10-Q 1 a2017-q1x10q.htm 10-Q

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

|  | FORM 10-Q |  |

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2017
o 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
Spark Energy, 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)
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 x No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).
Yes x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 o Accelerated filer x
Non-accelerated filer o (Do not check if a smaller reporting company) Smaller reporting company o
Emerging Growth Company x
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. x
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes o No x
There were 6,499,504 shares of Class A common stock, 10,742,563 shares of Class B common stock and 1,610,000 shares of Series A Preferred stock outstanding as of May 5, 2017.

PART I. FINANCIAL INFORMATION |  |
ITEM 1. FINANCIAL STATEMENTS |  |
CONDENSED CONSOLIDATED BALANCE SHEETS AS OF MARCH 31, 2017 AND DECEMBER 31, 2016 (unaudited) |  | 2
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME FOR THE THREE MONTHS ENDED MARCH 31, 2017 AND 2016 (unaudited) |  | 3
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY FOR THE THREE MONTHS ENDED MARCH 31, 2017 (unaudited) |  | 4
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE THREE MONTHS ENDED MARCH 31, 2017 AND 2016 (unaudited) |  | 5
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited) |  | 6
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS |  | 40
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK |  | 63
ITEM 4. CONTROLS AND PROCEDURES |  | 65
PART II. OTHER INFORMATION |  | 66
ITEM 1. LEGAL PROCEEDINGS |  | 66
ITEM 1A. RISK FACTORS |  | 67
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS |  | 70
ITEM 3. DEFAULTS UPON SENIOR SECURITIES |  | 70
ITEM 4. MINE SAFETY DISCLOSURES |  | 70
ITEM 5. OTHER INFORMATION |  | 71
ITEM 6. INDEX TO EXHIBITS |  | 72
APPENDIX A |  | 73
SIGNATURES |  | 74

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PART 1. — FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
SPARK ENERGY, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
AS OF MARCH 31, 2017 AND DECEMBER 31, 2016
(in thousands)
(unaudited)

| March 31, 2017 |  | December 31, 2016
Assets |  |  |
Current assets: |  |  |
Cash and cash equivalents | $ | 24,931 |  |  | $ | 18,960 |
Accounts receivable, net of allowance for doubtful accounts of $2.4 million and $2.3 million as of March 31, 2017 and December 31, 2016, respectively | 108,754 |  |  | 112,491 |
Accounts receivable—affiliates | 2,013 |  |  | 2,624 |
Inventory | 430 |  |  | 3,752 |
Fair value of derivative assets | 2,388 |  |  | 8,344 |
Customer acquisition costs, net | 18,515 |  |  | 18,834 |
Customer relationships, net | 12,474 |  |  | 12,113 |
Prepaid assets | 2,319 |  |  | 1,361 |
Deposits | 6,264 |  |  | 7,329 |
Other current assets | 13,595 |  |  | 12,175 |
Total current assets | 191,683 |  |  | 197,983 |
Property and equipment, net | 4,389 |  |  | 4,706 |
Fair value of derivative assets | — |  |  | 3,083 |
Customer acquisition costs, net | 8,776 |  |  | 6,134 |
Customer relationships, net | 18,537 |  |  | 21,410 |
Deferred tax assets | 54,335 |  |  | 55,047 |
Goodwill | 79,407 |  |  | 79,147 |
Other assets | 8,690 |  |  | 8,658 |
Total assets | $ | 365,817 |  |  | $ | 376,168 |
Liabilities, Series A Preferred Stock and Stockholders' Equity |  |  |
Current liabilities: |  |  |
Accounts payable | $ | 40,315 |  |  | $ | 52,309 |
Accounts payable—affiliates | 3,217 |  |  | 3,775 |
Accrued liabilities | 40,022 |  |  | 36,619 |
Fair value of derivative liabilities | 1,723 |  |  | 680 |
Current portion of Senior Credit Facility | 22,236 |  |  | 51,287 |
Current contingent consideration for acquisitions | 12,103 |  |  | 11,827 |
Current portion of note payable | 8,185 |  |  | 15,501 |
Convertible subordinated notes to affiliates | — |  |  | 6,582 |
Other current liabilities | 2,230 |  |  | 5,476 |
Total current liabilities | 130,031 |  |  | 184,056 |
Long-term liabilities: |  |  |  |  |
Fair value of derivative liabilities | 4,964 |  |  | 68 |
Payable pursuant to tax receivable agreement—affiliates | 49,886 |  |  | 49,886 |
Subordinated debt—affiliate | — |  |  | 5,000 |
Deferred tax liability | 139 |  |  | 938 |
Contingent consideration for acquisitions | 4,083 |  |  | 10,826 |
Other long-term liabilities | 1,333 |  |  | 1,658 |
Total liabilities | 190,436 |  |  | 252,432 |
Commitments and contingencies (Note 12) |  |  |  |  |
Series A Preferred Stock, par value $0.01 per share, 20,000,000 shares authorized, 1,610,000 shares issued and outstanding at March 31, 2017 and zero shares issued and outstanding at December 31, 2016 | 38,346 |  |  | — |
Stockholders' equity: |  |  |  |  |
Common Stock: |  |  |  |  |
Class A common stock, par value $0.01 per share, 120,000,000 shares authorized, 6,499,504 issued and outstanding at March 31, 2017 and 6,496,559 issued and outstanding at December 31, 2016 | 65 |  |  | 65 |
Class B common stock, par value $0.01 per share, 60,000,000 shares authorized, 10,742,563 issued and outstanding at March 31, 2017 and 10,224,742 issued and outstanding at December 31, 2016 | 108 |  |  | 103 |
Additional paid-in capital | 33,812 |  |  | 25,413 |
Accumulated other comprehensive (income)/loss | (7 | ) |  | 11 |
Retained earnings | 4,625 |  |  | 4,711 |
Total stockholders' equity | 38,603 |  |  | 30,303 |
Non-controlling interest in Spark HoldCo, LLC | 98,432 |  |  | 93,433 |
Total equity | 137,035 |  |  | 123,736 |
Total liabilities, Series A Preferred Stock and stockholders' equity | $ | 365,817 |  |  | $ | 376,168 |

The accompanying notes are an integral part of the condensed consolidated financial statements.
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SPARK ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
FOR THE THREE MONTHS ENDED MARCH 31, 2017 AND 2016
(in thousands, except per share data)
(unaudited)

| Three Months Ended March 31,
| 2017 |  | 2016
Revenues: |  |  |
Retail revenues | $ | 194,539 |  |  | $ | 110,019 |
Net asset optimization (expense)/revenues (1) | (194 | ) |  | 527 |
Total Revenues | 194,345 |  |  | 110,546 |
Operating Expenses: |  |  |
Retail cost of revenues (2) | 143,698 |  |  | 68,800 |
General and administrative (3) | 24,377 |  |  | 17,380 |
Depreciation and amortization | 9,232 |  |  | 6,789 |
Total Operating Expenses | 177,307 |  |  | 92,969 |
Operating income | 17,038 |  |  | 17,577 |
Other (expense)/income: |  |  |
Interest expense | (3,445 | ) |  | (753 | )
Interest and other income | 199 |  |  | (95 | )
Total other expenses | (3,246 | ) |  | (848 | )
Income before income tax expense | 13,792 |  |  | 16,729 |
Income tax expense | 2,406 |  |  | 988 |
Net income | $ | 11,386 |  |  | $ | 15,741 |
Less: Net income attributable to non-controlling interests | 9,117 |  |  | 11,568 |
Net income attributable to Spark Energy, Inc. stockholders | $ | 2,269 |  |  | $ | 4,173 |
Other comprehensive loss, net of tax: |  |  |
Currency translation loss | $ | (49 | ) |  | $ | — |
Other comprehensive loss | (49 | ) |  | — |
Comprehensive income | $ | 11,337 |  |  | $ | 15,741 |
Less: Comprehensive income attributable to non-controlling interests | 9,086 |  |  | 11,568 |
Comprehensive income attributable to Spark Energy, Inc. stockholders | $ | 2,251 |  |  | $ | 4,173 |
Net income attributable to Spark Energy, Inc. per share of Class A common stock (4) |  |  |
Basic | $ | 0.32 |  |  | $ | 1.11 |
Diluted | $ | 0.31 |  |  | $ | 0.68 |
Weighted average shares of Class A common stock outstanding |  |  |  |
Basic | 6,498 |  |  | 3,756 |
Diluted | 6,634 |  |  | 14,520 |

(1) | Net asset optimization revenues (expenses) includes asset optimization revenues —affiliates of $0 and $113 for the three months ended March 31, 2017 and 2016, respectively, and asset optimization revenues—affiliates cost of revenues of $0 and $1,258 for the three months ended March 31, 2017 and 2016, respectively.

(2) | Retail cost of revenues includes retail cost of revenues—affiliates of $0 and less than $100 for the three months ended March 31, 2017 and 2016, respectively.

(3) | General and administrative includes general and administrative expense—affiliates of $7,300 and $4,400 for the three months ended March 31, 2017 and 2016, respectively.

(4) | In accordance with GAAP, net income attributable to stockholders of Class A common stock is presented net of cumulative Series A Preferred Stock dividends of $183 as of March 31, 2017.

The accompanying notes are an integral part of the condensed consolidated financial statements.
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SPARK ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
FOR THE THREE MONTHS ENDED MARCH 31, 2017
(in thousands)
(unaudited)

| Issued Shares of Class A Common Stock | Issued Shares of Class B Common Stock | Class A Common Stock | Class B Common Stock | Accumulated Other Comprehensive Income (Loss) | Additional Paid-in Capital | Retained Earnings (Deficit) | Total Stockholders' Equity | Non-controlling Interest | Total Equity
Balance at December 31, 2016 | 6,497 |  | 10,225 |  | $ | 65 |  | $ | 103 |  | $ | 11 |  | $ | 25,413 |  | $ | 4,711 |  | $ | 30,303 |  | $ | 93,433 |  | $ | 123,736 |
Stock based compensation | — |  | — |  | — |  | — |  | — |  | 531 |  | — |  | 531 |  | — |  | 531 |
Restricted stock unit vesting | 3 |  | — |  | — |  | — |  | — |  | 78 |  | — |  | 78 |  | — |  | 78 |
Consolidated net income | — |  | — |  | — |  | — |  | — |  | — |  | 2,269 |  | 2,269 |  | 9,117 |  | 11,386 |
Foreign currency translation adjustment for equity method investee | — |  | — |  | — |  | — |  | (18 | ) | — |  | — |  | (18 | ) | (31 | ) | (49 | )
Distributions paid to non-controlling unit holders | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | (4,347 | ) | (4,347 | )
Net contribution of the Major Energy Companies | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | 260 |  | 260 |
Dividends paid to Class A common stockholders | — |  | — |  | — |  | — |  | — |  | — |  | (2,355 | ) | (2,355 | ) | — |  | (2,355 | )
Conversion of Convertible Subordinated Notes to Class B Common Stock | — |  | 518 |  | — |  | 5 |  | — |  | 7,790 |  | — |  | 7,795 |  | — |  | 7,795 |
Balance at March 31, 2017 | 6,500 |  | 10,743 |  | $ | 65 |  | $ | 108 |  | $ | (7 | ) | $ | 33,812 |  | $ | 4,625 |  | $ | 38,603 |  | $ | 98,432 |  | $ | 137,035 |

The accompanying notes are an integral part of the condensed consolidated financial statements.
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SPARK ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE THREE MONTHS ENDED MARCH 31, 2017 AND 2016
(in thousands)
(unaudited)

| Three Months Ended March 31,
| 2017 |  | 2016
Cash flows from operating activities: |  |  |
Net income | $ | 11,386 |  |  | $ | 15,741 |
Adjustments to reconcile net income to net cash flows provided by operating activities: |  |  |
Depreciation and amortization expense | 8,167 |  |  | 6,789 |
Deferred income taxes | (87 | ) |  | 841 |
Stock based compensation | 1,367 |  |  | 618 |
Amortization of deferred financing costs | 248 |  |  | 117 |
Change in Fair Value of Earnout Liabilities | 1,936 |  |  | 1,000 |
Bad debt expense | 356 |  |  | 907 |
Loss on derivatives, net | 21,456 |  |  | 9,749 |
Current period cash settlements on derivatives, net | (6,178 | ) |  | (10,457 | )
Accretion of discount to convertible subordinated notes to affiliate | 1,004 |  |  | 35 |
Other | 7 |  |  | 235 |
Changes in assets and liabilities: |  |  |
Decrease in accounts receivable | 3,381 |  |  | 5,060 |
Increase in accounts receivable—affiliates | (55 | ) |  | (273 | )
Decrease in inventory | 3,322 |  |  | 3,484 |
Increase in customer acquisition costs | (7,690 | ) |  | (2,305 | )
Increase in prepaid and other current assets | (1,597 | ) |  | (1,180 | )
Decrease in other assets | — |  |  | 265 |
Decrease in accounts payable and accrued liabilities | (9,348 | ) |  | (7,340 | )
(Decrease) increase in accounts payable—affiliates | (558 | ) |  | 1,949 |
(Decrease) increase in other current liabilities | (2,413 | ) |  | 156 |
(Decrease) increase in other non-current liabilities | (324 | ) |  | 111 |
Net cash provided by operating activities | 24,380 |  |  | 25,502 |
Cash flows from investing activities: |  |  |
Purchases of property and equipment | (112 | ) |  | (665 | )
Payment of the Major Energy Companies Earnout | (7,403 | ) |  | — |
Payment of the Provider Companies Earnout and Installment Note | (2,097 | ) |  | — |
Contribution to equity method investment in eRex Spark | — |  |  | (168 | )
Net cash used in investing activities | (9,612 | ) |  | (833 | )
Cash flows from financing activities: |  |  |
Proceeds from issuance of Series A Preferred Stock, net of issuance costs paid | 38,607 |  |  | — |
Borrowings on notes payable | 5,625 |  |  | — |
Payments on notes payable | (46,993 | ) |  | (18,825 | )
Proceeds from disgorgement of stockholders short-swing profits | 666 |  |  | — |
Payment of dividends to Class A common stockholders | (2,355 | ) |  | (1,493 | )
Payment of distributions to non-controlling unitholders | (4,347 | ) |  | (5,876 | )
Net cash used in financing activities | (8,797 | ) |  | (26,194 | )
Increase in cash and cash equivalents | 5,971 |  |  | (1,525 | )
Cash and cash equivalents—beginning of period | 18,960 |  |  | 4,474 |
Cash and cash equivalents—end of period | $ | 24,931 |  |  | $ | 2,949 |
Supplemental Disclosure of Cash Flow Information: |  |  |
Non-cash items: |  |  |  |  |
Property and equipment purchase accrual | $ | 76 |  |  | $ | 57 |
Tax impact from tax receivable agreement upon exchange of units of Spark HoldCo, LLC to shares of Class A Common Stock | $ | — |  |  | $ | 1,707 |
Cash paid during the period for: |  |  |
Interest | $ | 888 |  |  | $ | 539 |
Taxes | $ | 118 |  |  | $ | 842 |

