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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, 2021
 
☐         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)

Spark Energy, Inc.
(Former name, if changed since last report)

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 15,572,388 shares of Class A common stock, 20,000,000 shares of Class B common stock and 3,567,543 shares of Series A Preferred Stock outstanding as of November 2, 2021.


VIA RENEWABLES, INC.
INDEX TO QUARTERLY REPORT ON FORM 10-Q
For the Quarter Ended September 30, 2021
Page No.
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
CONDENSED CONSOLIDATED BALANCE SHEETS AS OF SEPTEMBER 30, 2021 AND DECEMBER 31, 2020 (unaudited)
4
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2021 AND 2020 (unaudited)
5
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY FOR THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2021 AND 2020 (unaudited)
6
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2021 AND 2020 (unaudited)
10
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited)
12
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
39
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
58
ITEM 4. CONTROLS AND PROCEDURES
60
PART II. OTHER INFORMATION
61
ITEM 1. LEGAL PROCEEDINGS
61
ITEM 1A. RISK FACTORS
61
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
61
ITEM 6. EXHIBITS
64
SIGNATURES
66

1
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 COVID-19 and the 2021 severe weather event, cash flow generation and liquidity, business strategy, prospects for growth and acquisitions, outcomes of legal proceedings, ability to pay cash dividends, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans, objectives, beliefs of management, availability and terms of capital, competition, governmental 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:
•evolving risks, uncertainties and impacts relating to COVID-19, including the geographic spread, the severity of the disease, the scope and duration of the COVID-19 outbreak, actions that may be taken by governmental authorities to contain the COVID-19 outbreak or to treat its impact, and the potential for continuing negative impacts of COVID-19 on economies and financial markets;
•the ultimate impact of the 2021 severe weather event, including resolution of outstanding pricing and volume settlement data from ERCOT; the results of formal disputes regarding pricing and volume settlement data received to date; 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 sufficiency of risk management and hedging policies and practices;
•the impact of extreme and unpredictable weather conditions, including hurricanes 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 in our debt agreements and collateral requirements;
•credit risk with respect to suppliers and customers;
•changes in costs to acquire customers as well as actual attrition rates;
•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, 2020, and in our other public filings and press releases.

You should review the risk factors and other factors noted throughout or incorporated by reference in this Report that could cause our actual results to differ materially from those contained in any forward-looking statement. All forward-looking statements speak only as of the date of this Report. Unless required by law, we disclaim any obligation to publicly update or revise these statements whether as a result of new information, future events or otherwise. It is not possible for us to predict all risks, nor can we assess the impact of all factors on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements.
2
PART I. — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS
3
VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands, except share counts)
(unaudited)
September 30, 2021 December 31, 2020
Assets
Current assets:
Cash and cash equivalents $ 89,422  $ 71,684 
Restricted cash 8,697  — 
Accounts receivable, net of allowance for doubtful accounts of $2,529 at September 30, 2021 and $3,942 at December 31, 2020
47,644  70,350 
Accounts receivable—affiliates 3,406  5,053 
Inventory 2,544  1,496 
Fair value of derivative assets 44,218  311 
Customer acquisition costs, net 1,200  5,764 
Customer relationships, net 9,708  12,077 
Deposits 5,438  5,655 
Renewable energy credit asset 16,373  20,666 
Other current assets 13,778  11,818 
Total current assets 242,428  204,874 
Property and equipment, net 4,518  3,354 
Fair value of derivative assets 1,090  — 
Customer acquisition costs, net 295  306 
Customer relationships, net 3,505  5,691 
Deferred tax assets 17,344  27,960 
Goodwill 120,343  120,343 
Other assets 2,959  4,139 
Total assets $ 392,482  $ 366,667 
Liabilities, Series A Preferred Stock and Stockholders' Equity
Current liabilities:
Accounts payable $ 27,422  $ 27,322 
Accounts payable—affiliates 412  826 
Accrued liabilities 25,057  34,164 
Renewable energy credit liability 14,901  19,549 
Fair value of derivative liabilities 1,092  7,505 
Other current liabilities 2,258  1,295 
Total current liabilities 71,142  90,661 
Long-term liabilities:
Fair value of derivative liabilities 77  227 
Long-term portion of Senior Credit Facility 130,000  100,000 
Subordinated debt—affiliates 10,000  — 
Other long-term liabilities 231  30 
Total liabilities 211,450  190,918 
Commitments and contingencies (Note 12)
Series A Preferred Stock, par value $0.01 per share, 20,000,000 shares authorized, 3,707,256 shares issued and 3,567,543 shares outstanding at September 30, 2021 and December 31, 2020
87,288  87,288 
Stockholders' equity:
       Common Stock:
Class A common stock, par value $0.01 per share, 120,000,000 shares authorized, 15,716,982 shares issued and 15,572,388 shares outstanding at September 30, 2021 and 14,771,878 shares issued and 14,627,284 shares outstanding at December 31, 2020
157  148 
Class B common stock, par value $0.01 per share, 60,000,000 shares authorized, 20,000,000 shares issued and outstanding at September 30, 2021 and 20,800,000 shares issued and outstanding at December 31, 2020
201  209 
       Additional paid-in capital 53,551  55,222 
       Accumulated other comprehensive loss (40) (40)
       Retained earnings 18,103  11,721 
       Treasury stock, at cost, 144,594 shares at September 30, 2021 and December 31, 2020
(2,406) (2,406)
       Total stockholders' equity 69,566  64,854 
Non-controlling interest in Spark HoldCo, LLC 24,178  23,607 
       Total equity 93,744  88,461 
Total liabilities, Series A Preferred Stock and Stockholders' equity $ 392,482  $ 366,667 
The accompanying notes are an integral part of the condensed consolidated financial statements.
4
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,
2021 2020 2021 2020
Revenues:
Retail revenues $ 98,267  $ 141,188  $ 293,721  $ 436,166 
Net asset optimization (expense) revenue (288) (558) (542) (319)
Total Revenues 97,979  140,630  293,179  435,847 
Operating Expenses:
Retail cost of revenues 40,298  85,118  198,642  269,546 
General and administrative 9,719  19,080  33,053  66,087 
Depreciation and amortization 5,049  7,278  16,498  24,084 
Total Operating Expenses 55,066  111,476  248,193  359,717 
Operating income 42,913  29,154  44,986  76,130 
Other (expense)/income:
Interest expense (1,298) (1,487) (4,161) (4,233)
Interest and other income 63  80  228  293 
Total other expenses (1,235) (1,407) (3,933) (3,940)
Income before income tax expense 41,678  27,747  41,053  72,190 
Income tax expense 7,021  5,141  9,160  12,739 
Net income $ 34,657  $ 22,606  $ 31,893  $ 59,451 
Less: Net income attributable to non-controlling interests 19,774  12,993  14,158  34,200 
Net income attributable to Via Renewables, Inc. stockholders $ 14,883  $ 9,613  $ 17,735  $ 25,251 
Less: Dividend on Series A Preferred Stock 1,951  1,951  5,853  5,490 
Net income attributable to stockholders of Class A common stock $ 12,932  $ 7,662  $ 11,882  $ 19,761 
Net income attributable to Via Renewables, Inc. per share of Class A common stock
       Basic $ 0.83  $ 0.52  $ 0.79  $ 1.36 
       Diluted $ 0.82  $ 0.52  $ 0.79  $ 1.35 
Weighted average shares of Class A common stock outstanding
       Basic 15,572  14,653  14,965  14,531 
       Diluted 15,686  14,671  15,099  14,655 

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

5
VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
(in thousands)
(unaudited)
Nine Months Ended September 30, 2021
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, 2020 14,772  20,800  (144) $ 148  $ 209  $ (2,406) $ (40) $ 55,222  $ 11,721  $ 64,854  $ 23,607  $ 88,461 
Stock based compensation —  —  —  —  —  —  —  1,792  —  1,792  —  1,792 
Restricted stock unit vesting 145  —  1  —  —  —  (588) —  (587) —  (587)
Consolidated net income —  —  —  —  —  —  —  —  17,735  17,735  14,158  31,893 
Distributions paid to non-controlling unit holders —  —  —  —  —  —  —  —  —  —  (13,811) (13,811)
Dividends paid to Class A common stockholders ($0.54375 per share)
—  —  —  —  —  —  —  (2,651) (5,500) (8,151) —  (8,151)
Dividends paid to Preferred Stockholders —  —  —  —  —  —  —  —  (5,853) (5,853) —  (5,853)
Exchange of shares of Class B common stock to shares of Class A common stock 800  (800) —  8  (8) —  —  320  —  320  (320) — 
Changes in ownership interest —  —  —  —  —  —  —  (544) —  (544) 544  — 
Balance at September 30, 2021 15,717  20,000  (144) $ 157  $ 201  $ (2,406) $ (40) $ 53,551  $ 18,103  $ 69,566  $ 24,178  $ 93,744 

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










6

Three Months Ended September 30, 2021
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, 2021 14,917 20,800 (144) $ 149  $ 209  $ (2,406) $ (40) $ 52,878  $ 7,994  $ 58,784  $ 8,312  $ 67,096 
Stock based compensation — — — — — — —  389 — 389 — 389
Restricted stock unit vesting — — — — — — — — — — — —
Consolidated net income —  —  —  —  —  —  —  —  14,883 14,883 19,774 34,657
Distributions paid to non-controlling unit holders — — — — — — — — — — (3,624) (3,624)
Dividends paid to Class A common stockholders ($0.18125 per share)
— — — — — — — — (2,823) (2,823) — (2,823)
Dividends paid to Preferred Stockholders — — — — — — — — (1,951) (1,951) — (1,951)
Exchange of shares of Class B common stock to shares of Class A common stock 800 (800) — 8 (8) — — 320 — 320 (320) —
Changes in Ownership Interest — — — — — — — (36) — (36) 36 —
Balance at September 30, 2021
15,717  20,000  (144) $ 157  $ 201  $ (2,406) $ (40) $ 53,551  $ 18,103  $ 69,566  $ 24,178  $ 93,744 

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















7
Nine Months Ended September 30, 2020
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, 2019 14,479  20,800  (99) $ 145  $ 209  $ (2,011) $ (40) $ 51,842  $ 1,074  $ 51,219  $ 16,067  $ 67,286 
Impact of adoption of ASC 326
—  —  —  —  —  —  —  —  (633) (633) —  (633)
Balance at January 1,2020 14,479  20,800  (99) 145  209  (2,011) (40) 51,842  441  50,586  16,067  66,653 
Stock based compensation —  —  —  —  —  —  —  2,061  —  2,061  —  2,061 
Restricted stock unit vesting 293  —  —  3  —  —  —  (915) —  (912) —  (912)
Consolidated net income —  —  —  —  —  —  —  —  25,251  25,251  34,200  59,451 
Distributions paid to non-controlling unit holders —  —  —  —  —  —  —  —  —  —  (23,409) (23,409)
Dividends paid to Class A common stockholders ($0.54375 per share)
—  —  —  —  —  —  —  —  (7,917) (7,917) —  (7,917)
Dividends paid to Preferred Stockholders —  —  —  —  —  —  —  —  (5,491) (5,491) —  (5,491)
Treasury Shares —  —  (45) —  —  (395) — — (395) — (395)
Changes in ownership interest —  —  —  —  —  —  —  1,181  —  1,181  (1,181) — 
Balance at September 30, 2020 14,772  20,800  (144) $ 148  $ 209  $ (2,406) $ (40) $ 54,169  $ 12,284  $ 64,364  $ 25,677  $ 90,041 

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














8
Three Months Ended September 30, 2020
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, 2020 14,772  20,800  (99) $ 148  $ 209  $ (2,011) $ (40) $ 53,409  $ 7,275  $ 58,990  $ 22,829  $ 81,819 
Stock based compensation —  —  —  —  —  —  —  289  —  289  —  289 
Consolidated net income —  —  —  —  —  —  —  —  9,613  9,613  12,993  22,606 
Distributions paid to non-controlling unit holders —  —  —  —  —  —  —  —  —  —  (9,674) (9,674)
Dividends paid to Class A common stockholders ($0.18125 per share)
—  —  —  —  —  —  —  —  (2,652) (2,652) —  (2,652)
Dividends paid to Preferred Stockholders —  —  —  —  —  —  —  —  (1,952) (1,952) —  (1,952)
Treasury Shares —  —  (45) —  —  (395) — — (395) — (395)
Changes in ownership interest —  —  —  —  —  —  —  471  —  471  (471) — 
Balance at September 30, 2020 14,772  20,800  (144) $ 148  $ 209  $ (2,406) $ (40) $ 54,169  $ 12,284  $ 64,364  $ 25,677  $ 90,041 

