accordingly, our results are significantly influenced by our customer acquisition costs. Changes in customer acquisition costs from period to period reflect our focus on growing organically versus growth through acquisitions. We are currently focused on growing through organic sales channels; however, we continue to evaluate opportunities to acquire customers through acquisitions and pursue such acquisitions when it makes sense economically or strategically.

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 September 30, 2023 and 2022 was 3.1% and 4.0%, respectively. Our customer attrition was slightly lower than the prior year due to the decrease in commodity prices across the industry in 2023, compared to 2022.

Customer Credit Risk

Our credit loss expense for the three months ended September 30, 2023 and 2022 was 1.3% and 1.8%, respectively, and our credit loss expense for the nine months ended September 30, 2023 and 2022 was 1.8% and 1.9% respectively, for non-purchase of receivable market ("non-POR") revenues. As the Company has increased sales

activities in non-POR markets in 2023 and focused on collection efforts, we have experienced a decrease in credit loss expense during the three and nine months ended September 30, 2023.

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 $0.9 million and a gain of $1.7 million for the three months ended September 30, 2023 and 2022, 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 September 30,				Nine Months Ended September 30,
(in thousands)	2023		2022		2023		2022
Adjusted EBITDA (1)	$	12,756	$	15,063	$	43,580	$	39,197
Retail Gross Margin (2)	$	31,888	$	30,456	$	102,944	$	82,903

(1) Adjusted EBITDA for the nine months ended September 30, 2022 includes a deduction of $5.2 million related to proceeds received under an ERCOT (Winter Storm Uri) securitization mechanism in June 2022. See further discussion below.

(2) Retail Gross Margin for the nine months ended September 30, 2022 includes a deduction of $9.6 million related to proceeds received under an ERCOT (Winter Storm Uri) securitization mechanism in June 2022. See further discussion below.

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 will continue this historical approach, but during the first quarter of 2021 we incurred a net pre-tax financial loss of $64.9 million due to Winter Storm Uri, as described above. This loss was incurred due to uncharacteristic extended sub-freezing temperatures across Texas combined with the impact of the pricing caps ordered by ERCOT. We believe this event is unusual, infrequent, and non-recurring in nature.

As our Senior Credit Facility is considered a material agreement and Adjusted EBITDA is a key component of our material covenants, we consider our covenant compliance to be material to the understanding of our financial condition and/or liquidity. Our lenders under our Senior Credit Facility allowed $60.0 million of the $64.9 million pre-tax storm loss incurred in the first quarter of 2021 to be added back as a non-recurring item in the calculation of Adjusted EBITDA for our Debt Covenant Calculations. We received a $0.4 million credit from ERCOT for winter storm related losses during the third quarter of 2021, resulting in a net pre-tax storm loss of $64.4 million for the year ended December 31, 2021. In June 2022, we received $9.6 million from ERCOT related to PURA Subchapter N Securitization financing. For consistent presentation of the financial impact of Winter Storm Uri, $5.2 million of the $9.6 million is reflected as non-recurring items reducing Adjusted EBITDA for the nine months ended September 30, 2022.

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, historical cost basis and specific items not reflective of ongoing operations;

•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, Maximum Total Leverage Ratio, and Maximum Senior Secured 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 September 30,				Nine Months Ended September 30,
(in thousands)	2023		2022		2023		2022
Reconciliation of Adjusted EBITDA to net income (loss):
Net income (loss)	$	14,659	$	(4,868)	$	26,974	$	38,691
Depreciation and amortization	1,816		3,270		7,146		13,390
Interest expense	2,233		2,002		7,377		5,129
Income tax expense (benefit)	3,355		(48)		6,599		8,726
EBITDA	22,063		356		48,096		65,936
Less:
Net, (loss) gain on derivative instruments	(6,991)		(1,645)		(50,428)		55,815
Net cash settlements on derivative instruments	15,100		(14,078)		51,767		(35,922)
Customer acquisition costs	1,698		1,684		4,961		4,274
Plus:
Non-cash compensation expense	500		668		1,784		2,590
Non-recurring event - Winter Storm Uri	—		—		—		(5,162)