The accompanying notes are an integral part of the condensed consolidated financial statements.
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SPARK ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
1. Formation and Organization
Organization
Spark Energy, Inc. ("Spark Energy," "Company," "we" or "us") is 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”). Spark HoldCo owns all of the outstanding membership interests or common stock in each of Spark Energy, LLC (“SE”), Spark Energy Gas, LLC (“SEG”), Oasis Power Holdings, LLC ("Oasis"), CenStar Energy Corp. ("CenStar"), Electricity Maine, LLC, Electricity N.H., LLC and Provider Power Mass, LLC (collectively, the "Provider Companies"); and Major Energy Services, LLC, Major Energy Electric Services, LLC, and Respond Power, LLC (collectively, the "Major Energy Companies"), the operating subsidiaries through which the Company operates. 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.
SE is a licensed retail electric provider in multiple states. SE provides retail electricity services to end-use retail customers, ranging from residential and small commercial customers to large commercial and industrial users. SE was formed on February 5, 2002 under the Texas Revised Limited Partnership Act (as recodified by the TBOC) and was converted to a Texas limited liability company on May 21, 2014.
SEG is a retail natural gas provider and asset optimization business competitively serving residential, commercial and industrial customers in multiple states. SEG was formed on January 17, 2001 under the Texas Revised Limited Partnership Act (as recodified by the TBOC) and was converted to a Texas limited liability company on May 21, 2014.
Oasis, through its operating subsidiary, Oasis Power LLC, is a retail energy provider formed on August 28, 2009 as a limited liability company under the TBOC. We acquired Oasis on July 31, 2015 from an affiliate.
CenStar is a retail energy provider incorporated on July 18, 2008 under the New York Business Corporation Law. We acquired CenStar on July 8, 2015.
The Provider Companies operate as retail energy providers. Electricity Maine, LLC, Electricity N.H., LLC, and Provider Power Mass, LLC were formed on June 17, 2010, January 20, 2012 and August 22, 2012, respectively, as limited liability companies under the Maine Limited Liability Company Act. We acquired the Provider Companies on August 1, 2016, as described in Note 3 "Acquisitions."
The Major Energy Companies operate as retail energy providers. Major Energy Services, LLC, Major Energy Electric Services, LLC and Respond Power, LLC were formed on October 11, 2005, September 12, 2007 and July 11, 2008, respectively, as limited liability companies under the New York Limited Liability Company Law. We completed the purchase of all the outstanding membership interests of the Major Energy Companies on August 23, 2016 from an affiliate, as described in Note 3 "Acquisitions."
We are a Delaware corporation formed on April 22, 2014 for the purpose facilitating an initial public offering ("IPO") of our Class A common stock, par value $0.01 per share ("Class A common stock"), and to become the sole managing member of, and to hold an ownership interest in, Spark HoldCo. In connection with our IPO, NuDevco Retail Holdings LLC ("NuDevco Retail Holdings") formed NuDevco Retail, LLC (“NuDevco Retail”), a single member limited liability company, on May 29, 2014, to hold the remaining Spark HoldCo units and shares of our Class B common stock, par value $0.01 per share ("Class B common stock"). In January 2016, Retailco, LLC
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("Retailco") succeeded to the interest of NuDevco Retail Holdings of its Class B common stock and an equal number of Spark HoldCo units it held pursuant to a series of transfers. See Note 4 "Equity" for further discussion.
Relationship with our Founder and Majority Shareholder
W. Keith Maxwell, III (our "Founder") is the owner of a majority in voting power of our common stock through his ownership of NuDevco Retail and Retailco. Retailco is a wholly owned subsidiary of TxEx Energy Investments, LLC ("TxEx"), which is wholly owned by Mr. Maxwell. NuDevco Retail is a wholly owned subsidiary of NuDevco Retail Holdings, which is a wholly owned subsidiary of Electric HoldCo, LLC, which is also a wholly owned subsidiary of TxEx.
Emerging Growth Company Status
As a company with less than $1.0 billion in revenues during its last fiscal year, the Company qualifies as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012, or the JOBS Act. An emerging growth company may take advantage of specified reduced reporting and other regulatory requirements.
The Company will remain an “emerging growth company” until as late as the last day of the Company's 2019 fiscal year, or until the earliest of (i) the last day of the fiscal year in which the Company has $1.0 billion or more in annual revenues; (ii) the date on which the Company becomes a “large accelerated filer” (the fiscal year-end on which the total market value of the Company’s common equity securities held by non-affiliates is $700 million or more as of June 30); (iii) the date on which the Company issues more than $1.0 billion of non-convertible debt over a three-year period.
As a result of the Company's election to avail itself of certain provisions of the JOBS Act, the information that the Company provides may be different than what you may receive from other public companies in which you hold an equity interest.
Exchange and Registration Rights
The Spark HoldCo Third Amended and Restated Limited Liability Company Agreement provides that if the Company issues a new share of Class A common stock, Series A Preferred Stock (as defined below) or other equity security of the Company (other than shares of Class B common stock, and excluding issuances of Class A common stock upon an exchange of Class B common stock or Series A Preferred Stock), Spark HoldCo will concurrently issue a corresponding limited liability company unit either to the holder of the Class B common stock, or to the Company in the case of the issuance of shares of Class A common stock, Series A Preferred Stock or such other equity security. As a result, the number of Spark HoldCo units held by the Company always equals the number of shares of Class A common stock, Series A Preferred Stock or such other equity securities of the Company outstanding.
Each share of Class B common stock, all of which are held by NuDevco Retail and Retailco, has no economic rights but entitles the holder to one vote on all matters to be voted on by stockholders generally. Holders of 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.
NuDevco Retail and Retailco have the right to exchange (the “Exchange Right”) all or a portion of their Spark HoldCo units (together with a corresponding number of shares of Class B common stock) for Class A common stock (or cash at Spark Energy, Inc.’s or Spark HoldCo’s election (the “Cash Option”)) 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. In addition, NuDevco Retail and Retailco have the right, under certain circumstances, to cause the Company to register the offer and resale of NuDevco Retail's and Retailco's shares of Class A common stock obtained pursuant to the Exchange Right. Retail Acquisition Co., LLC ("RAC") is entitled to similar registration
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rights under the $2.1 million convertible subordinated note (the "CenStar Note") and $5.0 million convertible subordinated note (the "Oasis Note"). Refer to Note 8 "Debt" for further information.
2. Basis of Presentation and Summary of Significant Accounting Policies
The accompanying interim unaudited condensed consolidated financial statements (“interim 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"). This information should be read in conjunction with our consolidated financial statements and notes contained in our annual report on Form 10-K for the year ended December 31, 2016. The Company's 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.
The preparation of the Company's 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. Effects on the business, financial condition and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revision become known. The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for a fair presentation of the condensed consolidated financial statements. Operating results for the three months ended March 31, 2017 are not necessarily indicative of the results that may be expected for the full year or for any interim period.
Transactions with Affiliates
The Company enters into transactions with and pays certain costs on behalf of affiliates that are commonly controlled by W. Keith Maxwell III, and these affiliates enter into transactions with and pay certain costs on our behalf, in order to reduce risk, reduce administrative expense, create economies of scale, create strategic alliances and supply goods and services among these related parties.
These transactions include, but are not limited to, certain services to the affiliated companies associated with the Company’s debt facility prior to the IPO, employee benefits provided through the Company’s benefit plans, insurance plans, leased office space, administrative salaries for management due diligence work, recurring management consulting, and accounting, tax, legal, or technology services based on services provided, departmental usage, or headcount, which are considered reasonable by management. As such, the accompanying condensed consolidated financial statements include costs that have been incurred by the Company and then directly billed or allocated to affiliates, and costs that have been incurred by our affiliates and then directly billed or allocated to us, and are recorded net in general and administrative expense on the condensed consolidated statements of operations with a corresponding accounts receivable—affiliates or accounts payable—affiliates, respectively, recorded in the condensed consolidated balance sheets. Additionally, the Company enters into transactions with certain affiliates for sales or purchases of natural gas and electricity, which are recorded in retail revenues, retail cost of revenues, and net asset optimization revenues in the condensed consolidated statements of operations with a corresponding accounts receivable—affiliate or accounts payable—affiliate in the condensed consolidated balance sheets. The allocations and related estimates and assumptions are described more fully in Note 13 “Transactions with Affiliates.”
Presentation of the Acquisition of Major Energy Companies
On April 15, 2016, National Gas & Electric, LLC (“NG&E”), an affiliate of the Company, completed the acquisition of 100% of the membership interests of Major Energy Companies. On May 3, 2016, Spark HoldCo and Retailco entered into a Membership Interest Purchase Agreement (the "Major Purchase Agreement") with NG&E
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for the purchase of all of the membership interests of the Major Energy Companies. Spark HoldCo and Retailco completed the acquisition of the Major Energy Companies from NG&E on August 23, 2016.
Subsequent Events
Subsequent events have been evaluated through the date these financial statements are issued. Any material subsequent events that occurred prior to such date have been properly recognized or disclosed in the condensed consolidated financial statements. See Note 15 "Subsequent Events" for further discussion.
Recent Accounting Pronouncements
Adopted Standards
In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718) ("ASU 2016-09"). ASU 2016-09 includes provisions intended to simplify various aspects of accounting for shared-based payments, including income tax consequences, classification of awards as either equity or liability and classification on the statement of cash flows. This guidance is effective for annual and interim reporting periods of public entities beginning after December 15, 2016, with early adoption permitted. The Company adopted ASU 2016-09 in the first quarter of 2017.
The new standard requires prospective recognition of excess tax benefits resulting from stock-based compensation vesting and exercises to be recognized as a reduction of income taxes and reflected in operating cash flows. Previously, these amounts were recognized in additional paid-in capital and presented as a financing activity on the statement of cash flows. No net excess tax benefits were recognized as a reduction of income taxes for the three months ended March 31, 2017. Prior periods have not been adjusted.
The Company has elected to continue to estimate the number of stock-based awards expected to vest, as permitted by ASU 2016-09, rather than electing to account for forfeitures as they occur.
ASU 2016-09 requires that employee taxes paid when an employer withholds shares for tax-withholding purposes to be reported as financing activities in the statement of cash flows. Previously, these cash flows were included in operating activities. The Company has elected to adopt this prospectively, as permitted by ASU 2016-09. This change resulted in no impact on the statement of cash flow for the three months ended March 31, 2017.
In October 2016, the FASB issued ASU No. 2016-17, Consolidation (Topic 810): Interests Held through Related Parties that Are under Common Control ("ASU 2016-17"). ASU 2016-17 amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity ("VIE") should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. Under ASU 2016-17, a single decision maker of a VIE is required to consider indirect economic interests in the entity held through related parties on a proportionate basis when determining whether it is the primary beneficiary of that VIE. If a single decision maker and its related party are under common control, the single decision maker is required to consider indirect interests in the entity held through those related parties to be the equivalent of direct interests in their entirety. The amendments are effective for public business entities for fiscal years beginning after December 15, 2016 (the Company's first quarter of fiscal 2017), including interim periods within those fiscal years. Early adoption is permitted. The standard may be applied retrospectively or through a cumulative effect adjustment to retained earnings as of the beginning of the fiscal year of adoption. The Company adopted ASU 2016-17 effective January 1, 2017, and the adoption had no impact on the Company's consolidated financial statements.
Standards Being Evaluated/Standards Not Yet Adopted
In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The standard permits the use of either the retrospective or cumulative effect transition
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method. In August 2015, the FASB issued ASU No. 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, which deferred the effective date to periods beginning after December 15, 2017. Early adoption is permitted only as of annual reporting periods beginning after December 15, 2016. In December 2016, the FASB further issued ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers, to increase stakeholders' awareness of the proposals and to expedite improvements to ASU 2014-09. After assessing the new standard, the Company expects that there will be no material impacts to our revenue recognition procedures.
The FASB issued additional amendments to ASU No. 2014-09, as amended by ASU No. 2015-14:

• | March 2016 - ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) ("ASU 2016-08"). ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations. The guidance includes indicators to assist an entity in determining whether it controls a specified good or service before it is transferred to customers.

• | April 2016 - ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing ("ASU 2016-10"). ASU 2016-10 covers two specific topics: performance obligations and licensing. This amendment includes guidance on immaterial promised goods or services, shipping or handling activities, separately identifiable performance obligations, functional or symbolic intellectual property licenses, sales-based and usage-based royalties, license restrictions (time, use, geographical) and licensing renewals.

• | May 2016 - ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients ("ASU 2016-12"). ASU 2016-12 clarifies certain core recognition principles including collectability, sales tax presentation, noncash consideration, contract modifications and completed contracts at transition and disclosures no longer required if the full retrospective transition method is adopted.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) ("ASU 2016-02"). ASU 2016-02 amends the existing accounting standards for lease accounting by requiring entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to not recognize leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous guidance. ASU 2016-02 also requires qualitative disclosures along with certain specific quantitative disclosures for both lessees and lessors. The amendments in this ASU are effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and are effective for interim periods in the year of adoption. The ASU should be applied using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments ("ASU 2016-13"). ASU 2016-13 requires entities to use a current expected credit loss ("CECL") model, which is a new impairment model based on expected losses rather than incurred losses. The model requires financial assets measured at amortized cost be presented at the net amount expected to be collected. The allowance for credit losses is a valuation account that is deducted from the amortized cost basis. The income statement reflects the measurement of credit losses for newly recognized financial assets, as well as the expected credit losses during the period. The measurement of expected losses is based upon historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. This guidance is effective for interim and annual reporting periods beginning after December 15, 2019, with early adoption permitted for annual reporting periods beginning after December 15, 2018. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
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In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments ("ASU 2016-15"). ASU 2016-15 provides guidance on the presentation and classification of eight specific cash flow issues in the statement of cash flows. Those issues are cash payment for debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instrument or other debt instrument with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; cash proceeds from the settlement of insurance claims, cash received from settlement of corporate-owned life insurance policies; distribution received from equity method investees; beneficial interest in securitization transactions; and classification of cash receipts and payments that have aspects of more than one class of cash flows. The guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied using a retrospective transition method for each period presented. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In October 2016, the FASB issued ASU No. 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory (“ASU 2016-16”). ASU 2016-16 requires immediate recognition of the current and deferred income tax consequences of intercompany asset transfers other than inventory. Current U.S. GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This guidance is effective for annual and interim reporting periods of public entities beginning after December 15, 2017, with early adoption permitted as of the beginning of an annual reporting period for which financial statements (interim or annual) have not been issued or made available for issuance. This ASU should be applied using a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash ("ASU 2016-18"). ASU 2016-18 is intended to add and clarify guidance on the classification and presentation of restricted cash on the statement of cash flows. ASU 2016-18 requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amendments are effective for public business entities for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business ("ASU 2017-01"). ASU 2017-01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The definition of a business affects many areas of accounting, including acquisitions, disposals, goodwill, and consolidation. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods, and the amendments should be applied prospectively on or after the effective date. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-03, Accounting Changes and Error Corrections (Topic 250) and Investments - Equity Method and Joint Ventures (Topic 323) ("ASU 2017-03"). ASU 2017-03 offers amendments to SEC paragraphs pursuant to staff announcements at the September 22, 2016 and November 17, 2016 EITF meetings for clarification purposes. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment ("ASU 2017-04"). ASU 2017-04 simplifies the subsequent measurement of goodwill by eliminating Step 2 from the goodwill impairment test. Under the amendments in this update, an entity should
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perform its annual or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value. However, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. ASU 2017-04 should be applied on a prospective basis and is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In February 2017, the FASB issued ASU No. 2017-05, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) : Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets ("ASU 2017-05"). ASU 2017-05 clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. Subtopic 610-20 was issued in May 2014 as part of ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) and provides guidance for recognizing gains and losses from the transfer of nonfinancial assets in contracts with noncustomers. The amendments in ASU 2017-05 clarify that a financial asset is within the scope of Subtopic 610-20 if it meets the definition of an in substance nonfinancial asset. The amendments also clarify that nonfinancial assets within the scope of Subtopic 610-20 may include nonfinancial assets transferred within a legal entity to a counterparty. The amendments in ASU 2017-05 are effective at the same time as the amendments in ASU 2014-09, which are effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. Early adoption is permitted for interim or annual reporting periods beginning after December 15, 2016. An entity may elect to apply the amendments in ASU 2017-05 either retrospectively to each period presented in the financial statements in accordance with the guidance on accounting changes (retrospective approach) or retrospectively with a cumulative-effect adjustment to retained earnings as of the beginning of the fiscal year of adoption (modified retrospective approach). The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
3. Acquisitions
Acquisition of the Provider Companies
On August 1, 2016, the Company and Spark HoldCo completed the purchase of all of the outstanding membership interests of the Provider Companies. The Provider Companies serve electrical customers in Maine, New Hampshire and Massachusetts. The purchase price for the Provider Companies was approximately $34.1 million, which included $1.3 million in working capital, subject to adjustments, and up to $9.0 million in earnout payments, valued at $4.8 million as of the purchase date, to be paid by June 30, 2017, subject to the achievement of certain performance targets (the "Provider Earnout"). See Note 9 "Fair Value Measurements" for further discussion on the Provider Earnout. The purchase price was funded by the issuance of 699,742 shares of Class B common stock (and a corresponding number of Spark HoldCo units) sold to Retailco, valued at $14.0 million based on a value of $20 per share; borrowings under the Senior Credit Facility of $10.6 million; and $3.8 million in net installment consideration to be paid in ten monthly payments that commenced in August 2016. The first payment of $0.4 million was made with the initial consideration paid. See Note 8 "Debt" for further discussion of the Senior Credit Facility.
The acquisition of the Provider Companies was accounted for under the acquisition method in accordance with ASC 805, Business Combinations (“ASC 805”). The allocation of purchase consideration was based upon the estimated fair value of the tangible and identifiable intangible assets acquired and liabilities assumed in the acquisition. The allocation was made to major categories of assets and liabilities based on management’s best estimates, and supported by independent third-party analyses. The excess of the purchase price over the estimated fair value of tangible and intangible assets acquired and liabilities assumed was allocated to goodwill. The purchase price allocation for the acquisition of the Provider Companies was finalized as of December 31, 2016. No changes were recorded during the three months ended March 31, 2017.

Acquisition of the Major Energy Companies
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On August 23, 2016, the Company and Spark HoldCo completed the transfer of all of the outstanding membership interests of the Major Energy Companies, which are retail energy companies operating in Connecticut, Illinois, Maryland (including the District of Columbia), Massachusetts, New Jersey, New York, Ohio, and Pennsylvania across 43 utilities, from NG&E in exchange for consideration of $63.4 million, which included $4.3 million in working capital, subject to adjustments; an assumed litigation reserve of $5.0 million, and up to $35.0 million in installment and earnout payments, valued at $13.1 million as of the purchase date, to be paid to the previous members of the Major Energy Companies, in annual installments on March 31, 2017, 2018 and 2019, subject to the achievement of certain performance targets (the “Major Earnout”). The Company is obligated to issue up to 200,000 shares of Class B common stock (and a corresponding number of Spark HoldCo units) to NG&E, subject to the achievement of certain performance targets, valued at $0.8 million (40,718 shares valued at $20 per share) as of the purchase date (the "Stock Earnout"). See Note 9 "Fair Value Measurements" for further discussion on the Major Earnout and Stock Earnout. The purchase price was funded by the issuance of 2,000,000 shares of Class B common stock (and a corresponding number of Spark HoldCo units) valued at $40.0 million based on a value of $20 per share, to NG&E. NG&E is owned by our Founder.
The acquisition of the Major Energy Companies by the Company and Spark HoldCo from NG&E was a transfer of equity interests of entities under common control on August 23, 2016. Accordingly, the assets acquired and liabilities assumed were based on their historical values as of August 23, 2016. NG&E acquired the Major Energy Companies on April 15, 2016 and the fair value of the net assets acquired was as follows (in thousands):

| Reported as of December 31, 2016 | Q1 2017 Adjustments (1) | March 31, 2017
Cash | $ | 17,368 |  | $ | — |  | $ | 17,368 |
Property and equipment | 14 |  | — |  | 14 |
Intangible assets - customer relationships & non-compete agreements | 24,271 |  | — |  | 24,271 |
Other assets - trademarks | 4,973 |  | — |  | 4,973 |
Non-current deferred tax assets | 1,042 |  | — |  | 1,042 |
Goodwill | 34,728 |  | 260 |  | 34,988 |
Net working capital, net of cash acquired | (6,746 | ) | — |  | (6,746 | )
Fair value of derivative liabilities | (7,260 | ) | — |  | (7,260 | )
Total | $ | 68,390 |  | $ | 260 |  | $ | 68,650 |