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












9
VIA RENEWABLES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
(unaudited)
  
Nine Months Ended September 30,
   2021 2020
Cash flows from operating activities:
Net income $ 31,893  $ 59,451 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization expense 16,498  24,084 
Deferred income taxes 10,616  3,366 
Stock based compensation 2,012  2,134 
Amortization of deferred financing costs 792  966 
Bad debt expense 379  4,613 
(Gain) loss on derivatives, net (57,726) 14,015 
Current period cash settlements on derivatives, net 6,050  (32,682)
Changes in assets and liabilities:
Decrease in accounts receivable 22,327  44,579 
Decrease (increase) in accounts receivable—affiliates 1,647  (2,546)
(Increase) decrease in inventory (1,048) 1,158 
Increase in customer acquisition costs (765) (1,763)
Decrease in prepaid and other current assets 1,331  6,268 
Decrease in intangible assets—customer acquisition 27  — 
Decrease (increase) in other assets 577  (316)
Decrease in accounts payable and accrued liabilities (16,920) (39,997)
Decrease in accounts payable—affiliates (414) (655)
Increase in other current liabilities 1,525  1,439 
Decrease in other non-current liabilities (29) (166)
Net cash provided by operating activities 18,772  83,948 
Cash flows from investing activities:
Purchases of property and equipment (2,170) (1,219)
Acquisition of Customers (1,519) — 
Net cash used in investing activities (3,689) (1,219)
Cash flows from financing activities:
Buyback of Series A Preferred Stock —  (2,282)
Borrowings on notes payable 575,000  420,000 
Payments on notes payable (545,000) (443,000)
Net borrowings on subordinated debt facility 10,000  — 
Purchase of Treasury Stock —  (395)
Restricted stock vesting (833) (1,107)
Payment for acquired customers —  (972)
Payment of dividends to Class A common stockholders (8,151) (7,917)
Payment of distributions to non-controlling unitholders (13,811) (23,409)
Payment of Preferred Stock dividends (5,853) (5,935)
Net cash provided (used) in financing activities 11,352  (65,017)
Increase in Cash, cash equivalents and Restricted cash 26,435  17,712 
Cash, cash equivalents and Restricted cash—beginning of period 71,684  57,668 
Cash, cash equivalents and Restricted cash—end of period $ 98,119  $ 75,380 
Supplemental Disclosure of Cash Flow Information:
Non-cash items:
        Property and equipment purchase accrual $ 287  $ 5 
Cash paid (received) during the period for:
Interest $ 3,143  $ 3,198 
Taxes $ (5,076) $ 13,074 
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The accompanying notes are an integral part of the condensed consolidated financial statements.
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VIA RENEWABLES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
1. Formation and Organization
Company's Name Change

In August 2021, Spark Energy, Inc. changed its name from Spark Energy, Inc. to Via Renewables, Inc. (the "Company").

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 sole material asset consists of units in Spark HoldCo, LLC (“Spark HoldCo”). The Company is the sole managing member of Spark HoldCo, is responsible for all operational, management and administrative decisions relating to Spark HoldCo’s business and consolidates the financial results of Spark HoldCo and its subsidiaries. Spark HoldCo is the direct and indirect owner of the subsidiaries through which we operate. We conduct our business through several brands across our service areas, including Electricity Maine, Electricity N.H., Major Energy, Provider Power Massachusetts, Spark Energy, and Verde Energy.
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, 2020 (the “2020 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 and Majority Shareholder

W. Keith Maxwell, III (our "Founder") is the Company's 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
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Retail Holdings LLC ("NuDevco Retail Holdings"), which is a wholly owned subsidiary of Electric HoldCo, LLC, which is also a wholly owned subsidiary of TxEx.

New Accounting Standards Recently Adopted

There have been no changes to our significant accounting policies as disclosed in our 2020 Form 10-K, except as follows:

In December 2019, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2019-12, Income Taxes (Topic 740), Simplifying the Accounting for Income Taxes ("ASU 2019-12"). These amendments simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. For public business entities, the amendments in ASU 2019-12 are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. We adopted ASU 2019-12 effective January 1, 2021 and the adoption did not have a material impact on our consolidated financial statements.

Standards Being Evaluated/Standards Not Yet Adopted

Below are accounting standards that have been issued by the FASB but have not yet been adopted by the Company at September 30, 2021. The Company considers the applicability and impact of all ASUs. ASUs not listed below were assessed and determined to be either not applicable or are expected to have minimal impact on our consolidated financial statements.

In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848), Facilitation of the Effects of Reference Rate Reform on Financial Reporting ("ASU 2020-04"). The amendments in ASU 2020-04 provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. In January 2021, the FASB issued ASU 2021-01, Reference Rate Reform ("ASU 2021-01"), which clarifies the scope and application of certain optional expedients and exceptions regarding the original guidance. The amendments in these ASUs were effective upon issuance and can be applied prospectively through December 31, 2022. The Company's Senior Credit Facility is the only agreement that makes reference to a LIBOR rate and the agreement outlines the specific procedures that will be undertaken once an appropriate alternative benchmark is identified. We do not expect adoption of the new standard to have a material impact to 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.

Revenues for electricity and natural gas sales are recognized under the accrual method when our performance obligation to a customer is satisfied, which is the point in time when the product is delivered and control of the product passes to the customer. Electricity and natural gas products may be sold as fixed-price or variable-price products. The typical length of a contract to provide electricity and/or natural gas is twelve months. Customers are billed and typically pay at least monthly, based on usage. Electricity and natural gas sales that have been delivered but not billed by period end are estimated and recorded as accrued unbilled revenues based on estimates of customer usage since the date of the last meter read provided by the utility. Volume estimates are based on forecasted volumes and estimated residential and commercial customer usage. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class (residential or commercial). Estimated amounts are adjusted when actual usage is known and billed.
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The following table discloses revenue by primary geographical market, customer type, and customer credit risk profile (in thousands). The table also includes a reconciliation of the disaggregated revenue to revenue by reportable segment (in thousands).
Reportable Segments
Three Months Ended September 30, 2021 Three Months Ended September 30, 2020
Retail Electricity Retail Natural Gas Total Reportable Segments Retail Electricity Retail Natural Gas Total Reportable Segments
Primary markets (a)
New England $ 25,406  $ 748  $ 26,154  $ 46,464  $ 1,361  $ 47,825 
Mid-Atlantic 30,122  1,354  31,476  46,878  2,243  49,121 
Midwest 12,473  1,367  13,840  16,933  1,540  18,473 
Southwest 24,103  2,694  26,797  22,683  3,086  25,769 
$ 92,104  $ 6,163  $ 98,267  $ 132,958  $ 8,230  $ 141,188 
Customer type
Commercial $ 12,395  $ 2,076  $ 14,471  $ 34,180  $ 2,705  $ 36,885 
Residential 82,778  3,781  86,559  103,092  5,082  108,174 
Unbilled revenue (b) (3,069) 306  (2,763) (4,314) 443  (3,871)
$ 92,104  $ 6,163  $ 98,267  $ 132,958  $ 8,230  $ 141,188 
Customer credit risk
POR $ 53,670  $ 2,151  $ 55,821  $ 87,439  $ 3,010  $ 90,449 
Non-POR 38,434  4,012  42,446  45,519  5,220  50,739 
$ 92,104  $ 6,163  $ 98,267  $ 132,958  $ 8,230  $ 141,188 











14
Reportable Segments
Nine Months Ended September 30, 2021 Nine Months Ended September 30, 2020
Retail Electricity Retail Natural Gas Total Reportable Segments Retail Electricity Retail Natural Gas Total Reportable Segments
Primary markets (a)
New England $ 73,045  $ 6,527  $ 79,572  $ 133,218  $ 11,144  $ 144,362 
Mid-Atlantic 81,981  18,032  100,013  131,463  23,976  155,439 
Midwest 32,894  14,515  47,409  46,428  19,338  65,766 
Southwest 54,628  12,099  66,727  55,872  14,727  70,599 
$ 242,548  $ 51,173  $ 293,721  $ 366,981  $ 69,185  $ 436,166 
Customer type
Commercial $ 38,782  $ 18,574  $ 57,356  $ 103,603  $ 25,512  $ 129,115 
Residential 213,440  39,911  253,351  275,229  53,410  328,639 
Unbilled revenue (b) (9,674) (7,312) (16,986) (11,851) (9,737) (21,588)
$ 242,548  $ 51,173  $ 293,721  $ 366,981  $ 69,185  $ 436,166 
Customer credit risk
POR $ 145,924  $ 26,731  $ 172,655  $ 246,046  $ 34,423  $ 280,469 
Non-POR 96,624  24,442  121,066  120,935  34,762  155,697 
$ 242,548  $ 51,173  $ 293,721  $ 366,981  $ 69,185  $ 436,166 

(a) The primary markets include the following states:

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

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

We record gross receipts taxes on a gross basis in retail revenues and retail cost of revenues. During the three months ended September 30, 2021 and 2020, our retail revenues included gross receipts taxes of $0.3 million and $0.3 million, respectively, and our retail cost of revenues included gross receipts taxes of $1.2 million and $1.6 million, respectively. During the nine months ended September 30, 2021 and 2020, our retail revenues included gross receipts taxes of $0.8 million and $1.0 million, respectively, and our retail cost of revenues included gross receipts taxes of $3.4 million and $4.7 million, respectively.

Accounts receivables and Allowance for Credit Losses

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

A rollforward of our allowance for credit losses for the nine months ended September 30, 2021 are presented in the table below (in thousands):

Balance at December 31, 2020 $ (3,942)
Current period bad debt provision (139)
Write-offs 1,907 
Recovery of previous write offs (355)
Balance at September 30, 2021 $ (2,529)

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, 2021 and December 31, 2020, respectively.

The Company Affiliated Owners
September 30, 2021 44.00  % 56.00  %
December 31, 2020 41.53  % 58.47  %

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,
2021 2020 2021 2020
Net income allocated to non-controlling interest $ 21,959  $ 14,909  $ 18,884  $ 38,717 
Income tax expense allocated to non-controlling interest 2,185  1,916  4,726  4,517 
Net income attributable to non-controlling interest $ 19,774  $ 12,993  $ 14,158  $ 34,200 

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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.

Conversion of Class B Common Stock to Class A Common Stock

In July 2021, holders of Class B common stock exchanged 800,000 of their Spark HoldCo units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock at an exchange ratio of one share of Class A common stock for each Spark HoldCo unit (and corresponding share of Class B common stock) exchanged.

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 nine months ended September 30, 2021, we paid $8.2 million in dividends to the holders of the Company's Class A common stock. This dividend represented a quarterly rate of $0.18125 per share on each share of Class A common stock.

In order to 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 nine months ended September 30, 2021, Spark HoldCo made corresponding distributions of $11.2 million to our non-controlling interest holders.

Share Repurchase Program

On August 18, 2020, our Board of Directors authorized a share repurchase program of up to $20.0 million of Class A common stock through August 18, 2021. Purchases could be made with available cash balances, our Senior Credit Facility and operating cash flows.

The shares of Class A common stock could be repurchased from time to time in the open market at prevailing market prices or in privately negotiated transactions based on ongoing assessments of capital needs, the market price of the stock, and other factors, including general market conditions. The repurchase program did not obligate us to acquire any particular amount of Class A common stock, could be modified or suspended at any time, and could be terminated prior to completion.

During the nine months ended September 30, 2021, we did not repurchase our Class A common stock. The share repurchase program expired on August 18, 2021 pursuant to an agreement with lenders under our Senior Credit Facility, and our Senior Credit Facility was subsequently amended, terminating the provision for borrowings specific to Class A common stock repurchases. See Note 9 "Debt" for further discussion.

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, 2021 and 2020 (in thousands, except per share data):
17
Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
Net income attributable to Via Renewables, Inc. stockholders $ 14,883  $ 9,613  $ 17,735  $ 25,251 
Less: Dividend on Series A Preferred Stock 1,951  1,951  5,853  5,490 
Net income attributable to stockholders of Class A common stock $ 12,932  $ 7,662  $ 11,882  $ 19,761 
Basic weighted average Class A common shares outstanding 15,572  14,653  14,965  14,531 
Basic income per share attributable to stockholders $ 0.83  $ 0.52  $ 0.79  $ 1.36 
Net income attributable to stockholders of Class A common stock $ 12,932  $ 7,662  $ 11,882  $ 19,761 
Effect of conversion of Class B common stock to shares of Class A common stock —  —  —  — 
Diluted net income attributable to stockholders of Class A common stock $ 12,932  $ 7,662  $ 11,882  $ 19,761 
Basic weighted average Class A common shares outstanding 15,572  14,653  14,965  14,531 
Effect of dilutive Class B common stock —  —  —  — 
Effect of dilutive restricted stock units 114  18  134  124 
Diluted weighted average shares outstanding 15,686  14,671  15,099  14,655 
Diluted income per share attributable to stockholders $ 0.82  $ 0.52  $ 0.79  $ 1.35 

The computation of diluted earnings per share for the three and nine months ended September 30, 2021, respectively, excludes 20.0 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. 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, 2021 and December 31, 2020 (in thousands):
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September 30, 2021 December 31, 2020
Assets
Current assets:
   Cash and cash equivalents $ 89,276  $ 71,442 
   Accounts receivable 47,644  70,350 
   Other current assets 99,963  55,575 
   Total current assets 236,883  197,367 
Non-current assets:
   Goodwill 120,343  120,343 
   Other assets 12,747  15,259 
   Total non-current assets 133,090  135,602 
   Total Assets $ 369,973  $ 332,969 
Liabilities
Current liabilities:
   Accounts payable and accrued liabilities $ 52,442  $ 61,436 
   Other current liabilities 46,818  43,676 
   Total current liabilities 99,260  105,112 
Long-term liabilities:
   Long-term portion of Senior Credit Facility 130,000  100,000 
   Subordinated debt — affiliate
10,000  — 
   Other long-term liabilities 308  256 
   Total long-term liabilities 140,308  100,256 
   Total Liabilities $ 239,568  $ 205,368 

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 accrue dividends at an annual percentage rate of 8.75%, and 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 sheet.