Adjusted EBITDA	$	12,756	$	15,063	$	43,580	$	39,197

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 September 30,				Nine Months Ended September 30,
(in thousands)	2023		2022		2023		2022
Reconciliation of Adjusted EBITDA to net cash provided by operating activities:
Net cash provided by operating activities	$	6,161	$	8,267	$	40,857	$	21,211
Amortization of deferred financing costs	(206)		(206)		(619)		(919)
Bad debt expense	(829)		(1,062)		(2,717)		(2,895)
Interest expense	2,233		2,002		7,377		5,129
Income tax expense (benefit)	3,355		(48)		6,599		8,726
Non-recurring event - Winter Storm Uri	—		—		—		(5,162)


Changes in operating working capital
Accounts receivable, prepaids, current assets	6,609		2,144		(31,254)		(7,229)
Inventory	1,104		2,883		(1,378)		3,292
Accounts payable and accrued liabilities	(3,432)		508		28,801		21,306
Other	(2,239)		575		(4,086)		(4,262)
Adjusted EBITDA	$	12,756	$	15,063	$	43,580	$	39,197
Cash Flow Data:
Net cash provided by operating activities	$	6,161	$	8,267	$	40,857	$	21,211
Net cash used in investing activities	$	(369)	$	(1,240)	$	(1,144)	$	(6,400)
Net cash used in financing activities	$	(7,714)	$	(10,199)	$	(29,927)	$	(47,780)

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.

We have historically included the financial impact of weather variability in the calculation of Retail Gross Margin. We will continue this historical approach, but during the first quarter of 2021 we added back the $64.9 million net financial loss incurred related to Winter Storm Uri, as described above, in the calculation of Retail Gross Margin because the extremity of the Texas storm combined with the impact of unprecedented pricing mechanisms ordered by ERCOT is considered unusual, infrequent, and non-recurring in nature. In June 2022, we received $9.6 million from ERCOT related to PURA Subchapter N Securitization financing. The $9.6 million is reflected as a non-recurring item reducing Retail Gross Margin for the nine months ended September 30, 2022 for consistent presentation of the financial impacts of Winter Storm Uri.

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 September 30,				Nine Months Ended September 30,
(in thousands)	2023		2022		2023		2022
Reconciliation of Retail Gross Margin to Gross Profit




Total Revenue	$	110,239	$	118,859	$	333,490	$	343,112
Less:
Retail cost of revenues	71,050		102,212		234,417		232,621
Gross Profit	39,189		16,647		99,073		110,491
Less:
Net asset optimization (expense) revenue	(936)		1,672		(5,568)		(480)
(Loss) gain on non-trading derivative instruments	(6,193)		(1,413)		(49,002)		54,570
Cash settlements on non-trading derivative instruments	14,430		(14,068)		50,699		(36,067)
Non-recurring event - Winter Storm Uri	—		—		—		9,565
Retail Gross Margin	$	31,888	$	30,456	$	102,944	$	82,903
Retail Gross Margin - Retail Electricity Segment (1)	$	25,991	$	28,507	$	69,454	$	62,404
Retail Gross Margin - Retail Natural Gas Segment	$	5,160	$	1,949	$	32,667	$	20,499
Retail Gross Margin - Other	$	737	$	—	$	823	$	—

(1) Retail Gross Margin for the nine months ended September 30, 2022 includes a deduction of $9.6 million related to proceeds received under an ERCOT (Winter Storm Uri) securitization mechanism in June 2022. See further discussion above.

Our non-GAAP financial measures of Adjusted EBITDA and Retail Gross Margin should not be considered as alternatives to net income (loss), net cash provided by (used in) operating activities, or 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 net income (loss), net cash provided by (used in) operating activities, and 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 September 30, 2023 Compared to Three Months Ended September 30, 2022