(1) Changes to the purchase price allocation in the first quarter of 2017 related to NG&E's working capital settlement with the Major Energy
Companies' sellers.
The initial working capital estimate paid to the Major Energy Companies by NG&E was $10.3 million. The Company subsequently paid $4.3 million in working capital to NG&E on August 23, 2016. Approximately $6.0 million was recorded as an equity transaction and treated as a contribution on August 23, 2016, revised to $4.9 million and $4.7 million based on the estimated working capital true-up adjustments with NG&E as of March 31, 2017 and December 31, 2016, respectively. An estimated working capital adjustment between the Company and NG&E of $1.4 million was recorded as of December 31, 2016 and is included in accounts payable - affiliates at March 31, 2017 and December 31, 2016. The Stock Earnout of $0.8 million due to NG&E is also reflected as a reduction to equity as of March 31, 2017 and December 31, 2016. Finalization of the Company's working capital adjustment with NG&E was completed prior to April 15, 2017.
The fair values of intangible assets were measured primarily based on significant inputs that are not observable in the market and thus represent a Level 3 measurement as defined by ASC 820, Fair Value Measurement ("ASC 820"). The fair value of derivative liabilities were measured by utilizing readily available quoted market prices and non-exchange-traded contracts fair valued using market price quotations available through brokers or over-the-counter and on-line exchanges and represent a Level 2 measurement as defined by ASC 820. Refer to Note 9 "Fair Value Measurements" for further discussion on the fair values hierarchy.
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Goodwill
The excess of the purchase consideration over the estimated fair value of the amounts initially assigned to the identifiable assets acquired and liabilities assumed was recorded as goodwill. Goodwill arose on the acquisition of the Major Energy Companies by NG&E primarily due to the value of the Major Energy Companies brand strength, established vendor relationships and access to new utility service territories. Goodwill recorded in connection with the acquisition of the Major Energy Companies is deductible for income tax purposes because the acquisition of the Major Energy Companies was an acquisition of all of the assets of the Major Energy Companies. The valuation and purchase price allocation of the Major Energy Companies was based on a preliminary fair value analysis performed as of April 15, 2016, the date the Major Energy Companies were acquired by NG&E. During the measurement period, the Company may record adjustments to the working capital balances upon settlement of the final working capital balances per the terms of the purchase agreement.
Goodwill was transferred to the Company based on the acquisition of the Major Energy Companies by NG&E on April 15, 2016. Goodwill recorded in connection with the transfer of the Major Energy Companies is deductible for income tax purposes.
In December 2016, certain executives of the Major Energy Companies exercised a change of control provision under employment agreements with the Major Energy Companies. As a result, the Company recorded employment contract termination costs of $4.1 million as of December 31, 2016. The Company paid employment contract termination costs totaling $1.5 million during the three months ended March 31, 2017. As of March 31, 2017, the Company's liability related to the contract termination costs was $2.6 million, to be paid over a 22 month period beginning April 1, 2017.
4. Equity
Non-controlling Interest
The Company holds an economic interest and is the sole managing member in Spark HoldCo, with NuDevco Retail and Retailco holding the remaining economic interest in Spark HoldCo. As a result, the Company has consolidated the financial position and results of operations of Spark HoldCo and reflected the economic interest retained by NuDevco Retail and Retailco as a non-controlling interest.
The Company and NuDevco Retail and Retailco owned the following economic interests in Spark HoldCo at December 31, 2016 and March 31, 2017, respectively.
Non-controlling Interest Economic Interest

| The Company | NuDevco Retail and Retailco (1) (2)
December 31, 2016 | 38.85 | % | 61.15 | %
March 31, 2017 | 37.70 | % | 62.30 | %

.
(1) In January 2016, Retailco succeeded to the interest of NuDevco Retail Holdings of its Class B common stock and an equal number of Spark HoldCo units it held pursuant to a series of transfers.
(2) In January 2017, Retailco converted the CenStar Note and Oasis Note into 134,731 and 383,090 shares, respectively, of Class B common stock.
The following table summarizes the portion of net income and income tax expense (benefit) attributable to non-controlling interest (in thousands):
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| Three Months Ended March 31,
| 2017 |  | 2016
Net income allocated to non-controlling interest | $ | 8,660 |  |  | $ | 12,008 |
Income tax expense (benefit) allocated to non-controlling interest | (457 | ) |  | 440 |
Net income attributable to non-controlling interest | $ | 9,117 |  |  | $ | 11,568 |

Class A Common Stock
The Company had a total of 6,499,504 and 6,496,559 shares of its Class A common stock outstanding at March 31, 2017 and December 31, 2016, respectively. Each share of Class A common stock holds economic rights and entitles its holder to one vote on all matters to be voted on by shareholders generally.
Class B Common Stock
The Company has a total of 10,742,563 and 10,224,742 shares of its Class B common stock outstanding at March 31, 2017 and December 31, 2016, respectively. Each share of Class B common stock, all of which are held by NuDevco Retail and Retailco, have no economic rights but entitles its holder to one vote on all matters to be voted on by shareholders generally.
Holders of Class A common stock and Class B common stock vote together as a single class on all matters presented to our shareholders for their vote or approval, except as otherwise required by applicable law or by our certificate of incorporation.
Conversion of CenStar and Oasis Notes
On January 8, 2017 and January 31, 2017, respectively, the CenStar Note and Oasis Note were converted into 134,731 and 383,090 shares of Class B common stock (and related Spark HoldCo units). Refer to Note 8 "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 interest in the Company. Diluted earnings per share is similarly calculated except that the denominator is increased (1) using the treasury stock method to determine the potential dilutive effect of the Company's outstanding unvested restricted stock units, (2) using the if-converted method to determine the potential dilutive effect of the Company's Class B common stock and (3) using the if-converted method to determine the potential dilutive effect of the outstanding convertible subordinated notes into the Company's Class B common stock.
The following table presents the computation of earnings per share for the three months ended March 31, 2017 and 2016 (in thousands, except per share data):
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| Three Months Ended March 31,
| 2017 | 2016
Net income attributable to Spark Energy, Inc. stockholders | $ | 2,269 |  | $ | 4,173 |
Less: Accumulated dividend on Series A preferred stock | $ | 183 |  | $ | — |
Net income attributable to stockholders of Class A common stock (2) | $ | 2,086 |  | $ | 4,173 |
Basic weighted average Class A common shares outstanding | 6,498 |  | 3,756 |
Basic EPS attributable to stockholders | $ | 0.32 |  | $ | 1.11 |
Net income attributable to stockholders of Class A common stock (2) | $ | 2,086 |  | $ | 4,173 |
Effect of conversion of Class B common stock to shares of Class A common stock | — |  | 6,094 |
Effect of conversion of convertible subordinated notes into shares of Class B common stock and shares of Class B common stock into shares of Class A common stock (1) | — |  | (413 | )
Diluted net income attributable to stockholders of Class A common stock | 2,086 |  | 9,854 |
Basic weighted average Class A common shares outstanding | 6,498 |  | 3,756 |
Effect of dilutive Class B common stock | — |  | 10,113 |
Effect of dilutive convertible subordinated notes into shares of Class B common stock and shares of Class B common stock into shares of Class A common stock (1) | — |  | 493 |
Effect of dilutive restricted stock units | 136 |  | 158 |
Diluted weighted average shares outstanding | 6,634 |  | 14,520 |
Diluted EPS attributable to stockholders | $ | 0.31 |  | $ | 0.68 |

(1) The CenStar Note and Oasis Note converted into 134,731 and 383,090 shares of Class B common stock on January 8, 2017, and January 31, 2017, respectively.
(2) In accordance with GAAP, net income attributable to stockholders of Class A common stock is presented net of cumulative Series A Preferred Stock dividends of $183 as of March 31, 2017.
The conversion of shares of Class B common stock to shares of Class A common stock was not recognized in dilutive earnings per share for the three months ended March 31, 2017 as the effect of the conversion was antidilutive.
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 inability to dissolve or otherwise remove its management. Spark HoldCo owns all of the outstanding membership interests in each of the operating subsidiaries through which the Company operates. The Company is the sole managing member of Spark HoldCo, manages Spark HoldCo's operating subsidiaries through this managing membership interest, and is considered the primary beneficiary of Spark HoldCo.
The assets of Spark HoldCo cannot be used to settle the obligations of the Company except through distributions to the Company, and the liabilities of Spark HoldCo cannot be settled by the Company 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 the Company's condensed consolidated balance sheet as of March 31, 2017 (in thousands):
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| March 31, 2017
Assets |
Current assets: |
Cash and cash equivalents | $ | 24,784 |
Accounts receivable | 108,754 |
Other current assets | 57,997 |
Total current assets | 191,535 |
Non-current assets: |
Goodwill | 79,407 |
Other assets | 40,392 |
Total non-current assets | 119,799 |
Total Assets | $ | 311,334 |
Liabilities |
Current liabilities: |
Accounts payable and Accrued Liabilities | $ | 77,633 |
Intercompany payable with Spark Energy, Inc. | 37,636 |
Current portion of Senior Credit Facility | 22,236 |
Contingent consideration | 12,103 |
Other current liabilities | 7,170 |
Total current liabilities | 156,778 |
Long-term liabilities: |
Contingent consideration | 4,083 |
Other long-term liabilities | 4,964 |
Total long-term liabilities | 9,047 |
Total Liabilities | $ | 165,825 |

5. Preferred Stock
On March 15, 2017, the Company issued 1,610,000 shares of 8.75% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock ("Series A Preferred Stock"), par value $0.01 per share and liquidation preference $25.00 per share, plus accumulated and unpaid dividends, at a price to the public of $25.00 per share ($24.21 per share to the Company, net of underwriting discounts and commissions). The Company received approximately $39.0 million in net proceeds from the offering, after deducting underwriting discounts and commissions and a structuring fee. Preferred offering expenses of $0.6 million were recorded as a reduction to the carrying value of the stock. The net proceeds from the offering were contributed to Spark HoldCo to use for general corporate purposes.
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 for as specified in the Series A Preferred Stock Certificate of Designations. From March 15, 2017, the Series A Preferred Stock issuance date, to, but not including, April 15, 2022, the Series A Preferred Stock will accrue dividends at a percentage of three-month LIBOR plus 6.578%.
The liquidation preference provisions of the Series A Preferred Stock were considered contingent redemption provisions because there were certain elements that were not solely within the control of the Company, such as a change in control of the Company. Accordingly, the Series A Preferred Stock is presented within the mezzanine portion of the accompanying consolidated balance sheet.
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The Company had a total of 1,610,000 shares of Series A Preferred Stock issued and outstanding at March 31, 2017 and no shares of Series A Preferred Stock issued and outstanding at December 31, 2016.
In connection with the issuance of the Series A Preferred Stock, the Company and Spark HoldCo entered into the Third Amended and Restated Spark HoldCo Limited Liability Company Agreement to amend the prior agreement to provide for, among other things, the designation and issuance of Spark HoldCo Series A preferred units, as another equity security of Spark HoldCo to be issued concurrently with the issuance of Series A Preferred Stock by the Company, including specific terms relating to distributions by Spark HoldCo in connection with the payment by the Company of dividends on the Series A Preferred Stock, the priority of liquidating distributions by Spark HoldCo, the allocation of income and loss to the Company in connection with distributions by Spark HoldCo on Series A preferred units, and other terms relating to the redemption and conversion by the Company of the Series A Preferred Stock.
6. Property and Equipment
Property and equipment consist of the following amounts as of (in thousands):

| Estimated useful lives (years) |  | March 31, 2017 |  | December 31, 2016
Information technology | 2 – 5 |  | $ | 29,863 |  |  | $ | 29,675 |
Leasehold improvements | 2 – 5 |  | 4,568 |  |  | 4,568 |
Furniture and fixtures | 2 – 5 |  | 1,024 |  |  | 1,024 |
Total |  |  | 35,455 |  |  | 35,267 |
Accumulated depreciation |  |  | (31,066 | ) |  | (30,561 | )
Property and equipment—net |  |  | $ | 4,389 |  |  | $ | 4,706 |

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 March 31, 2017 and December 31, 2016, information technology includes $1.2 million and $1.1 million, respectively, of costs associated with assets not yet placed into service.
Depreciation expense recorded in the condensed consolidated statements of operations was $0.5 million and $0.4 million for the three months ended March 31, 2017 and 2016, respectively.
7. Goodwill, Customer Relationships and Trademarks
Goodwill, customer relationships and trademarks consist of the following amounts as of (in thousands):
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| March 31, 2017 | December 31, 2016
Goodwill | $ | 79,407 |  | $ | 79,147 |
Customer relationships - Acquired (1) |  |
Cost | $ | 63,571 |  | $ | 63,571 |
Accumulated amortization | (33,812 | ) | (31,660 | )
Customer relationships - Acquired, net | $ | 29,759 |  | $ | 31,911 |
Customer relationships - Other (2) |  |
Cost | $ | 4,320 |  | $ | 4,320 |
Accumulated amortization | (3,068 | ) | (2,708 | )
Customer relationships - Other, net | $ | 1,252 |  | $ | 1,612 |
Trademarks (3) |  |
Cost | $ | 6,770 |  | $ | 6,770 |
Accumulated amortization | (551 | ) | (431 | )
Trademarks, net | $ | 6,219 |  | $ | 6,339 |

(1) Customer relationships - Acquired represent those customer acquisitions accounted for under the acquisition method in accordance with ASC 805. See Note 3 "Acquisitions" for further discussion.
(2) Customer relationships - Other represent portfolios of customer contracts not accounted for in accordance with ASC 805 as these acquisitions were not in conjunction with the acquisition of businesses.
(3) Trademarks reflect values associated with the recognition and positive reputation of acquired businesses accounted for as part of the acquisition method in accordance with ASC 805 through the acquisitions of CenStar, Oasis, the Provider Companies and the Major Energy Companies. These trademarks are recorded as other assets in the condensed consolidated balance sheets. See Note 3 "Acquisitions" for further discussion.
Changes in goodwill, customer relationships and trademarks consisted of the following (in thousands):

| Goodwill (1) | Customer Relationships - Acquired | Customer Relationships - Others | Trademarks
Balance at December 31, 2016 | $ | 79,147 |  | $ | 31,911 |  | $ | 1,612 |  | $ | 6,339 |
Additions (Major Working Capital Adjustment) | 260 |  | — |  | — |  | — |
Amortization expense | — |  | (2,152 | ) | (360 | ) | (120 | )
Balance at March 31, 2017 | $ | 79,407 |  | $ | 29,759 |  | $ | 1,252 |  | $ | 6,219 |

(1) Changes in goodwill in the three months ended March 31, 2017 related to NG&E's working capital settlement with the
Major Energy Companies' sellers.
The acquired customer relationship intangibles related to the Major Energy Companies and the Provider Companies were bifurcated between hedged and unhedged customer contracts. The unhedged customer contracts are amortized to depreciation and amortization based on the expected future cash flows by year. The hedged customer contracts were evaluated for favorable or unfavorable positions at the time of acquisition and amortized to retail cost of revenue based on the expected term and position of the underlying fixed price contract in each reporting period. Customer relationship amortization expense for the three months ended March 31, 2017 was $2.2 million, which is net of $1.1 million customer relationship amortization gain included in cost of revenues.
Estimated future amortization expense for customer relationships and trademarks at March 31, 2017 is as follows (in thousands):
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Year ending December 31, |
2017 | $ | 10,281 |
2018 | 10,337 |
2019 | 5,892 |
2020 | 2,894 |
2021 | 2,592 |
> 5 years | 5,234 |
Total | $ | 37,230 |

8. Debt
Debt consists of the following amounts (in thousands):

| March 31, 2017 |  | December 31, 2016
Current portion of Senior Credit Facility—Working Capital Line (1) (2) | $ | — |  |  | $ | 29,000 |
Current portion of Senior Credit Facility—Acquisition Line (2) | 22,236 |  |  | 22,287 |
Current portion of Note Payable—Pacific Summit Energy | 8,185 |  |  | 15,501 |
Convertible subordinated notes to affiliate | — |  |  | 6,582 |
Total current debt | 30,421 |  |  | 73,370 |
Subordinated Debt | — |  |  | 5,000 |
Total long-term debt | — |  |  | 5,000 |
Total debt | $ | 30,421 |  |  | $ | 78,370 |

(1) | As of March 31, 2017 and December 31, 2016, the Company had $39.3 million and $29.6 million in letters of credit issued, respectively.

(2) | As of March 31, 2017 and December 31, 2016, the weighted average interest rate on the current portion of our Senior Credit Facility was 4.75% and 4.93%, respectively.

Deferred financing costs were $0.2 million and $0.4 million as of March 31, 2017 and December 31, 2016, respectively, recorded in other current assets, representing capitalized financing costs in connection with the amendment and restatement of our Senior Credit Facility on July 8, 2015.
Interest expense consists of the following components for the periods indicated (in thousands):

| Three Months Ended March 31,
| 2017 |  | 2016
Interest incurred on Senior Credit Facility | $ | 694 |  |  | $ | 318 |
Accretion related to Earnouts (1) | 1,225 |  |  | — |
Letters of credit fees and commitment fees | 226 |  |  | 192 |
Amortization of deferred financing costs | 248 |  |  | 117 |
Interest incurred on convertible subordinated notes to affiliate (2) | 1,052 |  |  | 126 |
Interest Expense | $ | 3,445 |  |  | $ | 753 |

(1) Includes accretion related to the Provider Earnout of $0.1 million and the Major Earnout of $1.1 million for the three months ended March 31, 2017.
(2) Includes amortization of the discount on the convertible subordinated notes to affiliates of $1.0 million and $0.1 million for the three months ended March 31, 2017 and 2016, respectively.
Senior Credit Facility
The Company, as guarantor, and Spark HoldCo (the “Borrower,” and together with Spark Energy, LLC, Spark Energy Gas, LLC, CenStar Energy Corp, CenStar Operating Company, LLC, Oasis, Oasis Power, LLC, Electricity Maine, LLC, Electricity N.H., LLC, and Provider Power Mass, LLC, each a subsidiary of Spark HoldCo, the “Co-Borrowers”) are party to a senior secured revolving credit facility (“Senior Credit Facility”), which includes a
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senior secured revolving working capital facility up to $82.5 million ("Working Capital Line") and a secured revolving line of credit of $25.0 million ("Acquisition Line") to be used specifically for the financing of up to 75% of the cost of acquisitions with the remainder to be financed by the Company either through cash on hand or the issuance of subordinated debt or equity.
On June 1, 2016, the Company and the Co-Borrowers entered into Amendment No. 3 to the Senior Credit Facility to, among other things, increase the Working Capital Line from $60.0 million to $82.5 million in accordance with the Co-Borrowers' right to increase under the existing terms of the Senior Credit Facility. Amendment No. 3 also provides for the addition of new lenders and re-allocates working capital and revolving commitments among existing and new lenders. Amendment No. 3 also provides for additional representations of the Co-Borrowers and additional protections of the lenders of the Senior Credit Facility.
On August 1, 2016, the Company and the Co-Borrowers entered into Amendment No. 4 to the Senior Credit Facility to, among other things, amend the provisions under the Acquisition Line to allow for the Provider Companies acquisition. Amendment No. 4 also raises the minimum availability under the Working Capital Line to $40.0 million. In addition, Amendment No. 4 designates Major Energy Companies as "unrestricted subsidiaries" upon the closing of such acquisition on August 23, 2016.
The Senior Credit Facility will mature on July 8, 2017. The outstanding balances under the Working Capital Line and the Acquisition Line are classified as current debt as of March 31, 2017.
At our election, the interest rate under the Working Capital Line is generally determined by reference to:

• | the Eurodollar-based rate plus an applicable margin of up to 3.00% per annum (based upon the prevailing utilization); or

• | the alternate base rate plus an applicable margin of up to 2.00% per annum (based upon the prevailing utilization). The alternate base rate is equal to the highest of (i) Société Générale’s prime rate, (ii) the federal funds rate plus 0.50% per annum, or (iii) the reference Eurodollar rate plus 1.00%; or

• | the rate quoted by Société Générale as its cost of funds for the requested credit plus up to 2.50% per annum (based upon the prevailing utilization).