During the three and nine months ended September 30, 2021, we paid $1.9 million and $5.9 million in dividends to holders of the Series A Preferred Stock, respectively. As of September 30, 2021, we had accrued $2.0 million related to dividends to holders of the Series A Preferred Stock. This dividend was paid on October 15, 2021.

A summary of our preferred equity balance for the nine months ended September 30, 2021 is as follows:
(in thousands)
Balance at December 31, 2020 $ 87,288 
Repurchase of Series A Preferred Stock — 
Accumulated dividends on Series A Preferred Stock — 
Balance at September 30, 2021
$ 87,288 


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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, 2021 and December 31, 2020, we offset $1.7 million and $0.1 million, respectively, in collateral to net against the related derivative asset and liability's fair value. The specific types of derivative instruments we may execute to manage the commodity price risk include the following:

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

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

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

Volumes Underlying Derivative Transactions
The following table summarizes the net notional volumes of our open derivative financial instruments accounted for at fair value by commodity. Positive amounts represent net buys while bracketed amounts are net sell transactions (in thousands):
Non-trading 
Commodity Notional September 30, 2021 December 31, 2020
Natural Gas MMBtu 3,195  2,880 
Electricity MWh 1,804  1,845 
Trading
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Commodity Notional September 30, 2021 December 31, 2020
Natural Gas MMBtu 1,202  102 
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,
   2021 2020 2021 2020
Gain (Loss) on non-trading derivatives, net $ 32,262  $ 2,550  $ 58,214  $ (14,019)
(Loss) Gain on trading derivatives, net (464) (99) (488) 4 
Gain (Loss) on derivatives, net 31,798  2,451  57,726  (14,015)
Current period settlements on non-trading derivatives (1)
$ (5,660) $ 6,489  $ (6,054) $ 33,153 
Current period settlements on trading derivatives —  (64) 4  (156)
Total current period settlements on derivatives $ (5,660) $ 6,425  $ (6,050) $ 32,997 

(1) Excludes settlements of $(0.3) million, for the nine months ended September 30, 2020 related to power call options.
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, 2021
Description Gross Assets Gross
Amounts
Offset 		Net Assets Cash
Collateral
Offset 		Net Amount
Presented
Non-trading commodity derivatives $ 57,181  $ (11,972) $ 45,209  $ (1,677) $ 43,532 
Trading commodity derivatives 1,303  (617) 686  —  686 
Total Current Derivative Assets 58,484  (12,589) 45,895  (1,677) 44,218 
Non-trading commodity derivatives 1,343  (253) 1,090  —  1,090 
Trading commodity derivatives —  —  —  —  — 
Total Non-current Derivative Assets 1,343  (253) 1,090  —  1,090 
Total Derivative Assets $ 59,827  $ (12,842) $ 46,985  $ (1,677) $ 45,308 
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Description Gross 
Liabilities 		Gross
Amounts
Offset 		Net
Liabilities 		Cash
Collateral
Offset 		Net Amount
Presented
Non-trading commodity derivatives $ —  $ —  $ —  $ —  $ — 
Trading commodity derivatives (1,405) 313  (1,092) —  (1,092)
Total Current Derivative Liabilities (1,405) 313  (1,092) —  (1,092)
Non-trading commodity derivatives (332) 255  (77) —  (77)
Trading commodity derivatives —  —  —  —  — 
Total Non-current Derivative Liabilities (332) 255  (77) —  (77)
Total Derivative Liabilities $ (1,737) $ 568  $ (1,169) $ —  $ (1,169)
  
December 31, 2020
Description Gross Assets Gross
Amounts
Offset 		Net Assets Cash
Collateral
Offset 		Net Amount
Presented
Non-trading commodity derivatives $ 308  $ (105) $ 203  $ —  $ 203 
Trading commodity derivatives 112  (4) 108  —  108 
Total Current Derivative Assets 420  (109) 311  —  311 
Non-trading commodity derivatives —  —  —  —  — 
Trading commodity derivatives —  —  —  —  — 
Total Non-current Derivative Assets —  —  —  —  — 
Total Derivative Assets $ 420  $ (109) $ 311  $ —  $ 311 
Description Gross 
Liabilities 		Gross
Amounts
Offset 		Net
Liabilities 		Cash
Collateral
Offset 		Net Amount
Presented
Non-trading commodity derivatives $ (11,139) $ 3,620  $ (7,519) $ 86  $ (7,433)
Trading commodity derivatives (74) 2  (72) —  (72)
Total Current Derivative Liabilities (11,213) 3,622  (7,591) 86  (7,505)
Non-trading commodity derivatives (838) 611  (227) —  (227)
Trading commodity derivatives —  —  —  —  — 
Total Non-current Derivative Liabilities (838) 611  (227) —  (227)
Total Derivative Liabilities $ (12,051) $ 4,233  $ (7,818) $ 86  $ (7,732)





















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7. Property and Equipment
Property and equipment consist of the following (in thousands):
Estimated useful
lives (years) 		September 30, 2021 December 31, 2020
Information technology
2 – 5
$ 6,405  $ 5,821 
Furniture and fixtures
2 – 5
957  957 
Total 7,362  6,778 
Accumulated depreciation (2,844) (3,424)
Property and equipment—net $ 4,518  $ 3,354 
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, 2021 and December 31, 2020, information technology includes $0.4 million and $0.7 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, respectively, for the three months ended September 30, 2021 and 2020 and $1.3 million and $1.6 million for the nine months ended September 30, 2021 and 2020, respectively.
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8. Intangible Assets
Goodwill, customer relationships and trademarks consist of the following amounts (in thousands):
September 30, 2021 December 31, 2020
Goodwill $ 120,343  $ 120,343 
Customer relationships—Acquired
Cost $ 58,688  $ 58,688 
Accumulated amortization (50,985) (44,175)
Customer relationships—Acquired
$ 7,703  $ 14,513 
Customer relationships—Other
Cost $ 13,422  $ 8,988 
Accumulated amortization (7,912) (5,733)
Customer relationships—Other, net
$ 5,510  $ 3,255 
Trademarks
Cost $ 7,040  $ 7,570 
Accumulated amortization (3,257) (2,972)
Trademarks, net $ 3,783  $ 4,598 

Changes in goodwill, customer relationships (including non-compete agreements) and trademarks consisted of the following (in thousands):
Goodwill
Customer Relationships— Acquired
Customer Relationships— Other
Trademarks
Balance at December 31, 2020 $ 120,343  $ 14,513  $ 3,255  $ 4,598 
Additions —  —  4,524  — 
Adjustments —  —  (28) — 
Amortization —  (6,810) (2,241) (815)
Balance at September 30, 2021 $ 120,343  $ 7,703  $ 5,510  $ 3,783 

Estimated future amortization expense for customer relationships and trademarks at September 30, 2021 is as follows (in thousands):
Year ending December 31,
2021 (remaining three months) $ 3,640 
2022 7,702 
2023 2,113 
2024 1,521 
2025 404 
> 5 years 1,616 
Total $ 16,996 
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9. Debt
Debt consists of the following amounts as of September 30, 2021 and December 31, 2020 (in thousands):
September 30, 2021 December 31, 2020
Long-term debt:
  Senior Credit Facility (1) (2)
$ 130,000  $ 100,000 
  Subordinated Debt
10,000  — 
Total long-term debt 140,000  100,000 
Total debt $ 140,000  $ 100,000 
(1) As of September 30, 2021 and December 31, 2020, the weighted average interest rate on the Senior Credit Facility was 3.75% and 3.75%, respectively.
(2) As of September 30, 2021 and December 31, 2020, we had $24.4 million and $31.0 million in letters of credit issued, respectively.

Capitalized financing costs associated with our Senior Credit Facility were $0.9 million and $1.6 million as of September 30, 2021 and December 31, 2020, respectively. Of these amounts, $0.9 million and $1.0 million are recorded in other current assets, and zero and $0.6 million are recorded in other non-current assets in the condensed consolidated balance sheets as of September 30, 2021 and December 31, 2020, respectively.
Interest expense consists of the following components for the periods indicated (in thousands):
Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
Senior Credit Facility $ 678  $ 477  $ 1,950  $ 1,904 
Letters of credit fees and commitment fees 351  244  1,088  1,073 
Amortization of deferred financing costs
275  476  792  966 
Other
(6) 290  331  290 
Interest Expense
$ 1,298  $ 1,487  $ 4,161  $ 4,233 

Senior Credit Facility

The Company, as guarantor, and Spark HoldCo (the “Borrower” and, together with each subsidiary of Spark HoldCo (“Co-Borrowers”)) maintain a senior secured borrowing base credit facility (as amended from time to time, “Senior Credit Facility”) that allows us to borrow on a revolving basis and has a maximum borrowing capacity of $227.5 million as of September 30, 2021. As further described below, on October 15, 2021, the Company entered into the Fifth Amendment to its Senior Credit Facility.

Prior to the Fifth Amendment and subject to applicable sub-limits and terms of the Senior Credit Facility, borrowings were available for the issuance of letters of credit (“Letters of Credit”), working capital and general purpose revolving credit loans (“Working Capital Loans”), and share buyback loans (“Share Buyback Loans”). Prior to the Fifth Amendment, the Senior Credit Facility matured in July 2022.

On October 15, 2021, the Company entered into the Fifth Amendment to its Senior Credit Facility, which, among other things extended the maturity date, added a provision for borrowings to fund acquisitions ("Acquisition Loans") subject to limits as defined in the agreement, and terminated the provision allowing for Share Buyback Loans. Pursuant to the Fifth Amendment, the Senior Credit Facility will mature on October 13, 2023, and all amounts outstanding thereunder will be payable on the maturity date. Borrowings under the Senior Credit Facility may be used to pay fees and expenses in connection with the Senior Credit Facility, finance ongoing working capital requirements and general corporate purpose requirements of the Co-Borrowers, and to provide partial funding for acquisitions, as allowed under terms of the Senior Credit Facility. The Fifth Amendment provides for Acquisition Loans not to exceed 75% of the adjusted purchase price of the acquisition, as defined in the agreement.
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Pursuant to the Senior Credit Facility, the interest rate for Working Capital Loans and Letters of Credit under the Senior Credit Facility is generally determined by reference to the Eurodollar rate plus an applicable margin of up to 3.25% per annum (based on the prevailing utilization) or an alternate base rate plus an applicable margin of up to 2.25% per annum (based on the prevailing utilization). The alternate base rate is equal to the highest of (i) the prime rate (as published in the Wall Street Journal), (ii) the federal funds rate plus 0.50% per annum, or (iii) the reference Eurodollar rate plus 1.00%.

Prior to the Fifth Amendment, borrowings under the Senior Credit Facility for Share Buyback Loans, were generally determined by reference to the Eurodollar rate plus an applicable margin of 4.50% per annum or the alternate base rate plus an applicable margin of 3.50% per annum.

Pursuant to the Fifth Amendment, borrowings under the Senior Credit Facility for Acquisition Loans are generally determined by reference to the Eurodollar rate plus an applicable margin of 4.00% per annum or the alternate base rate plus an applicable margin of 3.00% per annum.

The Co-Borrowers pay a commitment 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 agency fee, and letter of credit fees based on a percentage of the face amount of letters of credit payable to any syndicate member that issues a letter of credit.

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

•Minimum Fixed Charge Coverage Ratio. We must maintain a minimum fixed charge coverage ratio of not less than 1.25 to 1.00. The Minimum Fixed Charge Coverage Ratio is defined as the ratio of (a) Adjusted EBITDA to (b) the sum of consolidated (with respect to the Company and the Co-Borrowers) interest expense, letter of credit fees, commitment fees, acquisition earn-out payments (excluding earnout payments funded with proceeds from newly issued preferred or common equity), distributions, scheduled amortization payments, and payments made on or after the closing of the Fourth Amendment to the Senior Credit Facility (other than such payments made from escrow accounts which were funded in connection with a permitted acquisition) 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, 2021 was 1.95 to 1.00.

•Maximum Total Leverage Ratio. We must maintain a ratio of (x) the sum of total indebtedness (excluding eligible subordinated debt and letter of credit obligations), plus (y) gross amounts reserved for civil and regulatory liabilities identified in SEC filings, to Adjusted EBITDA of no more than 2.50 to 1.00. Our Maximum Total Leverage Ratio as of September 30, 2021 was 1.59 to 1.00.

•Maximum Senior Secured Leverage Ratio. We must maintain a Senior Secured Leverage Ratio of no more than 1.85 to 1.00. The Senior Secured Leverage Ratio is defined as the ratio of (a) all indebtedness of the loan parties on a consolidated basis 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) to (b) Adjusted EBITDA. Our Maximum Senior Secured Leverage Ratio as of September 30, 2021 was 1.39 to 1.00.

The Senior Credit Facility contains various negative covenants that limit our ability to, among other things, incur certain additional indebtedness, grant certain liens, engage in certain asset dispositions, merge or consolidate, make certain payments, distributions, investments, acquisitions or loans, materially modify certain agreements, or enter into transactions with affiliates. The Senior Credit Facility also contains affirmative covenants that are customary for credit facilities of this type. As of September 30, 2021, we were in compliance with our various covenants under the Senior Credit Facility.