(In Thousands)	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
Revenues:
Retail revenues	$	109,753		$	117,187		$	337,499		$	343,592
Net asset optimization (expense) revenue	(936)			1,672			(5,568)			(480)
Other revenue	1,422			—			1,559			—
Total Revenues	110,239			118,859			333,490			343,112
Operating Expenses:
Retail cost of revenues	71,050			102,212			234,417			232,621
General and administrative expense	17,135			16,302			51,073			44,820
Depreciation and amortization	1,816			3,270			7,146			13,390
Total Operating Expenses	90,001			121,784			292,636			290,831
Operating income (loss)	20,238			(2,925)			40,854			52,281
Other (expense)/income:
Interest expense	(2,233)			(2,002)			(7,377)			(5,129)
Interest and other income	9			11			96			265
Total other expense	(2,224)			(1,991)			(7,281)			(4,864)
Income (loss) before income tax expense	18,014			(4,916)			33,573			47,417
Income tax expense (benefit)	3,355			(48)			6,599			8,726
Net income (loss)	$	14,659		$	(4,868)		$	26,974		$	38,691
Other Performance Metrics:
Adjusted EBITDA (1) (2)	$	12,756		$	15,063		$	43,580		$	39,197
Retail Gross Margin (1) (3)	$	31,888		$	30,456		$	102,944		$	82,903
Customer Acquisition Costs	$	1,698		$	1,684		$	4,961		$	4,274
Average Monthly RCE Attrition	3.1		%	4.0		%	3.4		%	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 nine ended September 30, 2022 includes a deduction of $5.2 million non-recurring credit related to Winter Storm Uri add back in 2021.

(3) Retail Gross Margin for the nine ended September 30, 2022 includes a deduction of $9.6 million non-recurring credit related to Winter Storm Uri add back in 2021.

Three Months Ended September 30, 2023 Compared to Three Months Ended September 30, 2022

Total Revenues. Total revenues for the three months ended September 30, 2023 were approximately $110.2 million, a decrease of approximately $8.7 million, or 7%, from approximately $118.9 million for the three months ended September 30, 2022, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity volumes sold as a result of a smaller electricity customer book, which was offset by higher electricity unit revenue per MWh as a result of increased electricity rates in the third quarter of 2023 as compared to the third quarter of 2022.


Change in electricity volumes sold	$	(10.1)
Change in natural gas volumes sold	2.6
Change in electricity unit revenue per MWh	2.9

Change in natural gas unit revenue per MMBtu	(2.9)
Change in other revenue	1.4
Change in net asset optimization expense	(2.6)
Change in total revenues	$	(8.7)

Retail Cost of Revenues. Total retail cost of revenues for the three months ended September 30, 2023 was approximately $71.1 million, a decrease of approximately $31.1 million, or 30%, from approximately $102.2 million for the three months ended September 30, 2022, as indicated in the table below (in millions). This decrease was primarily due to a change in value of our retail derivative portfolio, and a decrease in electricity volumes sold in the third quarter of 2023 as a result of smaller electricity customer book as compared to the third quarter of 2022.


Change in electricity volumes sold	$	(7.3)
Change in natural gas volumes sold	2.2
Change in electricity unit cost per MWh	2.7

Change in natural gas unit cost per MMBtu	(5.7)
Change in other costs	0.7
Change in value of retail derivative portfolio	(23.7)
Change in retail cost of revenues	$	(31.1)

General and Administrative Expense. General and administrative expense for the three months ended September 30, 2023 was approximately $17.1 million, an increase of approximately $0.8 million, or 5%, as compared to $16.3 million for the three months ended September 30, 2022. This increase was primarily attributable to higher employee costs and an increase in sales and marketing due to increased sales activity.

Depreciation and Amortization Expense. Depreciation and amortization expense for the three months ended September 30, 2023 was approximately $1.8 million, a decrease of approximately $1.5 million, or 45%, from approximately $3.3 million for the three months ended September 30, 2022. This decrease was primarily due to the decreased amortization expense associated with customer intangibles.

Customer Acquisition Cost. Customer acquisition cost for the three months ended September 30, 2023 was approximately $1.7 million, consistent with approximately $1.7 million for the three months ended September 30, 2022 primarily due to an increase in the sales activity and a decrease in the cost to acquire a customer in the third quarter of 2023 as compared to third quarter of 2022.

Nine months ended September 30, 2023 Compared to Nine months ended September 30, 2022

Total Revenues. Total revenues for the nine months ended September 30, 2023 were approximately $333.5 million, a decrease of approximately $9.6 million, or 3%, from approximately $343.1 million for the nine months ended September 30, 2022, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity volumes sold as a result of smaller electricity customer book. The decrease was offset by higher electricity unit revenue per MWh and higher natural gas unit revenue per MMBtu, as a result of increased electricity and natural gas rates in the first nine months of 2023 as compared to the first nine months of 2022.