The interest rate is generally reduced by 25 basis points if utilization under the Working Capital Line is below fifty percent.
Borrowings under the Acquisition Line are generally determined by reference to:

• | the Eurodollar rate plus an applicable margin of up to 3.75% per annum (based upon the prevailing utilization); or

• | the alternate base rate plus an applicable margin of up to 2.75% per annum (based upon the prevailing utilization). The alternate base rate is equal to the highest of (i) Société Générale's prime rate, (ii) the federal funds rate plus 0.50% per annum, or (iii) the reference Eurodollar rate plus 1.00%.

The Co-Borrowers pay an annual commitment fee of 0.375% or 0.50% on the unused portion of the Working Capital Line depending upon the unused capacity and 0.50% on the unused portion of the Acquisition Line. The lending syndicate under the Senior Credit Facility is entitled to several additional fees including an upfront fee, annual agency fee, and fronting 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 Company has the ability to elect the availability under the Working Capital Line between $40.0 million to $82.5 million. On September 30, 2016, the Company and the Co-Borrowers elected to reduce the capacity of the Working Capital Line from $82.5 million to $60.0 million. At December 31, 2016, we elected up to the $70.0 million level. The Company and the Co-Borrowers elected a Working Capital Line of $82.5 million, effective as of March 22, 2017.
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Availability under the working capital line will be subject to borrowing base limitations. The borrowing base is calculated primarily based on 80% to 90% of the value of eligible accounts receivable and unbilled product sales (depending on the credit quality of the counterparties) and inventory and other working capital assets. The Co-Borrowers must generally seek approval of the agent or the lenders for permitted acquisitions to be financed under the Acquisition Line.
The Senior Credit Facility is secured by pledges of the equity of the portion of Spark HoldCo owned by the Company and of the equity of Spark HoldCo’s subsidiaries (excluding the Major Energy Companies) and the Co-Borrowers’ present and future subsidiaries, all of 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.
The Major Energy Companies are currently excluded from the definition of "Borrowers" under the Senior Credit Facility. Accordingly we did not factor their working capital into our working capital covenants.
The Senior Credit Facility also contains covenants that, among other things, require the maintenance of specified ratios or conditions as follows:

• | Minimum Net Working Capital. The Co-Borrowers must maintain minimum consolidated net working capital equal to the greater of $5.0 million or 15% of the elected availability under the Working Capital Line.

• | Minimum Adjusted Tangible Net Worth. The Co-Borrowers must maintain a minimum consolidated adjusted tangible net worth at all times equal to the net cash proceeds from equity issuances occurring after the date of the Senior Credit Facility plus the greater of (i) 20% of aggregate commitments under the Working Capital Line plus 33% of borrowings under the Acquisition Line and (ii) $18.0 million.

• | Minimum Fixed Charge Coverage Ratio. Spark Energy, Inc. must maintain a minimum fixed charge coverage ratio of 1.25 to 1.00. The Fixed Charge Coverage Ratio is defined as the ratio of (a) Adjusted EBITDA to (b) the sum of consolidated interest expense (other than interest paid-in-kind in respect of any Subordinated Debt), letter of credit fees, commitment fees, acquisition earn-out payments, distributions and scheduled amortization payments.

• | Maximum Total Leverage Ratio. Spark Energy, Inc. must maintain a ratio of total indebtedness (excluding the Working Capital Facility and qualifying subordinated debt) to Adjusted EBITDA of a maximum of 2.50 to 1.00.

The Senior Credit Facility contains various negative covenants that limit the Company’s ability to, among other things, do any of the following:

• | incur certain additional indebtedness;

• | grant certain liens;

• | engage in certain asset dispositions;

• | merge or consolidate;

• | make certain payments, distributions, investments, acquisitions or loans; or

• | enter into transactions with affiliates.

Spark Energy, Inc. is entitled to pay cash dividends to the holders of the Class A common stock and Series A Preferred Stock, and Spark HoldCo will be entitled to make cash distributions to us, NuDevco Retail and Retailco (or their successors in interest) so long as: (a) no default exists or would result from such a payment; (b) the Co-Borrowers are in pro forma compliance with all financial covenants before and after giving effect to such payment and (c) the outstanding amount of all loans and letters of credit does not exceed the borrowing base limits. Spark
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HoldCo’s inability to satisfy certain financial covenants or the existence of an event of default, if not cured or waived, under the Senior Credit Facility could prevent the Company from paying dividends to holders of the Class A common stock.
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, change in control in which affiliates of W. Keith Maxwell III own less than 40% of the outstanding voting interests in the Company, certain events of bankruptcy, certain events under ERISA, material judgments in excess of $5.0 million, certain events with respect to material contracts, actual or asserted failure of any guaranty or security document supporting the Senior Credit Facility to be in full force and effect and changes of 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.
In addition, the Senior Credit Facility contains affirmative covenants that are customary for credit facilities of this type. The covenants include delivery of financial statements, including any filings made with the SEC, maintenance of property and insurance, payment of taxes and obligations, material compliance with laws, inspection of property, books and records and audits, use of proceeds, payments to bank blocked accounts, notice of defaults and certain other customary matters.
Convertible Subordinated Notes to Affiliate
In connection with the financing of the CenStar acquisition, the Company, together with Spark HoldCo, issued the CenStar Note to RAC for $2.1 million on July 8, 2015. The CenStar Note matures on July 8, 2020, and bears interest at an annual rate of 5%, payable semiannually. The Company has the right to pay interest in kind at its option. The CenStar Note is convertible into shares of the Company’s Class B common stock, par value $0.01 per share (and a related unit of Spark HoldCo) at a conversion price of $16.57 per share. RAC may not exercise conversion rights for the first eighteen months after the CenStar Note is issued. The CenStar Note is subject to automatic conversion upon a sale of the Company. The CenStar Note is subordinated in certain respects to the Senior Credit Facility pursuant to a subordination agreement. The Company may pay interest and prepay principal so long as the Company is in compliance with its covenants; is not in default under the Senior Credit Facility and has minimum availability of $5.0 million under its borrowing base under the Senior Credit Facility. Shares of Class A common stock resulting from the conversion of the shares of Class B common stock issued as a result of the conversion right under the CenStar Note will be entitled to registration rights identical to the registration rights currently held by NuDevco Retail and Retailco on shares of Class A common stock it receives upon conversion of its existing shares of Class B common stock. On October 5, 2016, RAC issued to the Company an irrevocable commitment to convert the CenStar Note into 134,731 shares of Class B common stock. RAC assigned the CenStar Note to Retailco on January 4, 2017, and on January 8, 2017, the CenStar Note was converted into 134,731 shares of Class B common stock.
In connection with the financing of the Oasis acquisition, the Company, together with Spark HoldCo, issued the Oasis Note to RAC for $5.0 million on July 31, 2015. The Oasis Note matures on July 31, 2020, and bears interest at an annual rate of 5%, payable semiannually. The Company has the right to pay-in-kind any interest at its option. The Oasis Note is convertible into shares of the Company's Class B common stock, par value $0.01 per share (and a related unit of Spark HoldCo) at a conversion price of $14.00 per share. RAC may not exercise conversion rights for the first eighteen months after the Oasis Note is issued. The Oasis Note is subject to automatic conversion upon a sale of the Company. The Oasis Note is subordinated in certain respects to the Senior Credit Facility pursuant to a subordination agreement. The Company may pay interest and prepay principal so long as the Company is in compliance with its covenants; is not in default under the Senior Credit Facility and has minimum availability of $5.0 million under its borrowing base under the Senior Credit Facility. Shares of Class A common stock resulting from the conversion of the shares of Class B common stock issued as a result of the conversion right under the Oasis Note will be entitled to registration rights identical to the registration rights currently held by NuDevco Retail and Retailco on shares of Class A common stock it receives upon conversion of its existing shares of Class B
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common stock. On October 5, 2016, RAC issued to the Company an irrevocable commitment to convert the Oasis Note into 383,090 shares of Class B common stock. RAC assigned the Oasis Note to Retailco on January 4, 2017, and on January 31, 2017 the Oasis Note was converted into 383,090 shares of Class B common stock.
The conversion rate of $14.00 per share for the Oasis Note was fixed as of the date of the execution of the Oasis acquisition agreement on May 12, 2015. Due to a rise in the price of our common stock from May 12, 2015 to the closing of Oasis acquisition on July 31, 2015, the conversion rate of $14.00 per share was below the market price per share of Class A common stock of $16.21 on the issuance date of the Oasis Note on July 31, 2015. As a result, the Company assessed the Oasis Note for a beneficial conversion feature. Due to this conversion feature being "in-the-money" upon issuance, we recognized a beneficial conversion feature based on its intrinsic value of $0.8 million as a discount to the Oasis Note and as additional paid-in capital. This discount was amortized as interest expense under the effective interest method over the life of the Oasis Note through the conversion on January 31, 2017, at which time the remaining $1.0 million beneficial conversion feature was written-off and recognized as interest expense.
Subordinated Debt Facility
On December 27, 2016, we and Spark HoldCo jointly issued to Retailco, an entity owned by our Founder, a 5% subordinated note in the principal amount of up to $25.0 million. The subordinated note allows the Company and Spark HoldCo to draw advances in increments of no less than $1.0 million per advance up to the maximum principal amount of the subordinated note. The subordinated note matures approximately 3 ½ years following the date of issuance, and advances thereunder accrue interest at 5% per annum from the date of the advance. The Company has the right to capitalize interest payments under the subordinated note. The subordinated note is subordinated in certain respects to the Company's Senior Credit Facility pursuant to a subordination agreement. The Company may pay interest and prepay principal on the subordinated note so long as it is in compliance with its covenants under the Senior Credit Facility, is not in default under the Senior Credit Facility and has minimum availability of $5.0 million under the borrowing base under the Senior Credit Facility. Payment of principal and interest under the subordinated note is accelerated upon the occurrence of certain change of control or sale transactions. As of March 31, 2017, there were no outstanding borrowings under the subordinated note, and at December 31, 2016, there was $5.0 million in outstanding borrowings under the subordinated note.
Pacific Summit Energy LLC
Prior to March 31, 2017, the Major Energy Companies were party to three trade credit arrangements with Pacific Summit Energy LLC (“Pacific Summit”), which consisted of purchase agreements, operating agreements relating to purchasing terms, security agreements, lockbox agreements and guarantees, and provided for the exclusive supply of gas and electricity on credit by Pacific Summit to the Major Energy Companies for resale to end users.
Under these arrangements, when the costs that Pacific Summit paid to procure and deliver the gas and electricity exceeded the payments that the Major Energy Companies made attributable to the gas and electricity purchased, the Major Energy Companies incurred interest on the difference. The operating agreements also allowed Pacific Summit to provide credit support. Each form of borrowing incurred interest at the floating 90-day LIBOR rate plus 300 basis points (except for certain credit support guaranties that did not bear interest). In connection with these arrangements, the Major Companies granted first liens to Pacific Summit on a substantial portion of the Major Companies’ assets, including present and future accounts receivable, inventory, liquid assets, and control agreements relating to bank accounts. As of March 31, 2017, the Company had aggregate outstanding amounts payable under these arrangements of approximately $8.2 million, bearing an interest rate of approximately 4.2%. The Company was also the beneficiary under various credit support guarantees issued by Pacific Summit under these arrangements as of such date. On September 27, 2016, we notified Pacific Summit of our election to trigger the expiration of these arrangements. On March 31, 2017 the agreements were terminated.
9. Fair Value Measurements
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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 not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of the Company’s own nonperformance risk on its liabilities.
The Company applies fair value measurements to its commodity derivative instruments and a contingent payment arrangement based on the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:

• | Level 1—Quoted prices in active markets for identical assets and liabilities. Instruments categorized in Level 1 primarily consist of financial instruments such as exchange-traded derivative instruments.

• | Level 2—Inputs other than quoted prices recorded in Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 primarily include non-exchange traded derivatives such as over-the-counter commodity forwards and swaps and options.

• | Level 3—Unobservable inputs for the asset or liability, including situations where there is little, if any, observable market activity for the asset or liability. The Level 3 category includes estimated earnout obligations related to the Company's acquisitions.

As the fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3), the Company maximizes the use of observable inputs and minimizes the use of unobservable inputs when measuring fair value. 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 table presents assets and liabilities measured and recorded at fair value in the Company’s condensed consolidated balance sheets on a recurring basis by and their level within the fair value hierarchy as of (in thousands):

| Level 1 |  | Level 2 |  | Level 3 |  | Total
March 31, 2017 |  |  |  |  |  |  |
Non-trading commodity derivative assets | $ | 865 |  |  | $ | 1,515 |  |  | $ | — |  |  | $ | 2,380 |
Trading commodity derivative assets | — |  |  | 8 |  |  | — |  |  | 8 |
Total commodity derivative assets | $ | 865 |  |  | $ | 1,523 |  |  | $ | — |  |  | $ | 2,388 |
Non-trading commodity derivative liabilities | $ | (238 | ) |  | $ | (6,305 | ) |  | $ | — |  |  | $ | (6,543 | )
Trading commodity derivative liabilities | (124 | ) |  | (20 | ) |  | — |  |  | (144 | )
Total commodity derivative liabilities | $ | (362 | ) |  | $ | (6,325 | ) |  | $ | — |  |  | $ | (6,687 | )
Contingent payment arrangement | $ | — |  |  | $ | — |  |  | $ | (16,186 | ) |  | $ | (16,186 | )

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| Level 1 |  | Level 2 |  | Level 3 |  | Total
December 31, 2016 |  |  |  |  |  |  |
Non-trading commodity derivative assets | $ | 1,511 |  |  | $ | 9,385 |  |  | $ | — |  |  | $ | 10,896 |
Trading commodity derivative assets | 101 |  |  | 430 |  |  | — |  |  | 531 |
Total commodity derivative assets | $ | 1,612 |  |  | $ | 9,815 |  |  | $ | — |  |  | $ | 11,427 |
Non-trading commodity derivative liabilities | $ | — |  |  | $ | (661 | ) |  | $ | — |  |  | $ | (661 | )
Trading commodity derivative liabilities | — |  |  | (87 | ) |  | — |  |  | (87 | )
Total commodity derivative liabilities | $ | — |  |  | $ | (748 | ) |  | $ | — |  |  | $ | (748 | )
Contingent payment arrangement | $ | — |  |  | $ | — |  |  | $ | (22,653 | ) |  | $ | (22,653 | )

The Company had no transfers of assets or liabilities between any of the above levels during the three months ended March 31, 2017 and the year ended December 31, 2016.
The Company’s derivative contracts include exchange-traded contracts fair valued utilizing readily available quoted market prices and non-exchange-traded contracts fair valued using market price quotations available through brokers or over-the-counter and on-line exchanges. In addition, in determining the fair value of the Company’s derivative contracts, the Company applies a credit risk valuation adjustment to reflect credit risk which is calculated based on the Company’s or the counterparty’s historical credit risks. As of March 31, 2017 and December 31, 2016, the credit risk valuation adjustment was not material.
The contingent payment arrangements referred to above reflect estimated earnout obligations incurred in relation to the Company's acquisitions. As of March 31, 2017, the estimated earnout obligations were $16.2 million, which was comprised of the Provider Earnout, the Major Earnout and the Stock Earnout in the amount of $4.0 million, $11.4 million, and $0.8 million, respectively. As of December 31, 2016, the estimated earnout obligations were $22.7 million, which was comprised of the Provider Earnout, the Major Earnout and the Stock Earnout in the amount of $4.9 million, $17.1 million, and $0.7 million, respectively. As of March 31, 2017, the estimated earnouts are recorded on our condensed consolidated balance sheets in current liabilities - contingent consideration and long-term liabilities - contingent consideration in the amount of $12.1 million and $4.1 million, respectively; and as of December 31, 2016, in current liabilities - contingent consideration and long-term liabilities - contingent consideration in the amount of $11.8 million and $10.8 million, respectively.
The Provider Earnout is based on achievement by the Provider Companies of a certain customer count criteria over the nine month period following the closing of the Provider Companies acquisition. The sellers of the Provider Companies are entitled to a maximum of $9.0 million and a minimum of $5.0 million in earnout payments based on the level of customer count attained, as defined by the Provider Companies membership interest purchase agreement. In March 2017, the Company paid the sellers of the Provider Companies $1.0 million related to the earnout based on the achievement of certain customer count targets. During the three months ended March 31, 2017, the Company recorded accretion of $0.1 million to reflect the impact of the time value of the liability. The Company has revalued the liability at March 31, 2017 with no expected change of the earnout payments. In determining the fair value of the Provider Earnout, the Company forecasted an expected customer count and certain other related criteria and calculated the probability of such forecast being attained. As this calculation is based on management's estimates of the liability, we classified the Provider Earnout as a Level 3 measurement.
The Major Earnout is based on the achievement by the Major Energy Companies of certain performance targets over the 33 month period following NG&E's closing of the Major Energy Companies acquisition (i.e., April 15, 2016). The previous members of Major Energy Companies are entitled to a maximum of $20.0 million in earnout payments based on the level of performance targets attained, as defined by the Major Purchase Agreement. The Stock Earnout obligation is contingent upon the Major Energy Companies achieving the Major Earnout's performance target ceiling, thereby earning the maximum Major Earnout payments. If the Major Energy Companies earn such maximum Major Earnout payments, NG&E would be entitled to a maximum of 200,000 shares of Class B common stock (and a corresponding number of Spark HoldCo units). Based on the financial results of the Major Energy Companies during the first earnout period, NG&E was not entitled to receive an issuance of shares of Class
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B common stock (and a corresponding number of SparkHoldCo units). In determining the fair value of the Major Earnout and the Stock Earnout, the Company forecasted certain expected performance targets and calculated the probability of such forecast being attained. In March 2017, the Company paid the previous members of the Major Energy Companies $7.4 million related to the achievement of targets for the period from April 15, 2016 through December 31, 2016. During the three month period ended March 31, 2017, the Company recorded accretion of $1.2 million to reflect the impact of the time value of the liability. The Company revalued the liability at March 31, 2017, resulting in the increase of the fair value of the liability to $12.2 million. The impact of the $0.7 million increase in fair value is recorded in general and administrative expenses. As this calculation is based on management's estimates of the liability, we classified the Major Earnout as a Level 3 measurement.
The following tables present reconciliations of liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the years ended March 31, 2017 and December 31, 2016.