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

We are entitled to pay cash dividends to the holders of the 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 does not exceed the borrowing base limits. Prior to the Fifth Amendment, which terminated Share Buyback Loans, we were entitled to repurchase up to an aggregate amount of 10,000,000 shares of our Class A common stock, and up to $92.7 million of Series A Preferred Stock through one or more normal course open market purchases through NASDAQ so long: (a) no default existed or would result therefrom; (b) the Co-Borrowers were 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 did not exceed the borrowing base limits.

The Senior Credit Facility contains certain customary representations and warranties and events of default. Events of default include, among other things, payment defaults, breaches of representations and warranties, covenant defaults, cross-defaults and cross-acceleration to certain indebtedness, certain events of bankruptcy, certain events under ERISA, material judgments in excess of $5.0 million, certain events with respect to material contracts, and actual or asserted failure of any guaranty or security document supporting the Senior Credit Facility to be in full force and effect. A default will also occur if at any time W. Keith Maxwell III ceases to, directly or indirectly, own at least 13,600,000 Class A and Class B shares on a combined basis (to be adjusted for any stock split, subdivisions or other stock reclassification or recapitalization), 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

In October 2021, the Company entered into 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 amended and restated the Subordinated Promissory Note dated June 2019, by and among the Company, Spark HoldCo and Retailco, solely to extend the maturity date from January 31, 2023 to January 31, 2025.

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. Advances thereunder accrue interest at 5% per annum from the date of the advance. We have 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. We may pay interest and prepay principal on the Subordinated Debt Facility so long as we are in compliance with the covenants under our Senior Credit Facility, are not in default under the Senior Credit Facility and have 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, 2021, and December 31, 2020, there were $10.0 million and zero outstanding borrowings under the Subordinated Debt Facility.
10. Fair Value Measurements
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes the credit standing of counterparties involved and the impact of credit enhancements.
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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, 2021        
Non-trading commodity derivative assets $ 1,079  $ 43,543  $ —  $ 44,622 
Trading commodity derivative assets 28  658  —  686 
Total commodity derivative assets $ 1,107  $ 44,201  $ —  $ 45,308 
Non-trading commodity derivative liabilities $ —  $ (77) $ —  $ (77)
Trading commodity derivative liabilities —  (1,092) —  (1,092)
Total commodity derivative liabilities $ —  $ (1,169) $ —  $ (1,169)
Level 1 Level 2 Level 3 Total
December 31, 2020
Non-trading commodity derivative assets $ 104  $ 99  $ —  $ 203 
Trading commodity derivative assets —  108  —  108 
Total commodity derivative assets $ 104  $ 207  $ —  $ 311 
Non-trading commodity derivative liabilities $ (5) $ (7,655) $ —  $ (7,660)
Trading commodity derivative liabilities —  (72) —  (72)
Total commodity derivative liabilities $ (5) $ (7,727) $ —  $ (7,732)
We had no transfers of assets or liabilities between any of the above levels during the nine months ended September 30, 2021 and the year ended December 31, 2020.
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
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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, 2021 and December 31, 2020, the credit risk valuation adjustment was a reduction of derivative assets and liabilities, respectively, net of $0.4 million and $0.2 million.

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, 2021, we had a net deferred tax asset of $17.3 million, of which approximately $15.6 million related 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, 2021 and 2020 was 16.8% and 18.5%, respectively. The effective U.S. federal and state income tax rate for the nine months ended September 30, 2021 and 2020 was 22.3% and 17.6%, respectively. The effective tax rate for the three and nine months ended September 30, 2021 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.
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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.

Variable Rate Cases

In the cases referred to as Variable Rate Cases, such actions involve consumers alleging they paid higher rates than they would have if they stayed with their default utility. The underlying claims of each case are similar; however, because numerous cases have been brought in several different jurisdictions, the varying applicable case law, the varying facts and stages of each case, the Company agreed to mediate to avoid duplicative defense costs in numerous jurisdictions. The Company continues to deny the allegations asserted by Plaintiffs and intends to vigorously defend these matters.

In August 2020, the Company participated in mediation which covered three Spark brand matters: (1) Janet Rolland et al v. Spark Energy, LLC (D.N.J Apr. 2017); (2) Burger v. Spark Energy Gas, LLC (N.D. Ill. Dec. 2019); and (3) Local 901 v. Spark Energy, LLC (Sup. Ct. Allen County, Indiana Aug. 2019). The Company is working with the mediator to find a resolution to these cases, but is also simultaneously continuing to defend the cases in the respective courts. Given the ongoing mediation, discovery, and current stage of these matters, we cannot predict the outcome of these cases at this time.

In December of 2020, the Company participated in mediation which covered several Verde brand matters: (1) Marshall. Verde Energy USA, Inc. (D.N.J. Jan. 2018); (2) Mercado v. Verde Energy USA, Inc. (N.D. Ill. Mar. 2018); (3) Davis v. Verde Energy USA, Inc., et al. (D. Mass. Apr. 2019); (4) Panzer v. Verde Energy, USA Inc. and Oasis Power, LLC (E.D. Pa Aug. 2019); (5) LaQua v. Verde Energy USA New York, LLC (E.D.N Y. Jan. 2020); and (6) Abbate v. Verde Energy USA Ohio, LLC (S.D. Ohio Jun. 2020).The parties agreed to a global settlement that would resolve all of these Verde cases on a nationwide basis. On August 18, 2021, the class action settlement agreement was granted preliminary approval in the United States District Court for the Northern District of Illinois Eastern Division, and the deadline for consumers to file a claim is March 31, 2022.

On January 14, 2021, Glikin, et. all 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 believes there is no merit to this case and plans to vigorously defend this matter; however, given the current early stage of this matter, we cannot predict the outcome of this case at this time.
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Corporate Matter Lawsuits

Saul Horowitz, as Sellers’ Representative for the former owners of the Major Energy Companies v. National Gas & Electric, LLC (“NG&E”) and Spark Energy, Inc., was a lawsuit filed on October 17, 2017 in the United States District Court for the Southern District of New York related to the Company's purchase of Major Energy and structure of the earn-out in connection therewith ("Major Earn-Out Case") asserting claims of fraudulent inducement against NG&E, breach of contract against NG&E and Spark, and tortious interference with contract against Spark related to a membership interest purchase agreement, subsequent dropdown, and associated earnout agreements with the Major Energy Companies' former owners. On September 30, 2021, the Court held in favor of the Company on all claims and entered judgment in favor of the Company to close this case. On October 29, 2021, plaintiffs filed a notice of appeal to the Second Circuit Court of Appeals. The Company will continue to aggressively defend this matter.

Several smaller, related cases to the Major Earn-Out Case involving the same facts are pending in the United States District Court for the Southern District of New York. These are regarding Major Energy executive compensation agreements. The Company believes there is no merit to these cases and is vigorously defending these matters; however, we cannot predict the outcome of these cases at this time.

In addition to the matters disclosed above, 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.

Connecticut. In 2019, PURA initiated review of two of the Company's brands in Connecticut, Spark and Verde, focusing on marketing, billing and enrollment practices. The Company has and is cooperating with PURA's requests to review Spark and Verde practices in Connecticut.

New York. Prior to the purchase of Major Energy by the Company, in 2015, Major Energy Services, LLC and Major Energy Electric Services were contacted by the Attorney General, Bureau of Consumer Frauds & Protection for State of New York relating to their marketing practices. Major Energy has exchanged information in response to various requests from the Attorney General and recently agreed to respond to additional questions via remote proceedings in October of 2020. The parties are in settlement negotiations at this time; however, no agreement has been met by parties.

Pennsylvania. Verde Energy USA, Inc. (“Verde”) was the subject of a formal investigation by the Pennsylvania Public Utility Commission, Bureau of Investigation and Enforcement (“PPUC”) initiated on January 30, 2020. The investigation asserted that Verde may have violated Pennsylvania retail energy supplier regulations. The Company met with the PPUC in February 2020 to discuss the matter and to work with the PPUC cooperatively. Verde reached a settlement, which included payment of a civil penalty of $1.0 million and a $0.1 million contribution to the PPL hardship fund. On June 30, 2020, Verde and PPUC Bureau of Investigation and Enforcement filed a Joint Petition for Approval of Settlement and Statements in Support of that Joint Petition with the Commission. Verde is currently awaiting final approval of this settlement.
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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 2014 to 2021 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, 2021 and December 31, 2020, we had accrued $19.3 million and $26.6 million, respectively, related to litigation and regulatory matters and $2.1 million and $1.2 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, 2021 December 31, 2020
Assets
Accounts Receivable - affiliates $ 3,406  $ 5,053 
Total Assets - affiliates
$ 3,406  $ 5,053 

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September 30, 2021 December 31, 2020
Liabilities
Accounts Payable - affiliates $ 412  $ 826 
Subordinated Debt - affiliates (1)
10,000  — 
Total Liabilities - affiliates
$ 10,412  $ 826 
(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. Advances thereunder accrue interest at 5% per annum 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,
2021 2020 2021 2020
Revenue NAO - affiliates $ 249  $ 125  $ 818  $ 843 
Cost of Revenue NAO - affiliates —  5  5  241 
Net NAO - affiliates
$ 249  $ 120  $ 813  $ 602 

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 $(0.6) million and $0.5 million for the three months ended September 30, 2021 and 2020, respectively. The total net amount direct billed and allocated to/(from) affiliates was $(0.3) million and $0.5 million for the nine months ended September 30, 2021 and 2020, respectively.

General and administrative costs of zero and $0.1 million were recorded for the three months ended September 30, 2021 and 2020, respectively, and $0.1 million and $0.2 million for the nine months ended September 30, 2021 and 2020, respectively. The general and administrative costs relate to telemarketing activities performed by an affiliate.

Distributions to and Contributions from Affiliates

During three months ended September 30, 2021 and 2020, Spark HoldCo made distributions to affiliates of our Founder of $3.6 million and $3.8 million, respectively, for the payments of quarterly distribution on their respective Spark HoldCo units. During the three months ended September 30, 2021 and 2020, Spark HoldCo also made distributions to these affiliates for gross-up distributions of zero and $5.9 million, respectively, in connection with distributions made between Spark HoldCo and Via Renewables, Inc. for payment of income taxes incurred by us.

During each of the nine months ended September 30, 2021 and 2020, Spark HoldCo made distributions to affiliates of our Founder of $11.2 million and $11.3 million, for payments of quarterly distributions on their respective Spark HoldCo units. During the nine months ended September 30, 2021 and 2020, Spark HoldCo also made distributions to these affiliates for gross-up distributions of $2.6 million and $12.1 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. The retail natural gas segment consists of natural gas sales to, and natural gas
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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. Asset optimization activities are also included in Corporate and other.
For the three months ended September 30, 2021 and 2020, we recorded asset optimization revenues of $9.6 million and $6.2 million and asset optimization cost of revenues of $9.9 million and $6.8 million, respectively, and for the nine months ended September 30, 2021 and 2020, we recorded asset optimization revenues of $43.1 million and $16.5 million and asset optimization cost of revenues of $43.6 million and $16.8 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 have historically defined retail gross margin as operating (loss) income plus (i) depreciation and amortization expenses and (ii) general and administrative expenses, less (i) net asset optimization (expenses) revenues, (ii) net (losses) gains on non-trading derivative instruments, and (iii) net current period cash settlements on non-trading derivative instruments.
Based on the events described below related to the February 2021 North American winter storm referred to as Winter Storm Uri ("Winter Storm Uri"), and to ensure Retail Gross Margin reflects repeatable operating performance that is not distorted by non-recurring events or extreme market volatility, we have revised the definition of Retail Gross Margin in this Report to include 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. Retail gross margin should not be considered an alternative to, or more meaningful than, operating income, as determined in accordance with GAAP.
Below is a reconciliation of retail gross margin to income before income tax expense (in thousands):

  
Three Months Ended September 30, Nine Months Ended September 30,
   2021 2020 2021 2020
Reconciliation of Retail Gross Margin to income before taxes
Income before income tax expense $ 41,678  $ 27,747  $ 41,053  $ 72,190 
Interest and other income (63) (80) (228) (293)
Interest expense 1,298  1,487  4,161  4,233 
Operating income 42,913  29,154  44,986  76,130 
Depreciation and amortization 5,049  7,278  16,498  24,084 
General and administrative 9,719  19,080  33,053  66,087 
Less:
Net asset optimization (expense) revenue (288) (558) (542) (319)
Net, gain (loss) on non-trading derivative instruments 32,262  2,550  58,214  (14,019)
Net, Cash settlements on non-trading derivative instruments (5,660) 6,489  (6,054) 33,153 
Non-recurring event - Winter Storm Uri 497  —  (64,403) — 
Retail Gross Margin $ 30,870  $ 47,031  $ 107,322  $ 147,486 

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Financial data for business segments are as follows (in thousands):
Three Months Ended September 30, 2021
Retail
Electricity 		Retail
Natural Gas 		Corporate
and Other 		Eliminations Consolidated
Total Revenues $ 92,104  $ 6,163  $ (288) $ —  $ 97,979 
Retail cost of revenues 41,035  (737) —  —  40,298 
Less:
Net asset optimization expense —  —  (288) —  (288)
Net, gain on non-trading derivative instruments 27,558  4,704  —  —  32,262 
Current period settlements on non-trading derivatives (5,199) (461) —  —  (5,660)
Non-recurring event - Winter Storm Uri Credit 497  —  —  —  497 
Retail Gross Margin $ 28,213  $ 2,657  $ —  $ —  $ 30,870 
Total Assets at September 30, 2021 $ 3,130,077  $ 996,315  $ 332,666  $ (4,066,576) $ 392,482 
Goodwill at September 30, 2021 $ 117,813  $ 2,530  $ —  $ —  $ 120,343 