Change in electricity volumes sold	$	(61.3)
Change in natural gas volumes sold	2.3
Change in electricity unit revenue per MWh	41.4

Change in natural gas unit revenue per MMBtu	11.5
Change in other revenue	1.6
Change in net asset optimization expense	(5.1)
Change in total revenues	$	(9.6)

Retail Cost of Revenues. Total retail cost of revenues for the nine months ended September 30, 2023 was approximately $234.4 million, an increase of approximately $1.8 million, or 1%, from approximately $232.6 million for the nine months ended September 30, 2022, as indicated in the table below (in millions). This increase was primarily due to a change in the value of our retail derivative portfolio and higher electricity costs. The increase was offset by a decrease in electricity volumes sold as a result of a smaller electricity customer book.


Change in electricity volumes sold	$	(47.4)
Change in natural gas volumes sold	1.6
Change in electricity unit cost per MWh	20.5
Change in electricity unit cost per MWh - Winter Storm Uri	9.6
Change in natural gas unit cost per MMBtu	—
Change in other costs	0.7
Change in value of retail derivative portfolio	16.8
Change in retail cost of revenues	$	1.8

General and Administrative Expense. General and administrative expense for the nine months ended September 30, 2023 was approximately $51.1 million, an increase of approximately $6.3 million, or 14%, as compared to $44.8 million for the nine months ended September 30, 2022. This increase was primarily attributable to higher employee costs and an increase in sales and marketing due to increased sales activity.

Depreciation and Amortization Expense. Depreciation and amortization expense for the nine months ended September 30, 2023 was approximately $7.1 million, a decrease of approximately $6.3 million, or 47%, from approximately $13.4 million for the nine months ended September 30, 2022. This decrease was primarily due to the decreased amortization expense associated with customer relationship intangibles.

Customer Acquisition Cost. Customer acquisition cost for the nine months ended September 30, 2023 was approximately $5.0 million, an increase of approximately $0.7 million, or 16%, from approximately $4.3 million for the nine months ended September 30, 2022. This increase was primarily due to increased sales activity in the first nine months of 2023 as compared to first nine months of 2022.

Operating Segment Results


(in thousands, except volume and per unit operating data)	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022

Retail Electricity Segment
Total Revenues	$	97,855	$	104,970	$	255,447	$	275,301
Retail Cost of Revenues	64,575		92,816		183,017		189,092

Less: Net gain (loss) on non-trading derivatives, net of cash settlements	7,289		(16,353)		2,976		14,240
Non-recurring event - Winter Storm Uri	—		—		—		9,565
Retail Gross Margin (1) — Electricity	$	25,991	$	28,507	$	69,454	$	62,404
Volumes — Electricity (MWhs)	627,851		694,035		1,541,182		1,982,684
Retail Gross Margin (2) — Electricity per MWh	$	41.40	$	41.07	$	45.07	$	31.47

Retail Natural Gas Segment
Total Revenues	$	11,898	$	12,217	$	82,052	$	68,291
Retail Cost of Revenues	5,790		9,396		50,664		43,529

Less: Net gain (loss) on non-trading derivatives, net of cash settlements	948		872		(1,279)		4,263
Retail Gross Margin (1) — Gas	$	5,160	$	1,949	$	32,667	$	20,499
Volumes — Gas (MMBtus)	1,419,291		1,170,857		8,031,902		7,771,468
Retail Gross Margin (2) — Gas per MMBtu	$	3.64	$	1.67	$	4.07	$	2.64

(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 September 30, 2023 Compared to Three Months Ended September 30, 2022

Retail Electricity Segment

Total revenues for the Retail Electricity Segment for the three months ended September 30, 2023 were approximately $97.8 million, a decrease of approximately $7.2 million, or 7%, from approximately $105.0 million for the three months ended September 30, 2022. This decrease was largely due to a decrease in electricity volumes of $10.1 million, which was partially offset by $2.9 million due to higher retail electricity prices.

Retail cost of revenues for the Retail Electricity Segment for the three months ended September 30, 2023 were approximately $64.6 million, a decrease of approximately $28.2 million, or 30%, from approximately $92.8 million for the three months ended September 30, 2022. This decrease was primarily due to a change in the fair value of our retail derivative portfolio used for hedging, which resulted in a decrease of $23.6 million and lower volumes due to a smaller customer book, resulting in a decrease of $7.3 million. The decrease was offset by an increase in electricity prices, resulting in an increase of $2.7 million.