|  | Major Earnout and Stock Earnout |  | Provider Earnout |  | Total
Fair value at December 31, 2016 |  | $ | 17,760 |  |  | $ | 4,893 |  |  | $ | 22,653 |
Purchase price contingent consideration |  | $ | — |  |  | $ | — |  |  | $ | — |
Change in fair value of contingent consideration, net |  | 711 |  |  | — |  |  | 711 |
Accretion of contingent earnout consideration (included within interest expense) |  | 1,167 |  |  | 58 |  |  | 1,225 |
Settlements (1) |  | (7,403 | ) |  | (1,000 | ) |  | (8,403 | )
Fair Value at March 31, 2017 |  | $ | 12,235 |  |  | $ | 3,951 |  |  | $ | 16,186 |

(1) Settlements include pay downs at maturity
Other Financial Instruments
The carrying amount of cash and cash equivalents, accounts receivable, accounts receivable—affiliates, accounts payable, accounts payable—affiliates, and accrued liabilities recorded in the condensed consolidated balance sheets approximate fair value due to the short-term nature of these items. The carrying amount of the Senior Credit Facility recorded in the condensed consolidated balance sheets approximates fair value because of the variable rate nature of the Company’s line of credit. The fair value of our convertible subordinated notes to affiliates is not determinable for accounting purposes due to the affiliate nature and terms of the associated debt instrument with the affiliate. The fair value of the payable pursuant to tax receivable agreement—affiliate is not determinable for accounting purposes due to the affiliate nature and terms of the associated agreement with the affiliate.
10. Accounting for Derivative Instruments
The Company is exposed to the impact of market fluctuations in the price of electricity and natural gas and basis costs, storage and ancillary capacity charges from independent system operators. The Company uses derivative instruments to manage exposure to these risks, and historically designated certain derivative instruments as cash flow hedges for accounting purposes.
The Company holds certain derivative instruments that are not held for trading purposes and are not designated as hedges for accounting purposes. These derivative instruments represent economic hedges that mitigate the Company’s exposure to fluctuations in commodity prices. For these derivative instruments, changes in the fair value are recognized currently in earnings in retail revenues or retail cost of revenues.
As part of the Company’s strategy to optimize its assets and manage related risks, it also manages a portfolio of commodity derivative instruments held for trading purposes. The Company’s commodity trading activities are subject to limits within the Company’s Risk Management Policy. For these derivative instruments, changes in the fair value are recognized currently in earnings in net asset optimization revenues.
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Derivative assets and liabilities are presented net in the Company’s condensed consolidated balance sheets when the derivative instruments are executed with the same counterparty under a master netting arrangement. The Company’s 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 a third party. To the extent the Company has 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 March 31, 2017 and December 31, 2016, the Company had paid $0.3 million and zero in collateral outstanding, respectively. The specific types of derivative instruments the Company may execute to manage the commodity price risk include the following:

• | Forward contracts, which commit the Company 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 qualify for the normal purchase or normal sale exception and are therefore not accounted for at fair value, including the following:
•Forward electricity and natural gas purchase contracts for retail customer load, and
•Natural gas transportation contracts and storage agreements.
Volumetric Underlying Derivative Transactions
The following table summarizes the net notional volume buy/(sell) of the Company’s open derivative financial instruments accounted for at fair value, broken out by commodity, as of (in thousands):
Non-trading

Commodity | Notional |  | March 31, 2017 |  | December 31, 2016
Natural Gas | MMBtu |  | 9,136 |  |  | 8,016 |
Natural Gas Basis | MMBtu |  | — |  |  | — |
Electricity | MWh |  | 4,276 |  |  | 3,958 |

Trading

Commodity | Notional |  | March 31, 2017 |  | December 31, 2016
Natural Gas | MMBtu |  | 108 |  |  | (953 | )
Natural Gas Basis | MMBtu |  | — |  |  | (380 | )

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):
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| Three Months Ended March 31,
| 2017 |  | 2016
Loss on non-trading derivatives, net | (21,037 | ) |  | $ | (9,620 | )
Loss on trading derivatives, net | (419 | ) |  | (129 | )
Loss on derivatives, net | (21,456 | ) |  | (9,749 | )
Current period settlements on non-trading derivatives (1) (2) | 7,574 |  |  | 11,277 |
Current period settlements on trading derivatives | (160 | ) |  | (5 | )
Total current period settlements on derivatives | $ | 7,414 |  |  | $ | 11,272 |

(1) | Excludes settlements of less than $0.1 million and $(0.8) million, respectively, for the three months ended March 31, 2017 and 2016 related to non-trading derivative liabilities assumed in the acquisitions of CenStar and Oasis.

(2) | Excludes settlements of $(1.3) million for the three months ended March 31, 2017 related to non-trading derivative liabilities assumed in the acquisitions of the Provider Companies and Major Energy Companies.

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 the Company’s derivative instruments by counterparty and collateral received or paid as of (in thousands):

| March 31, 2017
Description | Gross Assets |  | Gross Amounts Offset |  | Net Assets |  | Cash Collateral Offset |  | Net Amount Presented
Non-trading commodity derivatives | $ | 4,436 |  |  | $ | (2,056 | ) |  | $ | 2,380 |  |  | $ | — |  |  | $ | 2,380 |
Trading commodity derivatives | (23 | ) |  | 31 |  |  | 8 |  |  | — |  |  | 8 |
Total Current Derivative Assets | $ | 4,413 |  |  | $ | (2,025 | ) |  | $ | 2,388 |  |  | $ | — |  |  | $ | 2,388 |
Non-trading commodity derivatives | $ | 60 |  |  | $ | (60 | ) |  | $ | — |  |  | $ | — |  |  | $ | — |
Total Non-current Derivative Assets | $ | 60 |  |  | $ | (60 | ) |  | $ | — |  |  | $ | — |  |  | $ | — |
Total Derivative Assets | $ | 4,473 |  |  | $ | (2,085 | ) |  | $ | 2,388 |  |  | $ | — |  |  | $ | 2,388 |

| March 31, 2017
Description | Gross Liabilities |  | Gross Amounts Offset |  | Net Liabilities |  | Cash Collateral Offset |  | Net Amount Presented
Non-trading commodity derivatives | $ | (11,015 | ) |  | $ | 9,012 |  |  | $ | (2,003 | ) |  | $ | 300 |  |  | $ | (1,703 | )
Trading commodity derivatives | (20 | ) |  | — |  |  | (20 | ) |  | — |  |  | (20 | )
Total Current Derivative Liabilities | $ | (11,035 | ) |  | $ | 9,012 |  |  | $ | (2,023 | ) |  | $ | 300 |  |  | $ | (1,723 | )
Non-trading commodity derivatives | $ | (7,605 | ) |  | $ | 2,765 |  |  | $ | (4,840 | ) |  | $ | — |  |  | $ | (4,840 | )
Trading commodity derivatives | $ | (240 | ) |  | $ | 116 |  |  | $ | (124 | ) |  | $ | — |  |  | $ | (124 | )
Total Non-current Derivative Liabilities | $ | (7,845 | ) |  | $ | 2,881 |  |  | $ | (4,964 | ) |  | $ | — |  |  | $ | (4,964 | )
Total Derivative Liabilities | $ | (18,880 | ) |  | $ | 11,893 |  |  | $ | (6,987 | ) |  | $ | 300 |  |  | $ | (6,687 | )

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| December 31, 2016
Description | Gross Assets |  | Gross Amounts Offset |  | Net Assets |  | Cash Collateral Offset |  | Net Amount Presented
Non-trading commodity derivatives | $ | 19,657 |  |  | $ | (11,844 | ) |  | $ | 7,813 |  |  | $ | — |  |  | $ | 7,813 |
Trading commodity derivatives | 614 |  |  | (83 | ) |  | 531 |  |  | — |  |  | 531 |
Total Current Derivative Assets | 20,271 |  |  | (11,927 | ) |  | 8,344 |  |  | — |  |  | 8,344 |
Non-trading commodity derivatives | 7,874 |  |  | (4,791 | ) |  | 3,083 |  |  | — |  |  | 3,083 |
Total Non-current Derivative Assets | 7,874 |  |  | (4,791 | ) |  | 3,083 |  |  | — |  |  | 3,083 |
Total Derivative Assets | $ | 28,145 |  |  | $ | (16,718 | ) |  | $ | 11,427 |  |  | $ | — |  |  | $ | 11,427 |

| December 31, 2016
Description | Gross Liabilities |  | Gross Amounts Offset |  | Net Liabilities |  | Cash Collateral Offset |  | Net Amount Presented
Non-trading commodity derivatives | $ | (662 | ) |  | $ | 69 |  |  | $ | (593 | ) |  | $ | — |  |  | $ | (593 | )
Trading commodity derivatives | (92 | ) |  | 5 |  |  | (87 | ) |  | — |  |  | (87 | )
Total Current Derivative Liabilities | (754 | ) |  | 74 |  |  | (680 | ) |  | — |  |  | (680 | )
Non-trading commodity derivatives | (305 | ) |  | 237 |  |  | (68 | ) |  | — |  |  | (68 | )
Total Non-current Derivative Liabilities | (305 | ) |  | 237 |  |  | (68 | ) |  | — |  |  | (68 | )
Total Derivative Liabilities | $ | (1,059 | ) |  | $ | 311 |  |  | $ | (748 | ) |  | $ | — |  |  | $ | (748 | )