Three Months Ended September 30, 2020
Retail
Electricity 		Retail
Natural Gas 		Corporate
and Other 		Eliminations Consolidated
Total revenues $ 132,958  $ 8,230  $ (558) $ —  $ 140,630 
Retail cost of revenues 82,061  3,057  —  —  85,118 
Less:
Net asset optimization expense —  —  (558) —  (558)
Net, gain on non-trading derivative instruments 1,923  627  —  —  2,550 
Current period settlements on non-trading derivatives 6,212  277  —  —  6,489 
Retail Gross Margin $ 42,762  $ 4,269  $ —  $ —  $ 47,031 
Total Assets at December 31, 2020 $ 2,906,139  $ 941,569  $ 318,865  $ (3,799,906) $ 366,667 
Goodwill at December 31, 2020 $ 117,813  $ 2,530  $ —  $ —  $ 120,343 
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Nine Months Ended September 30, 2021
Retail
Electricity 		Retail
Natural Gas 		Corporate
and Other 		Eliminations Consolidated
Total revenues $ 242,548  $ 51,173  $ (542) $ —  $ 293,179 
Retail cost of revenues 179,762  18,880  —  —  198,642 
Less:
Net asset optimization expense —  —  (542) —  (542)
Net gain on non-trading derivatives 51,957  6,257  —  —  58,214 
Current period settlements on non-trading derivatives (5,246) (808) —  —  (6,054)
Non-recurring event - Winter Storm Uri (64,403) —  —  —  (64,403)
Retail Gross Margin $ 80,478  $ 26,844  $ —  $ —  $ 107,322 
Total Assets at September 30, 2021 $ 3,130,077  $ 996,315  $ 332,666  $ (4,066,576) $ 392,482 
Goodwill at September 30, 2021 $ 117,813  $ 2,530  $ —  $ —  $ 120,343 
Nine Months Ended September 30, 2020
Retail
Electricity 		Retail
Natural Gas 		Corporate
and Other 		Eliminations Consolidated
Total revenues $ 366,981  $ 69,185  $ (319) $ —  $ 435,847 
Retail cost of revenues 241,712  27,834  —  —  269,546 
Less:
Net asset optimization expense —  —  (319) —  (319)
Net (loss) gain on non-trading derivatives (14,416) 397  —  —  (14,019)
Current period settlements on non-trading derivatives 30,544  2,609  —  —  33,153 
Retail Gross Margin $ 109,141  $ 38,345  $ —  $ —  $ 147,486 
Total Assets at December 31, 2020 $ 2,906,139  $ 941,569  $ 318,865  $ (3,799,906) $ 366,667 
Goodwill at December 31, 2020 $ 117,813  $ 2,530  $ —  $ —  $ 120,343 
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15. Customer Acquisitions
Acquisition of Customer Books

In May 2021, we entered into a series of asset purchase agreements and agreed to acquire up to approximately 56,900 RCEs for a cash purchase price of up to a maximum of $11.5 million. These customers began transferring in August 2021, and are located in our existing markets. During the nine months ended September 30, 2021, a total of $1.5 million was paid for approximately 28,000 RCEs ($4.5 million for acquired customer contracts, net of $3.0 million related holdbacks under the terms of the purchase agreement). In addition, approximately $1.2 million was released back to us for a reduction in RCEs to be acquired.

As part of the acquisitions, we funded an escrow account, the balance of which is reflected as restricted cash in our consolidated balance sheet. As we acquire customers, we make payments to the sellers from the escrow account. As of September 30, 2021, the balance in the escrow account was $8.7 million, and these funds are expected to be released to the sellers as acquired customers transfer from the sellers to the Company in accordance with the asset purchase agreement, and any unallocated balance will be returned to the Company once the acquisition is complete.

In July 2021, we entered into an agreement to acquire up to approximately 50,000 RCEs and derivatives related to the customer load under a five-year contingent fee structure based on gas volume billed and collected for the acquired customer contracts. These customers will begin transferring in the fourth quarter of 2021, 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.
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16. Subsequent Events

Declaration of Dividends

On October 20, 2021, we declared a quarterly dividend of $0.18125 per share to holders of record of our Class A common stock on December 1, 2021, which will be paid on December 15, 2021.

On October 20, 2021, we also declared a quarterly cash dividend in the amount of $0.546875 per share to holders of record of the Series A Preferred Stock on January 3, 2022. The dividend will be paid on January 17, 2022.

Fifth Amendment to the Senior Credit Facility

On October 15, 2021, we entered into the Fifth Amendment to our Senior Credit Facility, which, among other things extended the maturity date to October 13, 2023, added a provision for Acquisition Loans (subject to limits as defined in the agreement), and terminated the provision allowing for Share Buyback Loans.

Amended and Restated Subordinated Promissory Note

In October 2021, we amended the Subordinated Debt Facility solely to extend the maturity date from January 31, 2023 to January 31, 2025.
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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 2020 Form 10-K filed with the Securities and Exchange Commission (“SEC”) on March 4, 2021. Results of operations and cash flows for the three and nine months ended September 30, 2021 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, 2021, we operated in 100 utility service territories across 19 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, 2021 and 2020, approximately 94% and 94%, 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, 2021 and 2020, approximately 6% and 6%, respectively, of our retail revenues were derived from the sale of natural gas.

Recent Developments

Company's Name Change

In August 2021, we changed our name from Spark Energy, Inc. to Via Renewables, Inc.

Senior Credit Facility Amendment

In October 2021, we entered into the Fifth Amendment to our Senior Credit Facility, which, among other things extended the maturity date to October 13, 2023, and terminated the provision for Share Buyback Loans as well as added a provision for loans to fund acquisitions ("Acquisition Loans"), subject to limits as defined in the Fifth Amendment. Refer to Note 9 "Debt" for further discussion.

COVID-19

The outbreak of the novel coronavirus ("COVID-19") adversely impacted economic activity and conditions worldwide. In response to the COVID-19 pandemic, we deployed a remote working strategy in March 2020 that enabled our employees to work from home, provided timely communication to team members, implemented protocols for team members' safety, and initiated strategies for monitoring and responding to local COVID-19 impacts. Our preparedness efforts, coupled with quick and decisive plan implementation, resulted in minimal
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impacts to our workforce. Our workforce resumed normal work schedules at our corporate headquarters in May 2021.

A slower than planned ramp-up of our door-to-door sales channels as COVID-19 restrictions have lifted has had the most significant adverse impact to our business, financial condition and results of operations during the quarter ended September 30, 2021. We are continuing to monitor developments involving customers and suppliers and the impact on our operations, business, financial condition, liquidity and results of operations for future periods.

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, 2021:

RCEs:
(In thousands) June 30, 2021 Additions Attrition September 30, 2021 % Increase (Decrease)
Retail Electricity 270 45 (22) 293 9%
Retail Natural Gas 77 2 (4) 75 (3)%
Total Retail 347 47 (26) 368 6%

RCEs:
(In thousands) December 31, 2020 Additions Attrition September 30, 2021 % Increase (Decrease)
Retail Electricity 303 74 (84) 293 (3)%
Retail Natural Gas 97 4 (26) 75 (23)%
Total Retail 400 78 (110) 368 (8)%
The following table details our count of RCEs by geographical location as of September 30, 2021:
RCEs by Geographic Location:
(In thousands) Electricity  % of Total Natural Gas  % of Total Total  % of Total
New England 102 36% 14 19% 116 32%
Mid-Atlantic 89 30% 22 29% 111 30%
Midwest 29 10% 23 30% 52 14%
Southwest 73 24% 16 22% 89 24%
Total 293 100% 75 100% 368 100%

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 and Pennsylvania;
•Midwest - Illinois, Indiana, Michigan and Ohio; and
•Southwest - Arizona, California, Colorado, Florida, Nevada and Texas.

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Across our market areas, we have operated under a number of different retail brands. We currently operate under six retail brands. During 2020 and 2019, we consolidated certain brands and billing systems in an effort to simplify our business operations where practical.

Drivers of Our Business

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

Customer Growth

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

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.

Due to the COVID-19 pandemic, certain public utility commissions, regulatory agencies, and other governmental authorities in most of our markets maintained orders prohibiting energy services companies from door-to-door marketing and in some cases telemarketing during the pandemic, which restricted some of the sales channels we have historically used to market for organic sales. In response, we focused on development of products and channels, partners for web sales, as well as accelerating our telemarketing sales quality programs. In November 2020, we began active door-to-door marketing activities as COVID-19 restrictions were lifted.

During the three months ended September 30, 2021, we added approximately 19,000 RCEs primarily through our various organic sales channels. We expect to acquire customers organically in future periods but it will be slower in the near term, however we expect this number to increase on a monthly basis.

During the three months ended September 30, 2021, we added approximately 28,000 RCEs as a result of a series of asset purchase agreements entered in May 2021. Refer to Note 15 “Customer Acquisitions” for further discussion. 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 2021.

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
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opportunities to acquire customers through acquisitions and pursue such acquisitions when it makes sense economically or strategically.

As described above, during the COVID-19 pandemic certain public utility commissions, regulatory agencies, and other governmental authorities in all of our markets issued orders that impacted the way we have historically acquired customers prior to the COVID-19 pandemic, such as door to door marketing. Our gradual increase of marketing efforts as restrictions have been lifted resulted in increased marketing and customer acquisition costs during the three months ended September 30, 2021, when compared to the three months ended September 30, 2020, although still lower compared to historical amounts. We are incurring costs related to other manners of marketing, such as online marketing.

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, 2021 and 2020 was 2.4% and 3.0%, respectively.

Our customer attrition was slightly lower than the prior year because of our pro-active non-renewal of some of the larger C&I customers in the prior year, which did not re-occur in 2021. Although customer attrition was slightly lower during the third quarter of 2021, we are unable to predict the ultimate impact on overall customer attrition over the next three months, at this time.

Customer Credit Risk

Our bad debt expense for the three months ended September 30, 2021 and 2020 was 0.8% and 0.9%, respectively, and our bad debt expense for the nine months ended September 30, 2021 and 2020 was 0.04% and 2.0% respectively, for non-purchase of receivable market ("non-POR") revenues. An increased focus on collection efforts, timely billing and credit monitoring for new enrollments in non-POR markets beginning in late 2020 have led to an improvement in the bad debt expense over the past several months, including the three months ended September 30, 2021. We have also been able to collect on debts that were previously written off, which has further reduced our bad debt expense during the three and nine months ended September 30, 2021.

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.

Winter Storm Uri

During the first quarter of 2021, the U.S. experienced Winter Storm Uri, an unprecedented storm bringing extreme cold temperatures to the central U.S., including Texas. As a result of increased power demand for customers across the state of Texas and power generation disruptions during the weather event, power and ancillary costs in the ERCOT service area reached or exceeded maximum allowed clearing prices. As of September 30, 2021, we
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recorded a net loss of approximately $64.4 million as a direct result of Winter Storm Uri. Although our hedge position was 120% of our forecasted demand in Texas for the month of February, we were still required to purchase power at unprecedented prices for an extended period of time during the storm. These price caps imposed by ERCOT for the duration of the storm and beyond have never been experienced in any deregulated market in which we serve. The policies imposed on the electricity markets by ERCOT related to pricing resulted in overall negative impact on our electricity unit margin for 2021.

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 $0.3 million and $0.6 million for the three months ended September 30, 2021 and 2020, 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) 2021 2020 2021 2020
Adjusted EBITDA (1)
$ 22,019  $ 27,749  $ 69,058  $ 81,897 
Retail Gross Margin (2)
$ 30,870  $ 47,031  $ 107,322  $ 147,486 
(1) Adjusted EBITDA for the nine months ended September 30, 2021 includes a $60.0 million add back related to Winter Storm Uri and includes a deduction of $2.2 million non-recurring legal settlement related to an add back in 2019. See discussion below.
(2) Retail Gross Margin for the three months ended September 30, 2021 includes a $0.5 million reduction related to the Winter Storm Uri credit settlements received and nine months ended September 30, 2021 includes a $64.4 million add back related to Winter Storm Uri. See 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.
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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. 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. We will present any credits received related to the storm exceeding $4.9 million as a reduction of the related $60.0 million non-recurring add back to Adjusted EBITDA for consistent presentation. There are no assurances credits will be received.