Retail gross margin for the Retail Electricity Segment for the three months ended September 30, 2023 was approximately $26.0 million, a decrease of approximately $2.5 million, or 9%, from approximately $28.5 million for the three months ended September 30, 2022, as indicated in the table below (in millions).


Change in volumes sold	$	(2.7)

Change in unit margin per MWh	0.2

Change in retail electricity segment retail gross margin	$	(2.5)

Retail Natural Gas Segment

Total revenues for the Retail Natural Gas Segment for the three months ended September 30, 2023 were approximately $11.9 million, a decrease of approximately $0.3 million, or 3%, from approximately $12.2 million for the three months ended September 30, 2022. This decrease was attributable to lower natural gas prices, which decreased total revenues by $2.9 million and offset by increase in natural gas volumes of $2.6 million.

Retail cost of revenues for the Retail Natural Gas Segment for the three months ended September 30, 2023 were approximately $5.8 million, a decrease of $3.6 million, or 38%, from approximately $9.4 million for the three months ended September 30, 2022. This decrease was primarily due to lower natural gas costs, which resulted in a decrease of $5.7 million. The decrease was offset by an increase in volumes sold resulting in an increase of $2.2 million.

Retail gross margin for the Retail Natural Gas Segment for the three months ended September 30, 2023 was approximately $5.2 million, an increase of approximately $3.3 million, or 174%, from approximately $1.9 million for the three months ended September 30, 2022, as indicated in the table below (in millions).


Change in volumes sold	$	0.5
Change in unit margin per MMBtu	2.8
Change in retail natural gas segment retail gross margin	$	3.3

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Retail Electricity Segment

Total revenues for the Retail Electricity Segment for the nine months ended September 30, 2023 were approximately $255.4 million, a decrease of approximately $19.9 million, or 7%, from approximately $275.3 million for the nine months ended September 30, 2022. This decrease was largely due to lower volumes, resulting in a decrease of $61.3 million. This decrease was partially offset by higher electricity prices, resulting in an increase of $41.4 million.

Retail cost of revenues for the Retail Electricity Segment for the nine months ended September 30, 2023 was approximately $183.0 million, a decrease of approximately $6.1 million, or 3%, from approximately $189.1 million for the nine months ended September 30, 2022. This decrease was primarily due to a decrease in electricity volumes sold resulting in a decrease of $47.4 million. The decrease was offset by an increase in electricity costs of $20.5 million due to higher commodity price environment in 2023, a change in the value of our derivative portfolio used for hedging resulting in an increase of $11.2 million, and a credit of $9.6 million related to Winter Storm Uri received in 2022 from ERCOT.

Retail gross margin for the Retail Electricity Segment for the nine months ended September 30, 2023 was approximately $69.5 million, an increase of approximately $7.1 million, or 11%, from approximately $62.4 million for the nine months ended September 30, 2022, as indicated in the table below (in millions).


Change in volumes sold	$	(13.9)

Change in unit margin per MWh	21.0
Change in retail electricity segment retail gross margin	$	7.1

Retail Natural Gas Segment

Total revenues for the Retail Natural Gas Segment for the nine months ended September 30, 2023 were approximately $82.1 million, an increase of approximately $13.8 million, or 20%, from approximately $68.3 million for the nine months ended September 30, 2022. This increase was attributable to higher rates, which resulted in an increase in total revenues of $11.5 million and an increase in volumes as a result of a higher natural gas customer book resulting in an increase of $2.3 million.

Retail cost of revenues for the Retail Natural Gas Segment for the nine months ended September 30, 2023 was approximately $50.7 million, an increase of approximately $7.2 million, or 17%, from approximately $43.5 million for the nine months ended September 30, 2022. The increase was primarily attributable to a change in the value of our derivative portfolio used for hedging, which resulted in an increase of $5.6 million and an increase in volumes sold resulting in an increase of $1.6 million.

Retail gross margin for the Retail Natural Gas Segment for the nine months ended September 30, 2023 was approximately $32.7 million, an increase of approximately $12.2 million, or 60%, from approximately $20.5 million for the nine months ended September 30, 2022, as indicated in the table below (in millions).


Change in volumes sold	$	0.8
Change in unit margin per MMBtu	11.4
Change in retail natural gas segment retail gross margin	$	12.2

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.