11. Income Taxes
Income Taxes
The Company and CenStar are each subject to U.S. federal income tax as corporations. Spark HoldCo and its subsidiaries, with the exception of CenStar, 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, the Company is subject to U.S. federal income taxation on its allocable share of Spark HoldCo’s net U.S. taxable income.
The Company accounts for income taxes using the assets and liabilities 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 those assets and liabilities tax bases. The Company applies existing tax law and the tax rate that the Company expects 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.
The Company periodically assesses whether it is more likely than not that it will generate sufficient taxable income to realize its deferred income tax assets. In making this determination, the Company considers all available positive and negative evidence and makes certain assumptions. The Company considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends, and its outlook for future years. The Company believes it is more likely than not that the deferred tax assets will be utilized.
On February 3, 2016, Retailco exchanged 1,000,000 of its Spark HoldCo units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock. The exchange resulted in a step
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up in tax basis, which gave rise to a deferred tax asset of approximately $8.0 million on the exchange date. In addition, the Company recorded an additional long-term liability as a result of the exchange of approximately $10.3 million pursuant to the Tax Receivable Agreement and a corresponding long-term deferred tax asset of approximately $3.9 million. The initial estimate for the deferred tax asset, net of the liability, under the Tax Receivable Agreement was recorded within additional paid-in capital on our condensed consolidated balance sheet at December 31, 2016.
On April 1, 2016, Retailco exchanged 1,725,000 of its Spark HoldCo units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock. The exchange resulted in a step up in tax basis, which gave rise to a deferred tax asset of approximately $7.6 million on the exchange date. In addition, the Company recorded an additional long-term liability as a result of the exchange of approximately $10.3 million pursuant to the Tax Receivable Agreement and a corresponding long-term deferred tax asset of approximately $3.9 million. The initial estimate for the deferred tax asset, net of the liability, under the Tax Receivable Agreement was recorded within additional paid-in capital on our condensed consolidated balance sheet at December 31, 2016.
On June 8, 2016, Retailco exchanged 500,000 of its Spark HoldCo units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock. The exchange resulted in a step up in tax basis, which gave rise to a deferred tax asset of approximately $5.3 million on the exchange date. In addition, the Company recorded an additional long-term liability as a result of the exchange of approximately $6.9 million pursuant to the Tax Receivable Agreement and a corresponding long-term deferred tax asset of approximately $2.6 million. The initial estimate for the deferred tax asset, net of the liability, under the Tax Receivable Agreement was recorded within additional paid-in capital on our condensed consolidated balance sheet at December 31, 2016.
The Company had a net deferred tax asset of approximately $15.6 million related to the step up in tax basis resulting from the purchase by the Company of Spark HoldCo units from NuDevco Retail and NuDevco Retail Holdings (predecessor to Retailco) on the IPO date. In addition, as of March 31, 2017, the Company had a total liability of $49.9 million for the effect of the Tax Receivable Agreement liability classified as a long-term liability. The Company had a long-term deferred tax asset of approximately $19.7 million related to the Tax Receivable Agreement liability. See Note 13 "Transactions with Affiliates" for further discussion.
The effective U.S. federal and state income tax rate for the three months ended March 31, 2017 and 2016 is 17.4% and 5.9%, respectively, with respect to pre-tax income attributable to the Company's stockholders. The higher effective tax rate for the three months ended March 31, 2017 is primarily attributable to the tax treatment of Preferred Dividends and a decrease in the non-controlling interest. The decrease in non-controlling interest is primarily attributable to units exchanged by Retailco, which corresponds with an increase in taxable income allocable to the Company from Spark HoldCo that is subject to U.S. federal income taxation.
Total income tax expense for the three months ended March 31, 2017 differed from amounts computed by applying the U.S. federal statutory tax rates to pre-tax income primarily due to state taxes and the impact of permanent differences between book and taxable income, most notably the income attributable to non-controlling interest. The effective tax rate includes a rate benefit attributable to the fact that Spark HoldCo operates as a limited liability company 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’s taxable income. The February, April and June 2016 exchanges by Retailco decreased the effective tax rate benefit attributable to non-controlling interest.
12. Commitments and Contingencies
From time to time, the Company may be involved in legal, tax, regulatory and other proceedings in the ordinary course of business. Other than proceedings discussed below, management does not believe that we are a party to any litigation, claims or proceedings that will have a material impact on the Company’s condensed consolidated financial condition or results of operations. Liabilities for loss contingencies arising from claims, assessments, litigations or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.
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Indirect Tax Audits
The Company is undergoing various types of indirect tax audits spanning from years 2006 to 2016 for which the Company may have additional liabilities arise. At the time of filing these condensed 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 March 31, 2017, we have accrued $1.9 million related to indirect tax audits. The outcome of these indirect tax audits may result in additional expense.
Legal Proceedings
The Company is the subject of the following lawsuits. At the time of filing these combined and consolidated financial statements, this litigation is at an early stage and 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 this litigation or estimate a range of possible losses or a minimum loss that could result from an adverse verdict in a potential lawsuit.
John Melville et al v. Spark Energy Inc. and Spark Energy Gas, LLC is a purported class action filed on December 17, 2015 in the United States District Court for the District of New Jersey alleging, among other things, that (i) sales representatives engaged as independent contractors for Spark Energy Gas, LLC engaged in deceptive acts in violation of the New Jersey Consumer Fraud Act, (ii) Spark Energy Gas, LLC breach its contract with plaintiff, including a breach of the covenant of good faith and fair dealing. Plaintiffs are seeking unspecified compensatory and punitive damages for the purported class, injunctive relief and/or declaratory relief, disgorgement of revenues and/or profits and attorneys’ fees. Initial discovery is ongoing. Spark Energy Inc. and Spark Energy Gas, LLC intend to vigorously defend this matter and the allegations asserted therein. Given the early stages of this matter, we cannot predict the outcome or consequences of this case at this time.
Halifax-American Energy Company, LLC et al v. Provider Power, LLC, Electricity N.H., LLC, Electricity Maine, LLC, Emile Clavet and Kevin Dean is a lawsuit initially filed on June 12, 2014, in the Rockingham County Superior Court, State of New Hampshire, alleging various claims related to the Provider Companies’ employment of a sales contractor formerly employed with one or more of the plaintiffs, including misappropriation of trade secrets and tortious interference with a contractual relationship. The dispute occurred prior to the Company's acquisition of the Provider Companies. Portions of the original claim proceeded to trial and on January 19, 2016, a jury found in favor of the plaintiff. Damages totaling approximately $0.6 million and attorney’s fees totaling approximately $0.3 million were awarded to the plaintiff. On May 4, 2016, following post-verdict motions, the defendants filed an appeal in the State of New Hampshire Supreme Court, appealing, among other things the failure of the trial court to direct a verdict for the defendants, to set aside the verdict, or grant judgment for the defendants, and the trial court's award of certain attorneys' fees. As of December 31, 2016 and March 31, 2017, respectively, the Company has accrued approximately $1.0 million in contingent liabilities related to this litigation. Initial damages and attorney's fees have been factored into the purchase price for the Provider Companies, and the Company believes it has full indemnity coverage and set-off rights against future price installments for any actual exposure in the appeal.
Katherine Veilleux and Jennifer Chon, individually and on behalf of all other similarly situated v. Electricity Maine. LLC, Provider Power, LLC, Spark Holdco, LLC, Kevin Dean and Emile Clavet is a purported class action lawsuit filed on November 18, 2016 in the United States District Court of Maine, alleging that Electricity Maine, LLC, an entity acquired by Spark Holdco, LLC in mid-2016, enrolled customers through fraudulent and misleading advertising and promotions prior to the acquisition. Plaintiffs allege the following claims against all Defendants: violation of the Maine Unfair Trade Practices Act, violation of RICO, negligence, negligent misrepresentation, fraudulent misrepresentation, unjust enrichment and breach of contract. Plaintiffs seek unspecified damages for themselves and the purported class, rescission of contracts with Electricity Maine, injunctive relief, restitution, and attorney’s fees. Discovery has not yet commenced in this matter. Spark HoldCo intends to vigorously defend this matter and the allegations asserted therein. Given the early stages of this matter, we cannot predict the outcome or
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consequences of this case at this time. Under the terms of the acquisition, Spark HoldCo is indemnified for losses and expenses in connection with this action subject to certain limits.
Gillis et al. v. Respond Power, LLC is a purported class action lawsuit that was originally filed on May 21, 2014 in the Philadelphia Court of Common Pleas. On June 23, 2014, the case was removed to the United States District Court for the Eastern District of Pennsylvania. On September 15, 2014, the plaintiffs filed an amended class action complaint seeking a declaratory judgment that the disclosure statement contained in Respond Power, LLC’s variable rate contracts with Pennsylvania consumers limited the variable rate that could be charged to no more than the monthly rate charged by the consumers’ local utility company. The plaintiffs also allege that Respond Power, LLC (i) breached its variable rate contract with Pennsylvania consumers, and the covenant of good faith and fair dealing therein, by charging rates in excess of the monthly rate charged by the consumers’ local utility company; (ii) engaged in deceptive conduct in violation of the Pennsylvania Unfair Trade Practices and Consumer Protection Law; and (iii) engaged in negligent misrepresentation and fraudulent concealment in connection with purported promises of savings. The amount of damages sought is not specified. By order dated August 31, 2015, the district court denied class certification. The plaintiffs appealed the district court’s denial of class certification to the United States Court of Appeals for the Third Circuit. The United States Court of Appeals for the Third Circuit vacated the district court’s denial of class certification and remanded the matter to the district court for further proceedings. We currently cannot predict the outcome or consequences of this case at this time. The Company is indemnified for Major litigation matters, subject to certain limitations by original owners of the Major Energy Companies.
13. Transactions with Affiliates
The Company enters into transactions with and pays 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. The Company also sells and purchases natural gas and electricity with affiliates. The Company presents 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.
Master Service Agreement with Retailco Services, LLC
We entered into a Master Service Agreement (the “Master Service Agreement”) effective January 1, 2016 with Retailco Services, LLC ("Retailco Services"), which is wholly owned by our Founder. The Master Service Agreement is for a one-year term and renews automatically for successive one-year terms unless the Master Service Agreement is terminated by either party. Retailco Services provides us with operational support services such as: enrollment and renewal transaction services; customer billing and transaction services; electronic payment processing services; customer services and information technology infrastructure and application support services under the Master Service Agreement. See "Cost Allocations" for further discussion of the fees paid in connection with the Master Service Agreement during the three months ended March 31, 2017.
Accounts Receivable and Payable—Affiliates
The Company recorded current accounts receivable—affiliates of $2.0 million and $2.6 million as of March 31, 2017 and December 31, 2016, respectively, and current accounts payable—affiliates of $3.2 million and $3.8 million as of March 31, 2017 and December 31, 2016, respectively, for certain direct billings and cost allocations for services the Company provided to affiliates, services our affiliates provided to us, and sales or purchases of natural gas and electricity with affiliates.
Convertible Subordinated Notes to Affiliate
In connection with the financing of the CenStar acquisition, the Company, together with Spark HoldCo, issued the CenStar Note to Retailco Acquisition Co, LLC ("RAC"), which is wholly owned by our Founder, for $2.1 million on July 8, 2015. In connection with the financing of the Oasis acquisition, the Company, together with Spark HoldCo, issued the Oasis Note to RAC for $5.0 million on July 31, 2015. RAC converted the CenStar Note and the
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Oasis Note into shares of Class B common stock on January 8, 2017 and January 31, 2017, respectively. Refer to Note 8 "Debt" for further discussion.
Revenues and Cost of Revenues—Affiliates
The Company and an affiliate are party to an agreement whereby the Company purchases natural gas from an affiliate. Cost of revenues—affiliates, recorded in net asset optimization revenues in the condensed consolidated statements of operations for the three months ended March 31, 2017 and 2016 related to this agreement were zero and $1.3 million, respectively.
The Company also purchases natural gas at a nearby third-party plant inlet that is then sold to an affiliate. Revenues—affiliates, recorded in net asset optimization revenues in the condensed consolidated statements of operations for the three months ended March 31, 2017 and 2016 related to these sales were zero and $0.1 million, respectively.
Additionally, the Company entered into a natural gas transportation agreement with another affiliate at its pipeline, whereby the Company transports retail natural gas and pays the higher of (i) a minimum monthly payment or (ii) a transportation fee per MMBtu times actual volumes transported. The current transportation agreement renews annually on February 28 at a fixed rate per MMBtu without a minimum monthly payment. While this transportation agreement remains in effect, this entity is no longer an affiliate as our Founder terminated his interest in the affiliate on May 16, 2016. Cost of revenues—affiliates, recorded in retail cost of revenues in the condensed consolidated statements of operations related to this activity, was less than $0.1 million for the three months ended March 31, 2016.
Cost Allocations
The Company paid certain expenses on behalf of affiliates, which are reimbursed by the affiliates to the Company, and our affiliates paid certain expenses on our behalf, which are reimbursed by us. These transactions include costs that can be specifically identified and certain allocated overhead costs associated with general and administrative services, including executive management, due diligence work, recurring management consulting, facilities, banking arrangements, professional fees, insurance, information services, human resources and other support departments to the affiliates. Where costs incurred on behalf of the affiliate or us could not be determined by specific identification for direct billing, the costs were primarily allocated to the affiliated entities or us based on percentage of departmental usage, wages or headcount. The total net amount direct billed and allocated from affiliates was $7.4 million for the three months ended March 31, 2017.
Of the $7.4 million total net amount directly billed and allocated from affiliates, the Company recorded general and administrative expense of $7.3 million for the three months ended March 31, 2017 in the condensed consolidated statement of operations in connection with fees paid, net of damages charged, under the Master Service Agreement with Retailco Services. Additionally under the Master Service Agreement, we capitalized $0.1 million of property and equipment for the application, development and implementation of various systems during three months ended March 31, 2017.
The total net amount direct billed and allocated from affiliates was $5.0 million for the three months ended March 31, 2016, of which $4.4 million was recorded as general and administrative expense in the condensed consolidated statement of operations and $0.6 million was capitalized and amortized in accordance with our accounting policies.
Distributions to and Contributions from Affiliates
During the three months ended March 31, 2017 and 2016, the Company made net capital distributions to NuDevco Retail and Retailco of $3.9 million and $3.5 million, respectively, in conjunction with the payment of quarterly distributions attributable to its Spark HoldCo units. During the three months ended March 31, 2017, the Company made distributions to NuDevco Retail and Retailco for gross-up distributions of $0.5 million in connection with distributions made between Spark HoldCo and Spark Energy, Inc. for payment of income taxes incurred by Spark Energy, Inc.
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Proceeds from Disgorgement of Stockholder Short-swing Profits
During the three months ended March 31, 2017, the Company received $0.7 million cash for the disgorgement of stockholder short-swing profits under Section 16(b) under the Exchange Act accrued at December 31, 2016. The amount was recorded as an increase to additional paid-in capital in our condensed consolidated balance sheet as of December 31, 2016.
Class B Common Stock
In connection with the Major Energy Companies acquisition, the Company issued Retailco 2,000,000 shares of Class B common stock (and a corresponding number of Spark HoldCo units) to NG&E. In connection with the financing of the Provider Companies acquisition, the Company sold 699,742 shares of Class B common stock (and a corresponding number of Spark HoldCo units) to RetailCo, valued at $14.0 million based on a value of $20 per share.
Tax Receivable Agreement
The Company is party to a Tax Receivable Agreement with Spark HoldCo, NuDevco Retail Holdings and NuDevco Retail. This agreement generally provides for the payment by the Company to Retailco, LLC (as successor to NuDevco Retail Holdings) and NuDevco Retail of 85% of the net cash savings, if any, in U.S. federal, state and local income tax or franchise tax that the Company actually realizes (or is deemed to realize in certain circumstances) in future periods as a result of (i) any tax basis increases resulting from the purchase by the Company of Spark HoldCo units from NuDevco Retail Holdings, (ii) any tax basis increases resulting from the exchange of Spark HoldCo units for shares of Class A common stock pursuant to the Exchange Right (or resulting from an exchange of Spark HoldCo units for cash pursuant to the Cash Option) and (iii) any imputed interest deemed to be paid by the Company as a result of, and additional tax basis arising from, any payments the Company makes under the Tax Receivable Agreement. The Company retains the benefit of the remaining 15% of these tax savings. See Note 11 "Income Taxes" for further discussion.
In certain circumstances, the Company may defer or partially defer any payment due (a “TRA Payment”) to the holders of rights under the Tax Receivable Agreement, which are currently Retailco and NuDevco Retail. During the five-year period ending September 30, 2019, the Company will defer all or a portion of any TRA Payment owed pursuant to the Tax Receivable Agreement to the extent that Spark HoldCo does not generate sufficient Cash Available for Distribution (as defined below) during the four-quarter period ending September 30th of the applicable year in which the TRA Payment is to be made in an amount that equals or exceeds 130% (the “TRA Coverage Ratio”) of the Total Distributions (as defined below) paid in such four-quarter period by Spark HoldCo. For purposes of computing the TRA Coverage Ratio:

• | “Cash Available for Distribution” is generally defined as the Adjusted EBITDA of Spark HoldCo for the applicable period, less (i) cash interest paid by Spark HoldCo, (ii) capital expenditures of Spark HoldCo (exclusive of customer acquisition costs) and (iii) any taxes payable by Spark HoldCo; and

• | “Total Distributions” are defined as the aggregate distributions necessary to cause the Company to receive distributions of cash equal to (i) the targeted quarterly distribution the Company intends to pay to holders of its Class A common stock payable during the applicable four-quarter period, plus (ii) the estimated taxes payable by the Company during such four-quarter period, plus (iii) the expected TRA Payment payable during the calendar year for which the TRA Coverage Ratio is being tested.

In the event that the TRA Coverage Ratio is not satisfied in any calendar year, the Company will defer all or a portion of the TRA Payment to NuDevco Retail or Retailco under the Tax Receivable Agreement to the extent necessary to permit Spark HoldCo to satisfy the TRA Coverage Ratio (and Spark HoldCo is not required to make and will not make the pro rata distributions to its members with respect to the deferred portion of the TRA
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Payment). If the TRA Coverage Ratio is satisfied in any calendar year, the Company will pay NuDevco Retail or Retailco the full amount of the TRA Payment.
Following the five-year deferral period ending September 30, 2019, the Company will be obligated to pay any outstanding deferred TRA Payments to the extent such deferred TRA Payments do not exceed (i) the lesser of the Company's proportionate share of aggregate Cash Available for Distribution of Spark HoldCo during the five-year deferral period or the cash distributions actually received by the Company during the five-year deferral period, reduced by (ii) the sum of (a) the aggregate target quarterly dividends (which, for the purposes of the Tax Receivable Agreement, will be $0.3625 per share per quarter) during the five-year deferral period, (b) the Company's estimated taxes during the five-year deferral period, and (c) all prior TRA Payments and (y) if with respect to the quarterly period during which the deferred TRA Payment is otherwise paid or payable, Spark HoldCo has or reasonably determines it will have amounts necessary to cause the Company to receive distributions of cash equal to the target quarterly distribution payable during that quarterly period. Any portion of the deferred TRA Payments not payable due to these limitations will no longer be payable.
We met the threshold coverage ratio required to fund the first TRA Payment to Retailco and NuDevco Retail under the Tax Receivable Agreement during the four-quarter period ending September 30, 2016, resulting in an initial TRA Payment of $1.4 million becoming due in December 2016. On November 6, 2016, Retailco and NuDevco Retail granted the Company the right to defer the TRA Payment until May 2018. During the period of time when the Company has elected to defer the TRA payment, the outstanding payment amount will accrue interest at a rate calculated in the manner provided for under the Tax Receivable Agreement. We do not expect to meet the threshold coverage ratio required to fund the payment to Retailco, LLC under the Tax Receivable Agreement during the four-quarter period ending September 30, 2017. As such, the payment will be deferred pursuant to the terms thereof. The liability has been classified as non-current in our condensed consolidated balance sheet at March 31, 2017 and December 31, 2016.
14. Segment Reporting
The Company’s determination of reportable business segments considers the strategic operating units under which the Company makes financial decisions, allocates resources and assesses performance of its retail and asset optimization businesses.
The Company’s reportable business segments are retail natural gas and retail electricity. The retail natural gas segment consists of natural gas sales to, and natural gas transportation and distribution for, residential and commercial customers. Asset optimization activities, considered an integral part of securing the lowest price natural gas to serve retail gas load, are part of the retail natural gas segment. The Company recorded asset optimization revenues of $61.9 million and $42.3 million and asset optimization cost of revenues of $62.1 million and $41.8 million for the three months ended March 31, 2017 and 2016, respectively, which are presented on a net basis in asset optimization revenues. The retail electricity segment consists of electricity sales and transmission to residential and commercial customers. Corporate and other consists of expenses and assets of the retail natural gas and retail electricity segments that are managed at a consolidated level such as general and administrative expenses.
To assess the performance of the Company’s operating segments, the Chief Operating Decision Maker analyzes retail gross margin. The Company defines retail gross margin as operating income (loss) plus (i) depreciation and amortization expenses and (ii) general and administrative expenses, less (i) net asset optimization revenues (expenses), (ii) net gains (losses) on non-trading derivative instruments, and (iii) net current period cash settlements on non-trading derivative instruments. The Company deducts net gains (losses) on non-trading derivative instruments, excluding current period cash settlements, from the retail gross margin calculation in order to remove the non-cash impact of net gains and losses on non-trading derivative instruments.
Retail gross margin is a primary performance measure used by our management to determine the performance of our retail natural gas and electricity business by removing the impacts of our asset optimization activities and net non-cash income (loss) impact of our economic hedging activities. As an indicator of our retail energy business’
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operating performance, 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 March 31,
| 2017 |  | 2016
Reconciliation of Retail Gross Margin to Income before taxes |  |  |
Income before income tax expense | $ | 13,792 |  |  | $ | 16,729 |
Interest and other income | (199 | ) |  | 95 |
Interest expense | 3,445 |  |  | 753 |
Operating Income | 17,038 |  |  | 17,577 |
Depreciation and amortization | 9,232 |  |  | 6,789 |
General and administrative | 24,377 |  |  | 17,380 |
Less: |  |  |
Net asset optimization (expenses) revenues | (194 | ) |  | 527 |
Net, Losses on non-trading derivative instruments | (21,037 | ) |  | (9,620 | )
Net, Cash settlements on non-trading derivative instruments | 7,574 |  |  | 11,277 |
Retail Gross Margin | $ | 64,304 |  |  | $ | 39,562 |

The Company uses retail gross margin and net asset optimization revenues as the measure of profit or loss for its business segments. This measure represents the lowest level of information that is provided to the chief operating decision maker for our reportable segments.
Financial data for business segments are as follows (in thousands):

Three Months Ended March 31, 2017 | Retail Electricity |  | Retail Natural Gas |  | Corporate and Other |  | Eliminations |  | Spark Retail
Total Revenues | $ | 131,733 |  |  | $ | 62,612 |  |  | $ | — |  |  | $ | — |  |  | $ | 194,345 |
Retail cost of revenues | 106,780 |  |  | 36,918 |  |  | — |  |  | — |  |  | 143,698 |
Less: |  |  |  |  |  |  |  |  |
Net asset optimization expenses | — |  |  | (194 | ) |  | — |  |  | — |  |  | (194 | )
Losses on non-trading derivatives | (19,287 | ) |  | (1,750 | ) |  | — |  |  | — |  |  | (21,037 | )
Current period settlements on non-trading derivatives | 7,764 |  |  | (190 | ) |  | — |  |  | — |  |  | 7,574 |
Retail Gross Margin | $ | 36,476 |  |  | $ | 27,828 |  |  | $ | — |  |  | $ | — |  |  | $ | 64,304 |
Total Assets at March 31, 2017 | $ | 666,742 |  |  | $ | 272,045 |  |  | $ | 163,806 |  |  | $ | (736,776 | ) |  | $ | 365,817 |
Goodwill at March 31, 2017 | $ | 76,877 |  |  | $ | 2,530 |  |  | $ | — |  |  | $ | — |  |  | $ | 79,407 |

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Three Months Ended March 31, 2016 | Retail Electricity |  | Retail Natural Gas |  | Corporate and Other |  | Eliminations |  | Spark Retail
Total revenues | $ | 61,933 |  |  | $ | 48,613 |  |  | $ | — |  |  | $ | — |  |  | $ | 110,546 |
Retail cost of revenues | 46,300 |  |  | 22,500 |  |  | — |  |  | — |  |  | 68,800 |
Less: |  |  |  |  |  |  |  |  |
Net asset optimization revenues | — |  |  | 527 |  |  | — |  |  | — |  |  | 527 |
Losses on non-trading derivatives | (9,390 | ) |  | (230 | ) |  | — |  |  | — |  |  | (9,620 | )
Current period settlements on non-trading derivatives | 9,617 |  |  | 1,660 |  |  | — |  |  | — |  |  | 11,277 |
Retail Gross Margin | $ | 15,406 |  |  | $ | 24,156 |  |  | $ | — |  |  | $ | — |  |  | $ | 39,562 |
Total Assets at December 31, 2016 | $ | 577,695 |  |  | $ | 242,739 |  |  | $ | 169,404 |  |  | $ | (613,670 | ) |  | $ | 376,168 |
Goodwill at December 31, 2016 | $ | 76,617 |  |  | $ | 2,530 |  |  | $ | — |  |  | $ | — |  |  | $ | 79,147 |