We believe that the presentation of Adjusted EBITDA provides information useful to investors in assessing our performance and results of operations and that Adjusted EBITDA is also useful for an understanding of our financial condition and/or liquidity due to its use in covenants in our Senior Credit Facility. 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) 2021 2020 2021 2020
Reconciliation of Adjusted EBITDA to net income:
Net income $ 34,657  $ 22,606  $ 31,893  $ 59,451 
Depreciation and amortization 5,049  7,278  16,498  24,084 
Interest expense 1,298  1,487  4,161  4,233 
Income tax expense 7,021  5,141  9,160  12,739 
EBITDA
48,025  36,512  61,712  100,507 
Less:
Net, gain (loss) on derivative instruments 31,798  2,451  57,726  (14,015)
Net cash settlements on derivative instruments (5,660) 6,425  (6,050) 32,997 
Customer acquisition costs 309  207  765  1,762 
       Plus:
       Non-cash compensation expense 441  320  2,012  2,134 
Non-recurring event - Winter Storm Uri —  —  60,000  — 
Non-recurring legal settlement —  —  (2,225) — 
Adjusted EBITDA $ 22,019  $ 27,749  $ 69,058  $ 81,897 
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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) 2021 2020 2021 2020
Reconciliation of Adjusted EBITDA to net cash provided in operating activities:
Net cash provided by operating activities $ 9,604  $ 12,165  $ 18,772  $ 83,948 
Amortization of deferred financing costs (275) (476) (792) (966)
Bad debt expense (492) (880) (379) (4,613)
Interest expense 1,298  1,487  4,161  4,233 
Income tax expense 7,021  5,141  9,160  12,739 
Non-recurring event - Winter Storm Uri —  —  60,000  — 
Non-recurring legal settlement —  —  (2,225) — 
Changes in operating working capital
Accounts receivable, prepaids, current assets 6,456  1,709  (25,305) (48,301)
Inventory 1,448  823  1,048  (1,158)
Accounts payable and accrued liabilities 2,952  9,374  15,809  39,213 
Other (5,993) (1,594) (11,191) (3,198)
Adjusted EBITDA $ 22,019  $ 27,749  $ 69,058  $ 81,897 
Cash Flow Data:
Net cash provided by operating activities $ 9,604  $ 12,165  $ 18,772  $ 83,948 
Net cash used in investing activities $ (2,626) $ (640) $ (3,689) $ (1,219)
Net cash (used in) provided by financing activities $ (13,399) $ (15,769) $ 11,352  $ (65,017)

Retail Gross Margin. We define retail gross margin as operating income (loss) plus (i) depreciation and amortization expenses and (ii) general and administrative expenses, less (iii) net asset optimization revenues (expenses), (iv) net gains (losses) on non-trading derivative instruments, (v) net current period cash settlements on non-trading derivative instruments and (vi) 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, operating income (loss), 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. We received credits totaling $0.5 million related to Winter Storm Uri costs in the third quarter of 2021, which is included in the calculation of retail gross margin for consistent presentation.

The GAAP measure most directly comparable to Retail Gross Margin is operating income (loss). The following table presents a reconciliation of Retail Gross Margin to operating income (loss) for each of the periods indicated.
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   Three Months Ended September 30, Nine Months Ended September 30,
(in thousands) 2021 2020 2021 2020
Reconciliation of Retail Gross Margin to Operating income:
Operating income $ 42,913  $ 29,154  $ 44,986  $ 76,130 
Plus:
Depreciation and amortization 5,049  7,278  16,498  24,084 
General and administrative expense 9,719  19,080  33,053  66,087 
Less:
Net asset optimization (expense) revenue (288) (558) (542) (319)
Gain (loss) on non-trading derivative instruments 32,262  2,550  58,214  (14,019)
Cash settlements on non-trading derivative instruments (5,660) 6,489  (6,054) 33,153 
Non-recurring event - Winter Storm Uri 497  —  (64,403) — 
Retail Gross Margin $ 30,870  $ 47,031  $ 107,322  $ 147,486 
Retail Gross Margin - Retail Electricity Segment (1)
$ 28,213  $ 42,762  $ 80,478  $ 109,141 
Retail Gross Margin - Retail Natural Gas Segment $ 2,657  $ 4,269  $ 26,844  $ 38,345 
(1) Retail Gross Margin for the three months ended September 30, 2021 includes a $0.5 million reduction related to the Winter Storm Uri credit settlements received and nine months ended September 30, 2021 includes a $64.4 million add back related to Winter Storm Uri.

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 operating income (loss). 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 operating activities, and operating income (loss), 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.
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Consolidated Results of Operations

Three and Nine Months Ended September 30, 2021 Compared to Three and Nine Months Ended September 30, 2020
(In Thousands) Three Months Ended September 30, Nine Months Ended September 30,
2021 2020 2021 2020
Revenues:
Retail revenues $ 98,267  $ 141,188  $ 293,721  $ 436,166 
Net asset optimization (expense) revenue (288) (558) (542) (319)
Total Revenues 97,979  140,630  293,179  435,847 
Operating Expenses:
Retail cost of revenues 40,298  85,118  198,642  269,546 
General and administrative expense 9,719  19,080  33,053  66,087 
Depreciation and amortization 5,049  7,278  16,498  24,084 
Total Operating Expenses 55,066  111,476  248,193  359,717 
Operating income 42,913  29,154  44,986  76,130 
Other (expense)/income:
Interest expense (1,298) (1,487) (4,161) (4,233)
Interest and other income 63  80  228  293 
Total other expense (1,235) (1,407) (3,933) (3,940)
Income before income tax expense 41,678  27,747  41,053  72,190 
Income tax expense 7,021  5,141  9,160  12,739 
Net income $ 34,657  $ 22,606  $ 31,893  $ 59,451 
Other Performance Metrics:
  Adjusted EBITDA (1) (2)
$ 22,019  $ 27,749  $ 69,058  $ 81,897 
  Retail Gross Margin (1) (3)
$ 30,870  $ 47,031  $ 107,322  $ 147,486 
  Customer Acquisition Costs $ 309  $ 207  $ 765  $ 1,762 
  Average Monthly RCE Attrition 2.4  % 3.0  % 3.3  % 4.1  %
(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 months ended September 30, 2021 includes a $60.0 million add back related to Winter Storm Uri and a deduction of $2.2 million non-recurring legal settlement related to an add back in 2019.
(3) Retail Gross Margin for the three months ended September 30, 2021 includes a $0.5 million reduction related to the Winter Storm Uri credit settlements received and nine months ended September 30, 2021 includes a $64.4 million add back related to Winter Storm Uri.

Three Months Ended September 30, 2021 Compared to Three Months Ended September 30, 2020

Total Revenues. Total revenues for the three months ended September 30, 2021 were approximately $98.0 million, a decrease of approximately $42.6 million, or 30%, from approximately $140.6 million for the three months ended September 30, 2020, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity and natural gas volumes as a result of a smaller customer book in the third quarter of 2021 as compared to the third quarter of 2020.
Change in electricity volumes sold $ (44.3)
Change in natural gas volumes sold (2.1)
Change in electricity unit revenue per MWh 3.4 
Change in natural gas unit revenue per MMBtu 0.4 
Change in total revenues $ (42.6)

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Retail Cost of Revenues. Total retail cost of revenues for the three months ended September 30, 2021 was approximately $40.3 million, a decrease of approximately $44.8 million, or 53%, from approximately $85.1 million for the three months ended September 30, 2020, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity and natural gas volumes as a result of a smaller customer book in 2021 and a change in the fair value of our retail derivative portfolio.
Change in electricity volumes sold $ (30.0)
Change in natural gas volumes sold (1.2)
Change in electricity unit cost per MWh 3.7 
Change in electricity unit cost per MWh - Winter Storm Uri Credit (0.5)
Change in natural gas unit cost per MMBtu 0.7 
Change in value of retail derivative portfolio (17.5)
Change in retail cost of revenues $ (44.8)

General and Administrative Expense. General and administrative expense for the three months ended September 30, 2021 was approximately $9.7 million, a decrease of approximately $9.4 million, or 49%, as compared to $19.1 million for the three months ended September 30, 2020. This decrease was primarily attributable to lower employee costs, lower bad debt expense due to improved collection efforts and lower legal fees in the third quarter of 2021.

Depreciation and Amortization Expense. Depreciation and amortization expense for the three months ended September 30, 2021 was approximately $5.0 million, a decrease of approximately $2.3 million, or 32%, from approximately $7.3 million for the three months ended September 30, 2020. 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, 2021 was approximately $0.3 million, an increase of $0.1 million, or 49%, from approximately $0.2 million for the three months ended September 30, 2020 primarily due to increased sales activity in the third quarter of 2021 as compared to third quarter of 2020. The low customer acquisition cost in both periods was primarily due to limitation on our ability to use door-to-door marketing as a result of COVID-19 and a reduction in targeted organic customer acquisitions as we focus our efforts to improve our organic sales channels, including vendor selection and sales quality.
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Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

Total Revenues. Total revenues for the nine months ended September 30, 2021 were approximately $293.2 million, a decrease of approximately $142.6 million, or 33%, from approximately $435.8 million for the nine months ended September 30, 2020, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity and natural gas volumes due to a smaller customer book in 2021 as compared to 2020, partially offset by an increase in electricity unit revenue per MWh.
Change in electricity volumes sold $ (138.6)
Change in natural gas volumes sold (20.5)
Change in electricity unit revenue per MWh 13.2 
Change in electricity unit revenue per MMBtu - Winter Storm Uri 0.9 
Change in natural gas unit revenue per MMBtu 2.5 
Change in net asset optimization revenue (expense) (0.1)
Change in total revenues $ (142.6)

Retail Cost of Revenues. Total retail cost of revenues for the nine months ended September 30, 2021 was approximately $198.6 million, a decrease of approximately $70.9 million, or 26%, from approximately $269.5 million for the nine months ended September 30, 2020, as indicated in the table below (in millions). This decrease was primarily due to a decrease in electricity and natural gas volumes as a result of a smaller customer book in 2021, a decrease due to change in fair value of our retail derivative portfolio, offset by an increase in electricity and natural gas unit cost, as well as an increase in electricity supply costs due to Winter Storm Uri in the first quarter of 2021.
Change in electricity volumes sold $ (97.4)
Change in natural gas volumes sold (9.2)
Change in electricity unit cost per MWh 0.8 
Change in electricity unit cost per MWh - Winter Storm Uri 65.3 
Change in natural gas unit cost per MMBtu 2.6 
Change in value of retail derivative portfolio (33.0)
Change in retail cost of revenues $ (70.9)

General and Administrative Expense. General and administrative expense for the nine months ended September 30, 2021 was approximately $33.1 million, a decrease of approximately $33.0 million, or 50%, as compared to $66.1 million for the nine months ended September 30, 2020. This decrease was primarily attributable to lower employee costs, lower bad debt expense in 2021 due to improved collection efforts and lower legal costs.

Depreciation and Amortization Expense. Depreciation and amortization expense for the nine months ended September 30, 2021 was approximately $16.5 million, a decrease of approximately $7.6 million, or 32%, from approximately $24.1 million for the nine months ended September 30, 2020. 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, 2021 was approximately $0.8 million, a decrease of approximately $1.0 million, or 57%, from approximately $1.8 million for the nine months ended September 30, 2020. This decrease was primarily due to limitation on our ability to use door-to-door marketing as a result of COVID-19 during most of 2020 and 2021 and a reduction in targeted organic customer acquisitions as we focus our efforts to improve our organic sales channels, including vendor selection and sales quality.
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Operating Segment Results
(in thousands, except volume and per unit operating data) Three Months Ended September 30, Nine Months Ended September 30,
   2021 2020 2021 2020
Retail Electricity Segment
Total Revenues $ 92,104  $ 132,958  $ 242,548  $ 366,981 
Retail Cost of Revenues 41,035  82,061  179,762  241,712 
Less: Net gain on non-trading derivatives, net of cash settlements 22,359  8,135  46,711  16,128 
Non-recurring event - Winter Storm Uri 497  —  (64,403) — 
Retail Gross Margin (1) — Electricity
$ 28,213  $ 42,762  $ 80,478  $ 109,141 
Volumes — Electricity (MWhs) (3)
777,340  1,165,500  2,013,468  3,235,222 
Retail Gross Margin (2) (4) — Electricity per MWh
$ 36.29  $ 36.69  $ 39.97  $ 33.74 
Retail Natural Gas Segment
Total Revenues $ 6,163  $ 8,230  $ 51,173  $ 69,185 
Retail Cost of Revenues (737) 3,057  18,880  27,834 
Less: Net gain on non-trading derivatives, net of cash settlements 4,243  904  5,449  3,006 
Retail Gross Margin (1) — Gas
$ 2,657  $ 4,269  $ 26,844  $ 38,345 
Volumes — Gas (MMBtus) 668,063  949,088  5,765,588  8,198,827 
Retail Gross Margin (2) — Gas per MMBtu
$ 3.98  $ 4.50  $ 4.66  $ 4.68 

(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.
(3) Excludes volumes (8,402 MWhs) related to Winter Storm Uri impact for the nine months ended September 30, 2021.
(4) Retail Gross Margin - Electricity per MWh excludes Winter Storm Uri impact.