We have historically paid dividends on our Class A common stock and Series A Preferred Stock. On April 19, 2023, we announced that our Board of Directors has elected to temporarily suspend the quarterly cash dividend on the Class A common stock. We may continue to use cash to pay dividends on the Series A Preferred Stock, and it may also be used to pay dividends on the Class A common stock if the Board of Directors reinstates the dividends on the Class A common stock.

Our liquidity requirements fluctuate with our customer count, 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 and to reinstate dividends on our Class A common stock 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 September 30, 2023:


($ in thousands)	September 30, 2023
Cash and cash equivalents	$	45,137
Senior Credit Facility Availability (1)	28,706

Subordinated Debt Facility Availability (2)	25,000
Total Liquidity	$	98,843

(1) Reflects amount of Letters of Credit that could be issued based on existing covenants as of September 30, 2023.

(2) The availability of the Subordinated Facility is dependent on our Founder's discretion. 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):


	Nine Months Ended September 30,
	2023		2022
Net cash provided by operating activities	$	40,857	$	21,211
Net cash used in investing activities	$	(1,144)	$	(6,400)
Net cash used in financing activities	$	(29,927)	$	(47,780)

Nine Months Ended September 30, 2023 Compared to the Nine Months Ended September 30, 2022

Cash Flows Provided by Operating Activities. Cash flows provided by operating activities for the nine months ended September 30, 2023 increased by $19.6 million compared to the nine months ended September 30, 2022. The increase was primarily the result of changes in working capital for the nine months ended September 30, 2023.

Cash Flows Used in Investing Activities. Cash flows used in investing activities decreased by $5.3 million for the nine months ended September 30, 2023. The decrease was primarily the result of customer acquisitions during the nine months ended September 30, 2022 that did not re-occur in 2023.

Cash Flows Used in Financing Activities. Cash flows used in financing activities decreased by $17.9 million for the nine months ended September 30, 2023, primarily due to an increase in net borrowings of our Senior Credit Facility of $47.0 million, decrease in dividends paid to Class A common stockholders of $5.7 million, decrease in distributions to non-controlling unitholders of $6.6 million, which was offset by a decrease in sub-debt borrowing of $40.0 million during the nine months ended September 30, 2023.

Sources of Liquidity and Capital Resources

Senior Credit Facility

On June 30, 2022, we entered into the Senior Credit Facility with 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, which replaced our prior credit agreement. The Senior Credit Facility allows us to borrow up to $195.0 million on a revolving basis in the form of working capital loans, loans to fund acquisitions, swingline loans and letters of credit. The Senior Credit Facility expires on June 30, 2025. The Senior Credit Facility revised the Fixed Charge Coverage Ratio and Maximum Senior Secured Leverage Ratio under our prior credit agreement.

As of September 30, 2023, we had total commitments of $195.0 million under the Senior Credit Facility, of which $134.0 million was outstanding, including $29.0 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 September 30, 2023, we were in compliance with the covenants under our Senior Credit Facility. Based upon existing covenants as of September 30, 2023, we had availability to borrow up to $28.7 million under the Senior Credit Facility.

The Company has experienced compressed gross profit due to an extreme elevation of commodity costs during 2022, impacting calculated Adjusted EBITDA, a primary component of the financial covenants described above. The Company is actively working to manage the impact of gross profit compression due to market volatility on financial covenant compliance. Maintaining compliance with our covenants under our Senior Credit Facility may impact our ability to pay dividends.

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, 2026. 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.

Although we may use the Subordinated Debt Facility from time to time to enhance short term liquidity, we do not view the Subordinated Debt Facility as a material source of liquidity. As of September 30, 2023, there was zero outstanding borrowings under the Subordinated Debt Facility, and availability to borrow up to $25.0 million under the Subordinated Debt Facility. 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 2025, and thus, 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 September 30, 2023 was $105.0 million. The current variable interest rate on the facility at September 30, 2023 was 8.81%.

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 September 30, 2023 and 2022, we spent a total of $1.7 million and $1.7 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 nine months ended September 30, 2023 and 2022 included $1.1 million and $1.9 million, respectively, related to information systems improvements.

Dividends and Distributions

During the three and nine months ended September 30, 2023, we paid zero and $2.9 million in dividends to holders of our Class A common stock. In order to pay dividends to holders of our Class A common stock, our subsidiary, Spark HoldCo is required to make corresponding distributions to holders of Class B common stock (our non-controlling interest holders). As a result, during the three and nine months ended September 30, 2023, Spark HoldCo made distributions of zero and $3.6 million to our non-controlling interest holders related to the dividend payments to holders of our Class A common stock.