15. Subsequent Events
Pacific Summit Energy LLC
On September 27, 2016, we notified Pacific Summit of our election to trigger the expiration of these arrangements as of March 31, 2017. On March 31, 2017, the Pacific Summit arrangements were terminated and the credit requirements of the Major Energy Companies are now being funded from our working capital.
Acquisition of Perigee
On April 1, 2017, the Company and Spark HoldCo entered into an agreement with NG&E for the acquisition of approximately 19,000 RCEs and the membership interests of Perigee Energy, LLC ("Perigee"), a Texas limited liability company, and simultaneously exercised an option to acquire an additional 41,000 RCEs from a third party in connection with the acquisition. The acquisition was approved by a special committee of the Board of Directors. The Company paid approximately $2.2 million in cash, subject to working capital adjustments as consideration for the Perigee Acquisition.
Declaration of Dividends
On April 19, 2017, the Company declared a quarterly dividend of $0.3625 to holders of record of our Class A common stock on May 30, 2017 and payable on June 14, 2017.
On April 19, 2017, the Company declared an initial cash dividend for the period from the date of issuance of the Series A Preferred Stock through June 30, 2017 in the amount of $0.72917 per share of Series A Preferred Stock. The dividend will be paid on July 15, 2017 to holders of record on July 1, 2017 of Spark's Class A Preferred Stock. The Company anticipates Series A Preferred Stock dividends paid and declared of $1.85 per share or $3.0 million for the year ended December 31, 2017 based on the Series A Preferred Stock outstanding as of March 31, 2017.
Verde Membership Interest and Stock Purchase Agreement
On May 5, 2017, the Company and CenStar Energy Corp. entered into a Membership Interest and Stock Purchase Agreement (the “Verde Purchase Agreement”) with Verde Energy USA Holdings, LLC (the “Seller”), as a seller of all interests in and to the Seller's operating companies (the “Verde Companies”). Pursuant to the terms of the Verde Purchase Agreement, CenStar Energy Corp. has agreed to purchase, and the Seller has agreed to sell, all of the outstanding membership interests and stock in the Verde Companies. The Company acts as a guarantor of the obligations of CenStar Energy Corp. under the Verde Purchase Agreement.
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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 combined and consolidated financial statements and notes thereto and management's discussion and analysis of financial condition and results of operations included in our Form 10-K for the year ended December 31, 2016 that was filed with the Securities and Exchange Commission (“SEC”). In this report, the terms “Spark Energy,” “Company,” “we,” “us” and “our” refer collectively to (i) the combined business and assets of the retail natural gas business and asset optimization activities of Spark Energy Gas, LLC and the retail electricity business of Spark Energy, LLC before the completion of our corporate reorganization in connection with the initial public offering of Spark Energy, Inc., which closed on August 1, 2014 (the “IPO”) and (ii) Spark Energy, Inc. and its subsidiaries as of the IPO and thereafter.
Cautionary Note Regarding Forward-Looking Statements
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,” “likely,” “will,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” “plan,” “intend,” “projects,” or other similar words. All statements, other than statements of historical fact included in this report, regarding strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans, objectives and beliefs of management are forward-looking statements. Forward-looking statements appear in a number of places in this report and may include statements about business strategy and prospects for growth, customer acquisition costs, ability to pay cash dividends, cash flow generation and liquidity, availability of terms of capital, competition and government regulation and general economic conditions. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot give any assurance that such expectations will prove correct.
The forward-looking statements in this report are subject to risks and uncertainties. Important factors that could cause actual results to materially differ from those projected in the forward-looking statements include, but are not limited to:

• | changes in commodity prices,

• | extreme and unpredictable weather conditions,

• | the sufficiency of risk management and hedging policies,

• | customer concentration,

• | federal, state and local regulation, including the industry's ability to prevail on its challenge to the New York Public Service Commission's order enacting new regulations that sought to impose significant new restrictions on retail energy providers operating in New York,

• | key license retention,

• | increased regulatory scrutiny and compliance costs,

• | 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,

• | level of indebtedness,

• | changes in costs to acquire customers,

• | actual customer attrition rates,

• | actual bad debt expense in non-POR markets,

• | actual results of the companies we acquire,

• | accuracy of billing systems,

• | ability to successfully navigate entry into new markets,

• | whether our majority stockholder or its affiliates offer us acquisition opportunities on terms that are commercially acceptable to us,

• | ability to successfully and efficiently integrate acquisitions into our operations,

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• | ability to achieve expected future results attributable to acquisitions,

• | competition, and

• | the "Risk Factors" in our Form 10-K for the year ended December 31, 2016 and 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.
Overview
Spark Energy, Inc. ("Spark Energy," "Company," "we" or "us") is a growing 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 their 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 March 31, 2017, we operated in 90 utility service territories across 18 states and the District of Columbia.
Our business consists of two operating segments:

• | Retail Natural Gas Segment. We purchase natural gas supply through physical and financial transactions with market counterparts and supply natural gas to residential and commercial consumers pursuant to fixed-price and variable-price contracts. For the three months ended March 31, 2017 and 2016, approximately 32% and 44%, respectively, of our retail revenues were derived from the sale of natural gas. We also identify wholesale natural gas arbitrage opportunities in conjunction with our retail procurement and hedging activities, which we refer to as asset optimization.

• | Retail Electricity Segment. We purchase electricity supply through physical and financial transactions with market counterparts and ISOs and supply electricity to residential and commercial consumers pursuant to fixed-price and variable-price contracts. For the three months ended March 31, 2017 and 2016, approximately 68% and 56%, respectively, of our retail revenues were derived from the sale of electricity.

Recent Developments
Issuance of Preferred Stock
On March 15, 2017, the Company issued 1,610,000 shares of 8.75% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock ("Series A Preferred Stock"), par value $0.01 per share and liquidation preference $25.00 per share, plus accumulated and unpaid dividends, at a price to the public of $25.00 per share ($24.21 per share to the Company, net of underwriting discounts and commissions). The Company received approximately $39.0 million in net proceeds from the offering, after deducting underwriting discounts and commissions and a structuring fee. The net proceeds from the offering were contributed to Spark HoldCo to use for general corporate purposes.
Acquisition of Perigee
Effective April 1, 2017, the Company and Spark HoldCo entered into an agreement with NG&E for the acquisition of approximately 19,000 RCEs and the membership interests of Perigee Energy, LLC, a Texas limited liability
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company, and simultaneously exercised an option to acquire an additional 41,000 RCEs from a third party in connection with the acquisition. The acquisition was approved by a special committee of the Board of Directors. The Company paid approximately $2.2 million in cash, subject to working capital adjustments, for Perigee.
Declaration of Dividends
On April 19, 2017, the Company declared a quarterly dividend of $0.3625 to holders of record of our Class A common stock on May 30, 2017 and payable on June 14, 2017.
On April 19, 2017, the Company declared a dividend of $0.72917 to holders of record of our Series A Preferred Stock on July 1, 2017 and payable on July 15, 2017.
Verde Membership Interest and Stock Purchase Agreement
On May 5, 2017, the Company and CenStar Energy Corp. entered into a Membership Interest and Stock Purchase Agreement (the “Verde Purchase Agreement”) with Verde Energy USA Holdings, LLC (the “Seller”), as a seller of all interests in Seller's operating subsidiaries (the “Verde Companies”). Pursuant to the terms of the Verde Purchase Agreement, CenStar Energy Corp. has agreed to purchase, and the Seller has agreed to sell, all of the outstanding membership interests and stock in the Verde Companies. The Company acts as a guarantor of the obligations of CenStar Energy Corp. under the Verde Purchase Agreement. For a more detailed description of the Verde Purchase Agreement, please see “Item 5. Other Information—Verde Membership Interest and Stock Purchase Agreement" in Part II of this Quarterly Report on Form 10-Q.
Residential Customer Equivalents
The following table shows activity of our residential customer equivalents ("RCEs") during the three months ended March 31, 2017:

RCEs: |  |  |  |  |
(In thousands) | December 31, 2016 | Additions | Attrition | March 31, 2017 | % Increase (Decrease)
Retail Electricity | 571 | 89 | (68) | 592 | 4%
Retail Natural Gas | 203 | 15 | (21) | 197 | (3)%
Total Retail | 774 | 104 | (89) | 789 | 2%

The following table details our count of RCEs by geographical location as of March 31, 2017:

RCEs by Geographic Location: |  |  |  |  |  |
(In thousands) | Electricity | % of Total | Natural Gas | % of Total | Total | % of Total
East | 471 | 80% | 114 | 58% | 585 | 74%
Midwest | 50 | 8% | 53 | 27% | 103 | 13%
Southwest | 71 | 12% | 30 | 15% | 101 | 13%
Total | 592 | 100% | 197 | 100% | 789 | 100%

The geographical regions noted above include the following states:

• | East - Connecticut, Florida, Maine, Maryland (including the District of Columbia), Massachusetts, New Hampshire, New Jersey, New York and Pennsylvania;

• | Midwest - Illinois, Indiana, Michigan and Ohio; and

• | Southwest - Arizona, California, Colorado, Nevada and Texas.

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Drivers of our Business
Customer Growth
Customer growth is a key driver of our operations. Our customer growth strategy includes acquiring customers through acquisitions as well as organically. We expect an emphasis on growth through acquisition to continue in 2017.
Acquisitions. Our acquisition strategy has two components. We independently acquire companies and portfolios of companies through some combination of cash, borrowings under the Acquisition Line of the Senior Credit Facility, or through the issuance of common or preferred stock or through financing arrangements with our Founder and his affiliates. Additionally, our Founder formed NG&E in 2015 for the purpose of purchasing retail energy companies and retail customer books that could ultimately be resold to us. We currently expect that we would fund any future transaction with some combination of cash, subordinated debt, or the issuance of Class A common stock or Class B common stock (and corresponding Spark HoldCo units) to NG&E. However, actual consideration will depend, among other things, on our capital structure and liquidity at the time of any transaction. There is no guarantee that NG&E will continue to offer us opportunities. Additionally, as we grow our access to capital and opportunities improves, we may rely less upon NG&E as a source of acquisitions and seek to enter into more transactions directly with third parties.
Our ability to grow at historic levels may be constrained if the market for acquisition candidates is limited and we are unable to make acquisitions of portfolios of customers and retail energy companies on commercially reasonable terms.
Organic Growth. Our organic sales strategies are used to both maintain and grow our customer base by offering competitive pricing, price certainty and/or green product offerings. 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 the local regulated utility is offering. 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 satisfies our profitability objectives and provides customer value. We develop marketing campaigns using a combination of sales channels, with an emphasis on door-to-door marketing and outbound telemarketing given their flexibility and historical effectiveness. We identify and acquire customers through a variety of additional sales channels, including our inbound customer care call center, online marketing, email, direct mail, affinity programs, direct sales, brokers and consultants. As we continue to grow our customer count, it is more difficult to achieve higher growth rates organically. Our marketing team continuously evaluates the effectiveness of each customer acquisition channel and makes adjustments in order to achieve desired growth and profitability targets.
We believe we can continue to grow organically, however achieving significant organic growth rates have become increasingly more difficult given our size, much of which is attributable to recent acquisitions. Additionally, increasing regulatory pressure on marketing channels, such as door-to-door and outbound telemarketing and the ability to manage customer acquisition costs, are significant factors in our ability to grow organically.
Customer Acquisition Costs Incurred
Management of customer acquisition costs is a key component to our profitability. Customer acquisition costs are spending for organic customer acquisitions and do not include customer acquisitions through acquisitions of businesses or portfolios of customer contracts, which are recorded as customer relationships.
We attempt to maintain a disciplined approach to recovery of our customer acquisition costs within defined periods. We capitalize and amortize our customer acquisition costs over a two year period, which is based on 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 spending.
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Customer acquisition cost for the three months ended March 31, 2017 was approximately $7.7 million. During the first quarter of 2017, we were able to both replace customers lost through attrition and achieve a net RCE increase of 15,000 through organic growth.
Our Ability to Manage Customer Attrition
Customer attrition is primarily due to: (i) customer initiated switches; (ii) residential moves and (iii) disconnection for customer payment defaults.
Customer attrition for the three months ended March 31, 2017 was 3.8%. Our customer attrition has been lower in recent quarters as we have increased our focus on the acquisition of higher lifetime value customers. We have also increased our customer win-back efforts, and have more aggressively pursued proactive renewals and other customer relationship strategies to maintain a low level of customer attrition.
Customer Credit Risk
Our bad debt expense for the three months ended March 31, 2017 was less than 1.0% of non-POR market retail revenues. An increased focus on collection efforts and timely billing along with tighter credit requirements for new enrollments in non-POR markets have led to a reduction in the bad debt expense over the past several months. We have also been able to collect on debts that were previously written off, which have further reduced our bad debt expense during the three months ended March 31, 2017.
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 because of our current substantial concentration and focus on growth in the residential customer segment in which energy usage is highly sensitive to weather conditions that impact heating and cooling demand. During the three months ended March 31, 2017, we experienced a milder than anticipated winter season, which negatively impacted overall customer usage that was offset by variations in customer mix.
Asset Optimization
Our natural gas business includes opportunistic transactions in the natural gas wholesale marketplace in conjunction with our retail procurement and hedging activities. Asset optimization opportunities primarily arise during the winter heating season when demand for natural gas is the highest. As such, the majority of our asset optimization profits are made in the winter. Given the opportunistic nature of these activities, we experience variability in our earnings from our asset optimization activities from year to year. As these activities are accounted for using mark to-market fair value accounting, the timing of our revenue recognition often differs from the actual cash settlement.
Net asset optimization results were a loss of $0.2 million for the three months ended March 31, 2017, primarily due to $0.4 million of our annual legacy demand charges allocated to the quarter, offset by arbitrage opportunities we captured during the three months ended March 31, 2017. During the full year 2017, we are obligated to pay demand charges of approximately $2.6 million under certain long-term legacy transportation assets that our predecessor entity acquired prior to 2013.
How We Evaluate Our Operations
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| Three Months Ended March 31,
(in thousands) | 2017 |  | 2016
Adjusted EBITDA | $ | 34,188 |  |  | $ | 21,061 |
Retail Gross Margin | $ | 64,304 |  |  | $ | 39,562 |

Adjusted EBITDA. We define “Adjusted EBITDA” as EBITDA less (i) customer acquisition costs incurred in the current period, (ii) net gain (loss) 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 provision for income taxes, interest expense and depreciation and amortization.
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 such costs and amortize them over two years in accordance with our accounting policies. The deduction of current period customer acquisition costs is consistent with how we manage our business, but the comparability of Adjusted EBITDA between periods may be affected by varying levels of customer acquisition costs. For example, our Adjusted EBITDA is lower in periods of customer growth reflecting larger customer acquisition spending.
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 derivative instruments. We also deduct non-cash compensation expense as a result of restricted stock units that are issued under our long-term incentive plan.
We believe that the presentation of Adjusted EBITDA provides information useful to investors in assessing our liquidity and financial condition and results of operations and that Adjusted EBITDA is also useful to investors as a financial indicator of our ability to incur and service debt, pay dividends and fund capital expenditures. Adjusted EBITDA is a supplemental financial measure that management and external users of our condensed consolidated financial statements, such as industry analysts, investors, commercial banks and rating agencies, use to assess the following:

• | our operating performance as compared to other publicly traded companies in the retail energy industry, without regard to financing methods, capital structure or historical cost basis;

• | the ability of our assets to generate earnings sufficient to support our proposed cash dividends; and

• | our ability to fund capital expenditures (including customer acquisition costs) and incur and service debt.

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 (i) net asset optimization revenues, (ii) net gains (losses) on non-trading derivative instruments, and (iii) net current period cash settlements on non-trading derivative instruments. 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 business by removing the impacts of our asset optimization activities and net non-cash income (loss) impact of our economic hedging activities. As an indicator of our retail energy business’ 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.
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The GAAP measures most directly comparable to Adjusted EBITDA are net income (loss) and net cash provided by operating activities. The GAAP measure most directly comparable to Retail Gross Margin is operating income (loss). 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 operating activities, or operating income (loss). Adjusted EBITDA and Retail Gross Margin are not presentations made in accordance with GAAP and have important 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) and net cash provided by operating activities, 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.
The following table presents a reconciliation of Adjusted EBITDA to net income (loss) for each of the periods indicated.

| Three Months Ended March 31,
(in thousands) | 2017 |  | 2016
Reconciliation of Adjusted EBITDA to Net Income (Loss): |  |  |
Net income | $ | 11,386 |  |  | $ | 15,741 |
Depreciation and amortization | 9,232 |  |  | 6,789 |
Interest expense | 3,445 |  |  | 753 |
Income tax expense | 2,406 |  |  | 988 |
EBITDA | 26,469 |  |  | 24,271 |
Less: |  |  |
Net, Losses on derivative instruments | (21,456 | ) |  | (9,749 | )
Net, Cash settlements on derivative instruments | 7,414 |  |  | 11,272 |
Customer acquisition costs | 7,690 |  |  | 2,305 |
Plus: |  |  |  |  |
Non-cash compensation expense | 1,367 |  |  | 618 |
Adjusted EBITDA | $ | 34,188 |  |  | $ | 21,061 |

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The following table presents a reconciliation of Adjusted EBITDA to net cash provided by (used in) operating activities for each of the periods indicated.

| Three Months Ended March 31,
(in thousands) | 2017 |  | 2016
Reconciliation of Adjusted EBITDA to net cash provided by operating activities: |  |  |
Net cash provided by operating activities | $ | 24,380 |  |  | $ | 25,502 |
Amortization of deferred financing costs | (248 | ) |  | (117 | )
Allowance for doubtful accounts and bad debt expense | (356 | ) |  | (907 | )
Interest expense | 3,445 |  |  | 753 |
Income tax expense | 2,406 |  |  | 988 |
Changes in operating working capital |  |  |
Accounts receivable, prepaids, current assets | (1,729 | ) |  | (3,607 | )
Inventory | (3,322 | ) |  | (3,484 | )
Accounts payable and accrued liabilities | 9,906 |  |  | 5,391 |
Other | (294 | ) |  | (3,458 | )
Adjusted EBITDA | $ | 34,188 |  |  | $ | 21,061 |
Cash Flow Data: |  |  |
Cash flows provided by operating activities | $ | 24,380 |  |  | $ | 25,502 |
Cash flows used in investing activities | (9,612 | ) |  | (833 | )
Cash flows used in financing activities | (8,797 | ) |  | (26,194 | )

The following table presents a reconciliation of Retail Gross Margin to operating income (loss) for each of the periods indicated.