Three Months Ended September 30, 2021 Compared to Three Months Ended September 30, 2020
Retail Electricity Segment
Total revenues for the Retail Electricity Segment for the three months ended September 30, 2021 were approximately $92.1 million, a decrease of approximately $40.9 million, or 31%, from approximately $133.0 million for the three months ended September 30, 2020. This decrease was largely due to lower volumes sold, resulting in a decrease of $44.3 million as a result of a smaller customer book in 2021, offset by higher retail electricity prices which resulted in an increase of $3.4 million.
Retail cost of revenues for the Retail Electricity Segment for the three months ended September 30, 2021 were approximately $41.0 million, a decrease of approximately $41.1 million, or 50%, from approximately $82.1 million for the three months ended September 30, 2020. This decrease was primarily due to fewer customers, resulting in a decrease of $30.0 million, an increase in supply costs of $3.2 million, and a change in the value of our retail derivative portfolio used for hedging, which resulted in a decrease of $14.3 million.
Retail gross margin for the Retail Electricity Segment for the three months ended September 30, 2021 was approximately $28.2 million, a decrease of approximately $14.5 million, or 34%, from approximately $42.8 million for the three months ended September 30, 2020, as indicated in the table below (in millions).
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Change in volumes sold $ (14.3)
Change in unit margin per MWh 0.2 
Change in electricity unit cost per MWh - Winter Storm Uri Credit (0.5)
Change in retail electricity segment retail gross margin $ (14.6)
Retail Natural Gas Segment
Total revenues for the Retail Natural Gas Segment for the three months ended September 30, 2021 were approximately $6.2 million, a decrease of approximately $2.0 million, or 25%, from approximately $8.2 million for the three months ended September 30, 2020. This decrease was primarily attributable to lower volumes sold, which decreased total revenues by $2.4 million offset by an increase of $0.4 million related to higher natural gas rates.
Retail cost of revenues for the Retail Natural Gas Segment for the three months ended September 30, 2021 were approximately $(0.7) million, a decrease of $3.8 million, or 124%, from approximately $3.1 million for the three months ended September 30, 2020. This decrease was primarily due to lower volumes resulting in a decrease of $1.2 million, higher natural gas costs, which resulted in an increase of $0.7 million, and a change in the value of our derivative portfolio used for hedging, which resulted in a decrease of $3.3 million.
Retail gross margin for the Retail Natural Gas Segment for the three months ended September 30, 2021 was approximately $2.7 million, a decrease of approximately $1.6 million, or 38%, from approximately $4.3 million for the three months ended September 30, 2020, as indicated in the table below (in millions).
Change in volumes sold $ (1.3)
Change in unit margin per MMBtu (0.3)
Change in retail natural gas segment retail gross margin $ (1.6)

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Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020
Retail Electricity Segment
Total revenues for the Retail Electricity Segment for the nine months ended September 30, 2021 were approximately $242.5 million, a decrease of approximately $124.5 million, or 34%, from approximately $367.0 million for the nine months ended September 30, 2020. This decrease was largely due to a decrease in volumes, resulting in a decrease of $138.6 million. This was partially offset by higher weighted average revenue rates, due to our customer mix shifting away from large commercial customers, which resulted in an increase of $13.2 million and an increase of $0.9 million related to electricity revenue due to Winter Storm Uri.
Retail cost of revenues for the Retail Electricity Segment for the nine months ended September 30, 2021 was approximately $179.8 million, a decrease of approximately $61.9 million, or 26%, from approximately $241.7 million for the nine months ended September 30, 2020. This decrease was primarily due to a decrease in volumes, resulting in a decrease of $97.4 million. This decrease was further impacted by increased electricity prices, which resulted in an increase in retail cost of revenues of $0.8 million and a decrease of $30.7 million due to a change in the value of our retail derivative portfolio used for hedging. This was offset by an increase in supply cost of $65.3 million related to Winter Storm Uri.
Retail gross margin for the Retail Electricity Segment for the nine months ended September 30, 2021 was approximately $80.5 million, a decrease of approximately $28.6 million, or 26%, from approximately $109.1 million for the nine months ended September 30, 2020, as indicated in the table below (in millions).
Change in volumes sold $ (41.2)
Change in gross margin - Winter Storm Uri 64.4 
Change in unit margin per MWh (51.8)
Change in retail electricity segment retail gross margin $ (28.6)
Retail Natural Gas Segment
Total revenues for the Retail Natural Gas Segment for the nine months ended September 30, 2021 were approximately $51.2 million, a decrease of approximately $18.0 million, or 26%, from approximately $69.2 million for the nine months ended September 30, 2020. This decrease was primarily attributable to a decrease in volumes of $20.5 million, partially offset by higher rates, which resulted in an increase in total revenues of $2.5 million.
Retail cost of revenues for the Retail Natural Gas Segment for the nine months ended September 30, 2021 was approximately $18.9 million, a decrease of approximately $8.9 million, or 32%, from approximately $27.8 million for the nine months ended September 30, 2020. The decrease of $9.2 million was related to lower volumes and a decrease of $2.3 million due to a change in the value of our derivative portfolio used for hedging, offset by increased supply costs of $2.6 million.
Retail gross margin for the Retail Natural Gas Segment for the nine months ended September 30, 2021 was approximately $26.8 million, a decrease of approximately $11.5 million, or 30%, from approximately $38.3 million for the nine months ended September 30, 2020, as indicated in the table below (in millions).
Change in volumes sold $ (11.5)
Change in unit margin per MMBtu — 
Change in retail natural gas segment retail gross margin $ (11.5)
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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, service debt and pay dividends. Our liquidity requirements fluctuate with our level of customer acquisition costs, acquisitions, collateral posting requirements on our derivative instruments portfolio, distributions, the effects of the timing between the settlement of payables and receivables, including the effect of bad debts, weather conditions, and our general working capital needs for ongoing operations. We believe that cash generated from operations and our available liquidity sources will be sufficient to sustain current operations and to pay required taxes and quarterly cash distributions, including the quarterly dividends to the holders of the Class A common stock and the Series A Preferred Stock, for the next twelve months. Estimating our liquidity requirements is highly dependent on then-current market conditions, including impacts of the COVID-19 pandemic, Winter Storm Uri, forward prices for natural gas and electricity, market volatility and our then existing capital structure and requirements.

Liquidity Position

The following table details our available liquidity as of September 30, 2021:
($ in thousands) September 30, 2021
Cash and cash equivalents $ 89,422 
Senior Credit Facility Availability (1)
30,121 
Subordinated Debt Facility Availability (2)
15,000 
Total Liquidity $ 134,543 
(1) Reflects amount of Letters of Credit that could be issued based on existing covenants as of September 30, 2021.
(2) The availability of the Subordinated Facility is dependent on our Founder's willingness and ability to lend. See "—Sources of Liquidity —Subordinated Debt Facility."

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

Cash Flows

Our cash flows were as follows for the respective periods (in thousands):
   Nine Months Ended September 30,
   2021 2020
Net cash provided by operating activities $ 18,772  $ 83,948 
Net cash used in investing activities $ (3,689) $ (1,219)
Net cash provided (used) in financing activities $ 11,352  $ (65,017)

Nine Months Ended September 30, 2021 Compared to the Nine Months Ended September 30, 2020

Cash Flows Provided by Operating Activities. Cash flows provided by operating activities for the nine months ended September 30, 2021 decreased by $65.2 million compared to the nine months ended September 30, 2020. The decrease was primarily the result of the non-recurring Winter Storm Uri related costs of $64.4 million for the nine months ended September 30, 2021.

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Cash Flows Used in Investing Activities. Cash flows used in investing activities increased by $2.5 million for the nine months ended September 30, 2021. The increase was primarily the result of increased capital spending and increases relating to customer acquisitions during the nine months ended September 30, 2021.

Cash Flows Provided by Financing Activities. Cash flows provided by financing activities increased by $76.4 million for the nine months ended September 30, 2021, primarily due to an increase in net borrowings under our Senior Credit Facility of $53.0 million and an increase in sub-debt borrowing of $10.0 million during the nine months ended September 30, 2021.

Sources of Liquidity and Capital Resources

Senior Credit Facility

As of September 30, 2021, we had total commitments of $227.5 million under the Senior Credit Facility, of which $154.4 million was outstanding, including $24.4 million of outstanding letters of credit, with a maturity date of July 31, 2022. On October 15, 2021, we entered into the Fifth Amendment to the Senior Credit Facility, which, among other things extended the maturity date to October 2023, added a provision for Acquisition Loans (subject to limits as defined in the agreement), and terminated the provision allowing for Share Buyback Loans. See Note 9 "Debt" for further discussion.

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, 2021, we were in compliance with the covenants under our Senior Credit Facility. Based upon existing covenants as of September 30, 2021, we had availability to borrow up to $30.1 million under the Senior Credit Facility.

Amended and Restated Subordinated Debt Facility

Our Subordinated Debt Facility allows us to draw advances in increments of no less than $1.0 million per advance up to $25.0 million. 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, 2021, there was $10.0 million outstanding borrowings under the Subordinated Debt Facility, and availability to borrow up to $15.0 million under the Subordinated Debt Facility. In October 2021, we amended the Subordinated Debt Facility solely to extend the maturity date from January 31, 2023 to January 31, 2025. See Note 9 "Debt" for further information regarding the extension of the Subordinated Debt Facility.

Uses of Liquidity and Capital Resources

Repayment of Current Portion of Senior Credit Facility

Our Senior Credit Facility, as amended by the Fifth Amendment, matures in October 2023, 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, 2021 was $130.0 million. The current variable interest rate on the facility at September 30, 2021 was 3.75%.

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, 2021 and 2020, we spent a total of $0.3 million and $0.2 million, respectively, on organic customer acquisitions.

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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, 2021 and 2020 included $2.2 million and $1.2 million, respectively, related to information systems improvements.

Dividends and Distributions

During the nine months ended September 30, 2021, we paid dividends to holders of our Class A common stock for the quarter ended December 31, 2020 of $0.18125 per share or $8.2 million in the aggregate. In order to 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 Class B common stock (our non-controlling interest holders). As a result, during the nine months ended September 30, 2021, Spark HoldCo made distributions of $11.2 million to our non-controlling interest holders related to the dividend payments to holders of our Class A common stock.

For the nine months ended September 30, 2021, we paid $1.9 million of dividends to holders of our Series A Preferred Stock, and as of September 30, 2021, we had accrued $2.0 million related to dividends to holders of our Series A Preferred Stock, which we paid on October 15, 2021. For the full year ended December 31, 2021, at the stated dividend rate of the Series A Preferred Stock of $2.1875 per share, we would be required to pay dividends of $7.9 million in the aggregate based on the Series A Preferred Stock outstanding as of September 30, 2021.

On October 20, 2021, our Board of Directors declared a quarterly cash dividend in the amount of $0.18125 per share to holders of our Class A common stock and $0.546875 per share for the Series A Preferred Stock for the third quarter of 2021. Dividends on Class A common stock will be paid on December 15, 2021 to holders of record on December 1, 2021, and Series A Preferred Stock dividends will be paid on January 17, 2022 to holders of record on January 3, 2022.

Our ability to pay dividends in the future will depend on many factors, including the performance of our business and restrictions under our Senior Credit Facility. If our business does not generate sufficient cash for Spark HoldCo to make distributions to us to fund our Class A common stock and Series A Preferred Stock dividends, we may have to borrow to pay such amounts. Further, even if our business generates cash in excess of our current annual dividend (of $0.725 per share on our Class A common stock), we may reinvest such excess cash flows in our business and not increase the dividends payable to holders of our Class A common stock. Our future dividend policy is within the discretion of our Board of Directors and will depend upon the results of our operations, our financial condition, capital requirements and investment opportunities.

Share Repurchase Program

On August 18, 2020, our Board of Directors authorized a share repurchase program of up to $20.0 million of Class A common stock through August 18, 2021. The share repurchase program was suspended in March 2021 pursuant to an agreement with lenders under our Senior Credit Facility and the provision providing for share repurchases in our Senior Credit Facility was removed as part of the October 2021 amendment to the facility (see discussion in Note 9 "Debt"). During the nine months ended September 30, 2021, we did not repurchase our Class A common stock. We do not expect share repurchases to be a use of liquidity and capital resources for the near term future.

Collateral Posting Requirements

Our contractual agreements with certain local regulated utilities and our supplier counterparties require us to maintain restricted cash balances or letters of credit as collateral for credit risk or the performance risk associated with the future delivery of natural gas or electricity. Due to the COVID-19 pandemic, certain local regulated utilities and our supplier counterparties have contacted us inquiring about our financial condition and the impact the pandemic is having on our operations. These inquiries may lead to additional requests for cash or letters of credit in an effort to mitigate the risk of default in paying our obligations related to the future delivery of natural gas or
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electricity. As of September 30, 2021, we had not been required to post additional collateral as a result of COVID-19.

As discussed above, during the Winter Storm Uri event, we were required to post a significant amount of collateral with ERCOT. Despite these posting requirements, we consistently maintained, and continue to maintain, sufficient liquidity to conduct our operations in the ordinary course. As of September 30, 2021, we had not been required to post additional collateral as a result of the Winter Storm Uri.

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Off-Balance Sheet Arrangements
As of September 30, 2021, 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 2020 Form 10-K. There have been no changes to these policies and estimates since the date of our 2020 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, 2021, 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.

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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 on our non-trading derivative instruments, net of cash settlements, was $26.6 million and $9.0 million for the three months ended September 30, 2021 and $52.2 million and $19.1 million for the nine months ended September 30, 2021 and 2020, 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 2020 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, 2021, our Gas Non-Trading Fixed Price Open Position (hedges net of retail load) was a long position of 236,616 MMBtu. An increase of 10% in the market prices (NYMEX) from their September 30, 2021 levels would have increased the fair market value of our net non-trading energy portfolio by less than $0.2 million. Likewise, a decrease of 10% in the market prices (NYMEX) from their September 30, 2021 levels would have decreased the fair market value of our non-trading energy derivatives by less than $0.2 million. As of September 30, 2021, our Electricity Non-Trading Fixed Price Open Position (hedges net of retail load) was a short position of 5,386 MWhs. An increase of 10% in the forward market prices from their September 30, 2021 levels would have decreased the fair market value of our net non-trading energy portfolio by $0.1 million. Likewise, a decrease of 10% in the forward market prices from their September 30, 2021 levels would have increased the fair market value of our non-trading energy derivatives by $0.1 million.