During the three and nine months ended September 30, 2023, we paid $2.6 million and $7.6 million in dividends to holders of the Series A Preferred Stock. As of September 30, 2023, we had accrued $2.7 million related to dividends to holders of the Series A Preferred Stock. This dividend was paid on October 16, 2023. The Series A Preferred Stock will accrue dividends 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. 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.

For the full year ended December 31, 2023, 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 $10.4 million in the aggregate based on the Series A Preferred Stock outstanding as of September 30, 2023.

On October 18, 2023, we declared a dividend in the amount of $0.76459 per share for the Series A Preferred Stock for the third quarter of 2023. Dividends on Series A Preferred Stock will be paid on January 16, 2024 to holders of record on January 1, 2024. The Board of Directors may be required to reduce, eliminate or suspend quarterly cash dividends to the holders of the Series A Preferred Stock.

In April, 2023, we announced that our Board of Directors elected to temporarily suspend the quarterly cash dividend on the Class A common stock.

Future dividends are within the discretion of our Board of Directors, and 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.

Even if we are permitted to pay dividends on the Series A Preferred Stock or could re-instate the dividends on the Class A common stock, our Board of Directors may elect to reduce, eliminate or suspend the dividends on the Series A Preferred Stock, or not reinstate dividends on the Class A common stock, in order to maintain cash balances for operations or for other reasons. 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 September 30, 2023, 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 2022 Form 10-K. There have been no changes to these policies and estimates since the date of our 2022 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. Except as described in Note 12 "Commitments and Contingencies" to Part I, Item 1 of this Report, as of September 30, 2023, management did not believe that any of our outstanding lawsuits, administrative proceedings or investigations could result in a material adverse effect. 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 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 gain/(loss) on our non-trading derivative instruments, net of cash settlements, was $8.2 million and $(15.5) million for three months ended September 30, 2023 and 2022, respectively and $1.7 million and $18.5 million for the nine months ended September 30, 2023 and 2022, 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 2022 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 September 30, 2023, our Gas Non-Trading Fixed Price Open Position (hedges net of retail load) was a short position of 105,135 MMBtu. An increase of 10% in the market prices (NYMEX) from their September 30, 2023 levels would have increased 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 September 30, 2023 levels would have decreased the fair market value of our non-trading energy derivatives by $0.1 million. As of September 30, 2023, our Electricity Non-Trading Fixed Price Open Position (hedges net of retail load) was a short position of 305,058 MWhs. An increase of 10% in the forward market prices from their September 30, 2023 levels would have decreased the fair market value of our net non-trading energy portfolio by $1.8 million. Likewise, a decrease of 10% in the forward market prices from their September 30, 2023 levels would have increased the fair market value of our non-trading energy derivatives by $1.8 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. These POR programs result in substantially all of our credit risk being with the utility and not with our end-use customers in these territories. Approximately 54% 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 September 30, 2023 and 2022, respectively, and 54% and 60% for the nine months ended September 30, 2023 and 2022, respectively, all of which had investment grade ratings as of such date. We paid these local regulated utilities a weighted average discount of 1.0% and 0.9%, for the

three months ended September 30, 2023 and 2022, respectively, and 1.0% and 0.9% for the nine months ended September 30, 2023 and 2022, 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 as 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 September 30, 2023 and 2022 was 1.3% and 1.8% of non-POR market retail revenues, respectively and our bad debt expense for the nine months ended September 30, 2023 and 2022 was 1.8% and 1.9% 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 nine months ended September 30, 2023.

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 September 30, 2023, approximately $0.8 million of our total exposure of $0.9 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 September 30, 2023.

Interest Rate Risk

We are exposed to fluctuations in interest rates under our variable-price debt obligations, including our Senior Credit Facility and our Series A Preferred Stock.

At September 30, 2023, we were co-borrowers under the Senior Credit Facility, under which $105.0 million of variable rate indebtedness was outstanding. Based on the average amount of our variable rate indebtedness outstanding during the three months ended September 30, 2023, a 1.0% increase in interest rates would have resulted in additional annual interest expense of approximately $1.1 million.

On and after April 15, 2022, our Series A Preferred Stock accrue dividends 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. 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. On October 18, 2023, our Board of Directors declared a quarterly cash dividend in the amount of $0.76459 per share for the Series A Preferred Stock for the third quarter of 2023 for an aggregate amount of $2.7 million for the quarter. Based on the Series A Preferred Stock outstanding on September 30, 2023, a 1.0% increase in interest rates would have resulted in additional dividends of less than $0.1 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. Based on this evaluation, management concluded that as a result of the material weakness in our internal control over financial reporting, more described below, our disclosure controls and procedures were not effective as of September 30, 2023.

However, the Company concluded that the existence of this material weakness did not result in material misstatement of the Company’s financial statements included in this Quarterly Report.

In connection with the audit of our financial statements for the year ended December 31, 2022, we identified a material weakness in the design and operation of the controls over our calculation of income tax expense, deferred tax assets and liabilities. A material weakness is defined as a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis. Although this material weakness did not result in a material misstatement to our consolidated financial statements for the year ended December 31, 2022 or any prior period, it did result in immaterial corrections for the years ended December 31, 2021 and 2020, as disclosed the Company’s December 31, 2022 Annual Report.

If unremediated, this material weakness could result in a material misstatement for annual or interim consolidated financial statements for future periods.

With oversight from the Audit Committee of the Board of Directors, we intend to take the necessary steps to remediate the material weakness by enhancing our internal controls to ensure proper review by and communication between our internal and external tax advisors and internal accounting personnel. Our efforts will consist primarily of strengthening our tax organization through continuing education and refining controls related to components of our tax process to enhance our management review controls over taxes. As part of the key remediation actions, we will:

•Review our tax accounting processes and controls and enhance the overall design and procedures performed to ensure changes in the Company’s interest in HoldCo are appropriately identified and recorded:

•Re-design our management review controls and enhance the precision of review of attributes of the Company's deferred tax assets and liabilities, income tax expense; and

•Evaluate the sufficiency of our tax resources and personnel to determine whether additional resources, including tax advisors, are needed.

The material weakness will not be considered remediated until the applicable remedial controls operate for a sufficient period of time and management has concluded, through testing, that these controls are operating effectively.

Changes in Internal Control over Financial Reporting

Except as noted above, 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 September 30, 2023 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.

Security holders and potential investors in our securities should carefully consider the risk factors under "Item 1A— Risk Factors" in our 2022 Form 10-K. Except as described below, there has been no material change in our risk factors from those described in the 2022 Form 10-K. Our description of risks are not the sole risks for investors. 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.

The price of our Class A common stock and Series A Preferred Stock has been and may continue to be volatile.

The market price of our Class A common stock and Series A Preferred Stock may be highly volatile and may fluctuate substantially as a result of a number of factors. The following factors could affect our stock price:

•the impact of our reverse stock split on our common stock;

•the announcement of the elimination, suspension, reduction or reinstatement of dividends on Class A common stock and Series A Preferred Stock;

•the public reaction to our press releases, our other public announcements and our filings with the SEC;

•trading volumes of the Class A common stock and Series A Preferred Stock;

•prevailing interest rates;

•the market for similar securities;

•general economic and financial market conditions;

•our issuance of debt or other preferred equity securities; and

•our financial condition, results of operations and prospects.

These and other factors may cause the market price and demand for our Class A common stock and Series A Preferred Stock to fluctuate substantially, which may adversely affect the trading price of our Class A common stock and Series A Preferred Stock. In the past, when the market price of a stock has been volatile, holders of that stock have often instituted securities class action litigation against the company that issued the stock. If any of our stockholders brought a lawsuit against us, we could incur substantial defense costs. Such a lawsuit could also divert the time and attention of our management from our business. Trading prices and corresponding market value of Class A common stock and Series A Preferred Stock may also impact our ability to satisfy continued listing standards of The Nasdaq Global Select Market, or a particular tier of The Nasdaq exchanges.

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

3.1

Amended and Restated Certificate of Incorporation of Via Renewables, Inc., as amended through August 6, 2021

10-Q

3.1

11/4/2021

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

3/14/2017

001-36559

4.2

Class A Common Stock Certificate

S-1

4.1

6/30/2014

333-196375

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

# 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

† Management contract, or compensatory plan or arrangement

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.

November 2, 2023

/s/ Mike Barajas

Mike Barajas

Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)