Credit Risk

In many of the utility services territories where we conduct business, Purchase of Receivables ("POR programs") have been established, whereby the local regulated utility purchases our receivables, and becomes responsible for billing the customer and collecting payment from the customer. These POR programs result in substantially all of our credit risk being with the utility and not to our end-use customers in these territories. Approximately 57% and 64% 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, 2021 and 2020 and 59% and 64% for the nine months ended September 30, 2021 and 2020, respectively, all of which had investment grade ratings as of such date. We paid these local regulated utilities a weighted average discount of 0.8% and 1.4%, for the three months ended
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September 30, 2021 and 2020, respectively, and 0.8% and 1.1% for the nine months ended September 30, 2021 and 2020, 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 to the extent the ability to terminate service has not been limited as a result of COVID-19. 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 (including impacts from COVID-19) 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, 2021 and 2020 was approximately 0.8% and 0.9% of non-POR market retail revenues, respectively, and our bad debt expense for the nine months ended September 30, 2021 and 2020 was approximately 0.04% and 2.0% 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, 2021.
The current COVID-19 pandemic has caused regulatory agencies and other governmental authorities to take, and potentially continue to take, emergency or other actions in light of the pandemic that may impact our customer credit risk, including prohibiting the termination of service for non-payment during the current COVID-19 pandemic, requiring deferred payment plans for certain customers unable to pay their bill, and utilities increasing POR fees they charge us in an effort to recoup their bad debts losses. Please see “Item 1A—Risk Factors” in our 2020 Form 10-K.
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, 2021, approximately $5.8 million of our total exposure of $34.5 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, 2021.
Interest Rate Risk
We are exposed to fluctuations in interest rates under our variable-price debt obligations. At September 30, 2021, we were co-borrowers under the Senior Credit Facility, under which $130.0 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, 2021, a 1% increase in interest rates would have resulted in additional annual interest expense of approximately $1.3 million.
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ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our Chief Executive Officer and our Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10-Q. The term “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, means controls and other procedures of a company that are designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving their objectives, and management necessarily applies its judgment in evaluating the cost benefit relationship of possible controls and procedures. Based on this evaluation, management concluded that our disclosure controls and procedures were effective as of September 30, 2021 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There was no change in our internal control over financial reporting identified in connection with the evaluation required by Rule 13a-15(d) and 15d-15(d) of the Exchange Act that occurred during the three months ended September 30, 2021 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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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 2020 Form 10-K. There has been no material change in our risk factors from those described in the 2020 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.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
There were no unregistered sales of equity securities during the three months ended September 30, 2021.


Item 5. Other Information.

Vendor Cybersecurity Incident

On November 1, 2021, we were informed by one of our vendors that we use for third party verification services that it was the target of a ransomware attack. We use third party verification services to review and confirm a customer’s non-financial information for accuracy at the time of enrollment. Upon learning of this event, we immediately worked with the vendor to confirm the nature and scope of the attack and the data at issue, including how it relates to our customers and operations. We are continuing to work with the third party vendor to gather facts and information about the incident. At this time and based on our investigation to date, (i) there has been no unauthorized access or data breach on our servers or information technology systems, and (ii) we have been informed by the vendor that its data has been encrypted by the third-party, but not removed. Therefore, we do not presently believe we will incur a material loss or impact to our operations associated with this cybersecurity incident. However, due to the evolving, ongoing and sensitive nature of this incident, we cannot provide any assurances to the ultimate outcome, and the incident may ultimately lead to litigation, fines, other remedial action, heightened regulatory scrutiny and regulatory proceedings, diminished customer confidence and damage to our reputation.

Management Changes

On November 2, 2021, the Company was notified by James G. Jones II of his intent to retire as Chief Financial Officer, effective as of November 4, 2021.

In connection with Mr. Jones retirement, the Company and Mr. Jones entered into a Transition and Resignation Agreement and Mutual Release of Claims (the “Transition Agreement”). Subject to the terms and conditions of the Transition Agreement, Mr. Jones will receive separation payments in the amount of $300,000.00, less ordinary withholding for federal income, Social Security, and Medicare taxes (the “Separation Payment”). The Separation Payment will be paid in twenty-six substantially equal bi-weekly installments, less applicable withholdings, in accordance with the Company’s normal payroll practices. The Transition Agreement also provides for the accelerated vesting 107,971 restricted stock units (“RSUs”) granted to Mr. Jones under the Company’s Amended and Restated Long-Term Incentive Plan, subject to the terms and conditions of the Transition Agreement and withholding of 42,487 shares of common stock to satisfy tax obligations.

The Transition Agreement also provides for a release by Mr. Jones of any claims against the Company, its affiliates and its agents, and affirmation of existing confidentiality, non-competition, non-solicitation and non-disparagement obligations, and other restrictive covenants, as set forth in Mr. Jones’s employment agreement with the Company.
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Within twenty-one days following the date of the Transition Agreement, and no later than November 25, 2021, Mr. Jones is required to execute a confirming release of claims (the “Confirming Release”). The Confirming Release may be revoked by Mr. Jones during the seven-day period beginning on the date Mr. Jones executes the Confirming Release.

The foregoing description of the Transition Agreement does not purport to be complete and is qualified in its entirety to the full text of the Transition Agreement, which is filed herewith as Exhibit 10.4 and is incorporated herein by reference.

On November 2, 2021, but effective November 4, 2021, the Company appointed Mike Barajas as Chief Financial Officer. Mr. Barajas, age 38, presently serves as our Vice President of Finance and Investor Relations. Prior to joining Via Renewables, Mr. Barajas served as director of accounting and reporting for NuDevco from April 2017 to September 2019, and as assistant controller from July 2015 to April 2017. Mr. Barajas holds a Master of Science in Accounting and a Bachelor of Business Administration in Accounting from the University of Houston. There are no understandings or arrangements between Mr. Barajas and any other person pursuant to which Mr. Barajas was selected to serve as Chief Financial Officer. There are no existing relationships between Mr. Barajas and any person that would require disclosure pursuant to Item 404(a) of Regulation S-K or any familial relationships that would require disclosure under Item 401(d) of Regulation S-K.

In connection with his appointment, the Company entered into an employment agreement, effective as of November 4, 2021 (the “Employment Agreement”), with Mr. Barajas. Pursuant to the Employment Agreement, Mr. Barajas will serve as Chief Financial Officer, and will receive an annual base salary of $250,000, as adjusted from time to time by the Company. The Employment Agreement provides for an initial term ending on December 31, 2022, and provides for subsequent one-year renewals unless either party gives at least 30 days prior notice to the end of the then existing term.

The Employment Agreement provides that, in the event Mr. Barajas is terminated by the Company other than for “Cause” or Mr. Barajas’s employment terminates due to either the Company’s election not to renew the term of the Employment Agreement or Mr. Barajas’s resignation for “Good Reason,” Mr. Barajas will, subject to execution of a release of claims, be entitled to receive the following payments and benefits:

•twelve months’ base salary plus an additional amount equal to Mr. Barajas’s target annual bonus for the year of termination pro-rated based upon the number of days Mr. Barajas was employed in the calendar year of termination and based upon the Company’s relative performance through such date of termination, payable in twelve substantially equal installments (the “Severance Payment”);
•any bonus earned for the calendar year prior to the year the termination occurs that is unpaid as of the date of termination (the “Post-Termination Bonus Payment”); and
•full vesting of any outstanding unvested awards held by Mr. Barajas under the Company’s Long Term Incentive Plan.

“Cause” under the Employment Agreement is generally defined to include: (a) a material uncured breach by Mr. Barajas of the Employment Agreement or any other material obligation owed to the Company, (b) commission of an act of gross negligence, willful misconduct, breach of fiduciary duty, fraud, theft or embezzlement, which has or can reasonably be expected to have an adverse effect on the Company, (c) any conviction, indictment or plea of nolo contendere with respect to any felony or any crime involving moral turpitude, (d) uncured willful failure or refusal to perform obligations pursuant to the Employment Agreement or uncured willful failure or refusal to follow the lawful instructions of the Company’s Board of Directors, and (e) any conduct which is materially injurious to the Company.

“Good Reason” under the Employment Agreement is generally defined to include (a) a material diminution in base salary, (b) a material diminution in title, duties, authority or responsibilities, (c) relocation of corporate offices by more than fifty miles, or (d) material and uncured breach of the Employment Agreement by the Company.

A non-renewal of the term of the Employment Agreement by Mr. Barajas, a termination by reason of Mr. Barajas’s death or disability, a termination by the Company for “Cause,” a termination of employment by Mr. Barajas without
62

“Good Reason,” or a separation in connection with a “Change in Control” described below, does not give rise to a right to the Severance Payment or Post-Termination Bonus Payment.

If within 120 days prior to execution of a definitive agreement for a “Change in Control” transaction and 365 days after consummation or final closing of such transaction, Mr. Barajas’s employment is terminated by the Company other than for “Cause” or Mr. Barajas’s employment terminates due to either the Company’s election not to renew the term of the Employment Agreement or Mr. Barajas’s resignation for “Good Reason,” subject to execution of a release of claims and other conditions, Mr. Barajas is entitled to receive the following payments and benefits:

•a lump sum payment equal to 1.0 times Mr. Barajas’s base salary then in effect, and the full target annual bonus for the year the termination occurs, and payable within 15 days following the date the employment is terminated;
•any bonus earned for the calendar year prior to the year the termination occurs that is unpaid as of the date of termination, payable within 15 days following the date the employment is terminated;
•a pro rata target annual bonus for the year of termination, calculated based upon relative achievement through such date and payable within 15 days following the date in which employment is terminated;
•full vesting of any outstanding awards held by Mr. Barajas under the Company’s Long Term Incentive Plan; and
•reimbursement or payment of certain continuing health benefits, if elected by Mr. Barajas.

The Employment Agreement generally defines “Change in Control” to mean:

•the consummation of an agreement to acquire or a tender offer for beneficial ownership by any person, of 50% or more of the combined voting power of the Company’s outstanding voting securities entitled to vote generally in the election of directors, or by any person of 90% or more of the then total outstanding shares of Class A common stock;
•individuals who constitute the incumbent board cease for any reason to constitute at least a majority of the Board;
•consummation of certain reorganizations, mergers or consolidations or a sale or other disposition of all or substantially all of the Company’s assets;
•approval by the Company’s shareholders of a complete liquidation or dissolution;
•a public offering or series of public offerings by Retailco and its affiliates, as a selling shareholder group, in which their total interest drops below 10 million of the Company’s total outstanding voting securities;
•a disposition by Retailco and its affiliates in which their total interest drops below 10 million of the Company’s total outstanding voting securities; or
•any other business combination, liquidation event of Retailco and its affiliates or restructuring of the Company that the Compensation Committee deems in its discretion to achieve the principles of a Change in Control.

The Employment Agreement also provides for noncompetition and nonsolicitation covenants that are in effect during the period of Mr. Barajas’s employment and for a period of 12 months thereafter, and customary provisions regarding the return of property.

In connection with his appointment and pursuant to the Employment Agreement, the Board approved a grant of 10,000 RSUs with dividend equivalent rights to Mr. Barajas. The RSUs vest as follows: (1) 25% on May 18, 2022, (2) 25% on May 18, 2023, (3) 25% on May 18, 2024 and (4) 25% on May 18, 2025. The grant of RSUs will be made pursuant to the Company’s Form of Restricted Stock Unit Agreement and Form of Notice of Grant of Restricted Stock Unit.

The foregoing description of the Employment Agreement does not purport to be complete and is qualified in its entirety to the full text of the Employment Agreement, which is filed herewith as Exhibit 10.5 and is incorporated herein by reference.
63

Item 6. Exhibits

The exhibits required to be filed by Item 6 are set forth in the Exhibit Index included below.
64

INDEX TO EXHIBITS
   Incorporated by Reference
Exhibit Exhibit Description Form Exhibit Number Filing Date SEC File No.
2.1# 10-Q 2.1 5/5/2016 001-36559
2.2# 10-Q 2.2 5/5/2016 001-36559
2.3# 8-K 2.1 8/1/2016 001-36559
2.4# 10-Q 2.4 5/8/2017 001-36559
2.5 8-K 2.1 7/6/2017 001-36559
2.6# 8-K 2.1 1/16/2018 001-36559
2.7# 10-K 2.7 3/9/2018 001-36559
2.8# 8-K 2.1 10/25/2018 001-36559
2.9 10-Q 2.9 8/5/2020 001-36559
3.1*
3.2 8-K 3.1 8/9/2021 001-36559
3.3 8-A 5 3/14/2017 001-36559
4.2 S-1 4.1 6/30/2014 333-196375
10.1# 8-K 10.1 10/21/2021 001-36559
10.2 8-K 10.2 10/21/2021 001-36559
10.3*†
65

10.4*†
10.5*†
31.1*
31.2*
32**
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
† 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 4, 2021 /s/ James G. Jones II
James G. Jones II
Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)


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