| Three Months Ended March 31,
(in thousands) | 2017 |  | 2016
Reconciliation of Retail Gross Margin to Operating Income (Loss): |  |  |
Operating income | $ | 17,038 |  |  | $ | 17,577 |
Depreciation and amortization | 9,232 |  |  | 6,789 |
General and administrative | 24,377 |  |  | 17,380 |
Less: |  |  |
Net asset optimization (expenses) revenues | (194 | ) |  | 527 |
Net, Losses on non-trading derivative instruments | (21,037 | ) |  | (9,620 | )
Net, Cash settlements on non-trading derivative instruments | 7,574 |  |  | 11,277 |
Retail Gross Margin | $ | 64,304 |  |  | $ | 39,562 |
Retail Gross Margin - Retail Natural Gas Segment | $ | 27,828 |  |  | $ | 24,156 |
Retail Gross Margin - Retail Electricity Segment | $ | 36,476 |  |  | $ | 15,406 |

Consolidated Results of Operations
Three Months Ended March 31, 2017 Compared to Three Months Ended March 31, 2016
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(In Thousands) | Three Months Ended March 31, |  |
| 2017 |  | 2016 |  | Change
Revenues: |  |  |  |  |
Retail revenues | $ | 194,539 |  |  | $ | 110,019 |  |  | $ | 84,520 |
Net asset optimization (expense)/revenues | (194 | ) |  | 527 |  |  | (721 | )
Total Revenues | 194,345 |  |  | 110,546 |  |  | 83,799 |
Operating Expenses: |  |  |  |  |  |  |  |
Retail cost of revenues | 143,698 |  |  | 68,800 |  |  | 74,898 |
General and administrative | 24,377 |  |  | 17,380 |  |  | 6,997 |
Depreciation and amortization | 9,232 |  |  | 6,789 |  |  | 2,443 |
Total Operating Expenses | 177,307 |  |  | 92,969 |  |  | 84,338 |
Operating income (loss) | 17,038 |  |  | 17,577 |  |  | (539 | )
Other (expense)/income: |  |  |  |  |  |  |  |
Interest expense | (3,445 | ) |  | (753 | ) |  | (2,692 | )
Interest and other income | 199 |  |  | (95 | ) |  | 294 |
Total other expenses/(income) | (3,246 | ) |  | (848 | ) |  | (2,398 | )
Income (loss) before income tax expense | 13,792 |  |  | 16,729 |  |  | (2,937 | )
Income tax expense (benefit) | 2,406 |  |  | 988 |  |  | 1,418 |
Net income (loss) | $ | 11,386 |  |  | $ | 15,741 |  |  | $ | (4,355 | )
Adjusted EBITDA (1) | $ | 34,188 |  |  | $ | 21,061 |  |  | $ | 13,127 |
Retail Gross Margin (1) | 64,304 |  |  | 39,562 |  |  | 24,742 |
Customer Acquisition Costs | 7,690 |  |  | 2,305 |  |  | 5,385 |
RCE Attrition | 3.8 | % |  | 4.3 | % |  | (0.5)% |

(1) | Adjusted EBITDA and Retail Gross Margin are non-GAAP financial measures. See “—How We Evaluate Our Operations” for a reconciliation of Adjusted EBITDA and Retail Gross Margin to their most directly comparable financial measures presented in accordance with GAAP.

Total Revenues. Total revenues for the three months ended March 31, 2017 were approximately $194.3 million, an increase of approximately $83.8 million, or 76%, from approximately $110.5 million for the three months ended March 31, 2016, as indicated in the table below (in millions). This increase was primarily due to an increase in electricity and natural gas volumes driven by the acquisitions of the Provider Companies and Major Energy Companies, partially offset by decreased electricity pricing and natural gas pricing.

Change in electricity volumes sold | $ | 81.7 |
Change in natural gas volumes sold | 16.1 |
Change in electricity unit revenue per MWh | (11.9 | )
Change in natural gas unit revenue per MMBtu | (1.4 | )
Change in net asset optimization revenue | (0.7 | )
Change in total revenues | $ | 83.8 |

Retail Cost of Revenues. Total retail cost of revenues for the three months ended March 31, 2017 was approximately $143.7 million, an increase of approximately $74.9 million, or 109%, from approximately $68.8 million for the three months ended March 31, 2016, as indicated in the table below (in millions). This increase was primarily due to an increase in electricity and natural gas volumes driven by the acquisitions of the Provider Companies and Major Energy Companies, partially offset by decreased electricity pricing.
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Change in electricity volumes sold | $ | 61.4 |
Change in natural gas volumes sold | 8.0 |
Change in electricity unit cost per MWh | (12.7 | )
Change in natural gas unit cost per MMBtu | 3.0 |
Change in value of retail derivative portfolio | 15.2 |
Change in retail cost of revenues | $ | 74.9 |

General and Administrative Expense. General and administrative expense for the three months ended March 31, 2017 was approximately $24.4 million, an increase of approximately $7.0 million, or 40%, as compared to $17.4 million for the three months ended March 31, 2016. This increase was primarily attributable to increased billing and other variable costs associated with increased RCEs as a result of the acquisitions of the Provider Companies and the Major Energy Companies and increased stock-based compensation associated with higher stock prices and additional equity awards, partially offset by a reduction in bad debt expense as we had better than anticipated collections as a result of new collection initiatives.
Depreciation and Amortization Expense. Depreciation and amortization expense for the three months ended March 31, 2017 was approximately $9.2 million, an increase of approximately $2.4 million, or 35%, from approximately $6.8 million for the three months ended March 31, 2016. This increase was primarily due to the increased amortization expense associated with customer intangibles from the acquisitions of the Provider Companies and the Major Energy Companies.
Customer Acquisition Cost. Customer acquisition cost for the three months ended March 31, 2017 was approximately $7.7 million, an increase of approximately $5.4 million, or 235%, from approximately $2.3 million for the three months ended March 31, 2016. This increase was primarily due to customer acquisition costs of the Major Energy Companies and Provider Companies of $3.1 million and $0.2 million, respectively, and increased organic sales of $2.1 million.
Operating Segment Results

| Three Months Ended March 31,
| 2017 |  | 2016
| (in thousands, except volume and per unit operating data)
Retail Natural Gas Segment |  |  |
Total Revenues | $ | 62,612 |  |  | $ | 48,613 |
Retail Cost of Revenues | 36,918 |  |  | 22,500 |
Less: Net Asset Optimization (Expenses) Revenues | (194 | ) |  | 527 |
Less: Net Gains on non-trading derivatives, net of cash settlements | (1,940 | ) |  | 1,430 |
Retail Gross Margin (1) — Gas | $ | 27,828 |  |  | $ | 24,156 |
Volumes — Gas (MMBtus) | 8,158,966 |  |  | 6,112,431 |
Retail Gross Margin (2) — Gas per MMBtu | $ | 3.41 |  |  | $ | 3.95 |
Retail Electricity Segment |  |  |
Total Revenues | $ | 131,733 |  |  | $ | 61,933 |
Retail Cost of Revenues | 106,780 |  |  | 46,300 |
Less: Net Gains (Losses) on non-trading derivatives, net of cash settlements | (11,523 | ) |  | 227 |
Retail Gross Margin (1) — Electricity | $ | 36,476 |  |  | $ | 15,406 |
Volumes — Electricity (MWhs) | 1,360,430 |  |  | 586,677 |
Retail Gross Margin (2) — Electricity per MWh | $ | 26.81 |  |  | $ | 26.26 |

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(1) | Reflects the Retail Gross Margin attributable to our Retail Natural Gas Segment or Retail Electricity Segment, as applicable. Retail Gross Margin is a non-GAAP financial measure. See “How We Evaluate Our Operations” for a reconciliation of Adjusted EBITDA and Retail Gross Margin to their most directly comparable financial measures presented in accordance with GAAP.

(2) | Reflects the Retail Gross Margin for the Retail Natural Gas Segment or Retail Electricity Segment, as applicable, divided by the total volumes in MMBtu or MWh, respectively.

Three Months Ended March 31, 2017 Compared to Three Months Ended March 31, 2016
Retail Natural Gas Segment
Total revenues for the Retail Natural Gas Segment for the three months ended March 31, 2017 were approximately $62.6 million, an increase of approximately $14.0 million, or 29%, from approximately $48.6 million for the three months ended March 31, 2016. This increase was primarily attributable to an increase in customer sales volumes resulting from the acquisition of Major Energy Companies, which increased total revenues by $16.1 million. This increase was partially offset by lower rates driven by the lower commodity pricing environment, which resulted in a decrease in total revenues of $1.4 million, and a decrease of $0.7 million in net asset optimization revenues.
Retail cost of revenues for the Retail Natural Gas Segment for the three months ended March 31, 2017 were approximately $36.9 million, an increase of $14.4 million, or 64%, from approximately $22.5 million for the three months ended March 31, 2016. This increase was primarily due to the addition of customers through our Major Energy Companies acquisition, which resulted in an increase of $8.0 million, increased supply costs, which resulted in an increase of $3.0 million, and a change in the value of our retail derivative portfolio used for hedging, which resulted in an increase of $3.4 million.
Retail gross margin for the Retail Natural Gas Segment for the three months ended March 31, 2017 was approximately $27.8 million, an increase of approximately $3.6 million, or 15%, from approximately $24.2 million for the three months ended March 31, 2016, as indicated in the table below (in millions).

Change in volumes sold | $ | 8.1 |
Change in unit margin per MMBtu | (4.5 | )
Change in retail natural gas segment retail gross margin | $ | 3.6 |

Retail Electricity Segment
Total revenues for the Retail Electricity Segment for the three months ended March 31, 2017 were approximately $131.7 million, an increase of approximately $69.8 million, or 113%, from approximately $61.9 million for the three months ended March 31, 2016. This increase was largely because of an increase in volumes, primarily due to our acquisition of the Major Energy Companies and the Provider Companies, as well as organic growth in the East, resulting in an increase of $81.7 million. This increase was partially offset by lower customer pricing, driven by the lower commodity pricing environment from milder than anticipated weather, which resulted in a decrease of $11.9 million.
Retail cost of revenues for the Retail Electricity Segment for the three months ended March 31, 2017 were approximately $106.8 million, an increase of approximately $60.5 million, or 131%, from approximately $46.3 million for the three months ended March 31, 2016. This increase was primarily due to an increase in volume as a result of the acquisitions of the Major Energy Companies and the Provider Companies, as well as organic growth in the East, resulting in an increase of $61.4 million. We additionally recognized a change in the value of our retail derivative portfolio used for hedging, which resulted in an increase of $11.8 million. These increases were partially offset by decreased supply costs, which resulted in a decrease of $12.7 million.
Retail gross margin for the Retail Electricity Segment for the three months ended March 31, 2017 was approximately $36.5 million, an increase of approximately $21.1 million, or 137%, from approximately $15.4 million for the three months ended March 31, 2016, as indicated in the table below (in millions).
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Change in volumes sold | $ | 20.3 |
Change in unit margin per MWh | 0.8 |
Change in retail electricity segment retail gross margin | $ | 21.1 |

Liquidity and Capital Resources
Our liquidity requirements fluctuate with our customer acquisition costs, acquisitions, collateral posting requirements on our derivative instruments portfolio, distributions, the effects of the timing between payments of payables and receipts of receivables, including bad debt receivables, and our general working capital needs for ongoing operations. Our borrowings under the Senior Credit Facility are also subject to material variations on a seasonal basis due to the timing of commodity purchases to satisfy required natural gas inventory purchases and to meet customer demands during periods of peak usage. Moreover, estimating our liquidity requirements is highly dependent on then-current market conditions, including forward prices for natural gas and electricity, and market volatility.
Our primary sources of liquidity are cash generated from operations and borrowings under our Senior Credit Facility. We believe that cash generated from these sources will be sufficient to sustain current operations and to pay required taxes and quarterly cash distributions including the quarterly dividend to the holders of the Class A common stock for the next twelve months.
We amended and restated the Senior Credit Facility on July 8, 2015. The amended covenants under the Senior Credit Facility require us to hold increasing levels of net working capital over time. The Senior Credit Facility, as amended, includes a $25 million secured revolving line of credit ("Acquisition Line") for the purpose of financing permitted acquisitions, which enables us to pursue growth through mergers and acquisitions. We are obligated to make payments outstanding under the Acquisition Line of 25% per year, which in turn increases availability under the line, with the balance due at maturity. We will be constrained in our ability to grow through acquisitions using financing under the Senior Credit Facility to the extent we have utilized the capacity under this Acquisition Line. In addition, the Senior Credit Facility requires us to finance permitted acquisitions with at least 25% of either cash on hand, equity contributions or subordinated debt. In order to finance the acquisitions of Oasis and CenStar, we have
issued convertible subordinated notes to an affiliate of our Founder and majority shareholder. There can be no assurance that our Founder and majority shareholder and their affiliates will continue to finance our acquisition activities through such notes. The Senior Credit Facility will mature on July 8, 2017. We are in the process of negotiating a new credit facility, which we expect to have similar terms as our current Senior Credit Facility, however this cannot be assured.
On October 7, 2016, we filed a registration statement under the Securities Act on Form S-3 covering offers and sales, from time to time, by us of up to $200,000,000 of Class A common stock, preferred stock, depositary shares and warrants, and by the selling stockholders named therein of up to 11,339,563 shares of Class A common stock. The registration statement was declared effective on October 20, 2016.
On December 27, 2016, we entered into the $25.0 million Subordinated Facility with Retailco, which is wholly owned by our Founder. Please see "—Subordinated Debt Facility" for a description of the Subordinated Facility.
On March 8, 2017, the Company entered into an underwriting agreement, pursuant to which the Company agreed to sell up to 1,610,000 shares of Series A Preferred Stock, par value $0.01 per share and $25.00 per share liquidation preference, plus accumulated and unpaid dividends, at a price of $25.00 per share to the public ($24.21 per share of Series A Preferred Stock to the Company, net of underwriting discounts and commissions). The Company issued 1,610,000 shares of Series A Preferred Stock in exchange for $39.0 million (net of underwriting discounts and commissions) on March 15, 2017.
Based upon our current plans, level of operations and business conditions, we believe that our cash on hand, cash generated from operations, and available borrowings under the Senior Credit Facility (including any renegotiation
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thereof) and Subordinated Debt Facility will be sufficient to meet our capital requirements and working capital needs. We believe that the financing of any additional growth through acquisitions in 2017 may require further equity financing and/or further expansion of our Senior Credit Facility to accommodate such growth.
The following table details our total liquidity as of the date presented:

($ in thousands) | March 31, 2017
Cash and cash equivalents | $ | 24,931 |
Senior Credit Facility Working Capital Line Availability (1) | 43,172 |
Senior Credit Facility Acquisition Line Availability (2) | 2,763 |
Subordinated Debt Availability | 25,000 |
Total Liquidity | $ | 95,866 |

(1) Subject to Senior Credit Facility borrowing base restrictions. See “—Cash Flows—Senior Credit Facility.”
(2) Subject to Senior Credit Facility covenant restrictions. See “—Cash Flows—Senior Credit Facility.”
Capital expenditures for the three months ended March 31, 2017 included approximately $7.7 million for customer acquisitions and $0.1 million related to information systems improvements.
The Spark HoldCo, LLC Agreement provides, to the extent cash is available, for distributions to the holders of Spark HoldCo units such that we receive an amount of cash sufficient to cover the estimated taxes payable by us, the targeted quarterly dividend we intend to pay to holders of our Class A common stock, the quarterly dividends on our Series A Preferred Stock, and payments under the Tax Receivable Agreement we have entered into with Spark HoldCo, Retailco and NuDevco Retail.
During the three months ended March 31, 2017, we paid dividends to holders of our Class A common stock for the three months ended December 31, 2016 of approximately $0.3625 per share or $2.4 million in the aggregate. On April 19, 2017, our Board of Directors declared a quarterly dividend of $0.3625 per share for the first quarter of 2017 to holders of the Class A common stock on May 30, 2017. This dividend will be paid on June 14, 2017. The dividends that we anticipate paying on an annualized basis equal approximately $1.45 per share or $9.4 million in the aggregate on an annualized basis based on the Class A common stock outstanding at March 31, 2017. Our ability to pay dividends in the future will depend on many factors, including the performance of our business in the future and restrictions under our Senior Credit Facility. The financial covenants included in the Senior Credit Facility require the Company to retain increasing amounts of working capital over time, which may have the effect of restricting our ability to pay dividends. Management does not currently believe that the financial covenants in the Senior Credit Facility will cause any such restrictions.
In order to pay our stated dividends to holders of our Class A common stock and corresponding distributions to holders of our non-controlling interest, Spark HoldCo generally is required to distribute approximately $15.6 million on an annualized basis to holders of its Spark HoldCo units. If our business does not generate enough cash for Spark HoldCo to make such distributions, we may have to borrow to pay our dividend. If our business generates cash in excess of the amounts required to pay an annual dividend of $1.45 per share of Class A common stock, we currently expect to reinvest any such excess cash flows in our business and not increase the dividends payable to holders of our Class A common stock. However, our future dividend policy is within the discretion of our Board of Directors and will depend upon various factors, including the results of our operations, our financial condition, capital requirements and investment opportunities.
In accordance with the terms of the Series A Preferred Stock, our Board of Directors declared an initial cash dividend for the period from the date of issuance of the Series A Preferred Stock through June 30, 2017 in the amount of $0.72917 per share of the Series A Preferred Stock. The dividend will be paid on July 15, 2017 to holders of record on July 1, 2017 of the Company's Series A Preferred Stock. The Company anticipates Series A Preferred Stock dividends paid and declared for the year ended December 31, 2017 of $1.85 per share or $3.0 million based on the Series A Preferred Stock outstanding as of March 31, 2017.
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We expect to make payments pursuant to the Tax Receivable Agreement that we have entered into with Retailco LLC (as assignee of NuDevco Retail Holdings), NuDevco Retail and Spark HoldCo in connection with our IPO. Except in cases where we elect to terminate the Tax Receivable Agreement early (or the Tax Receivable Agreement is terminated early due to certain mergers or other changes of control) or we have available cash but fail to make payments when due, generally we may elect to defer payments due under the Tax Receivable Agreement for up to five years if we do not have available cash to satisfy our payment obligations under the Tax Receivable Agreement or if our contractual obligations limit our ability to make these payments. Any such deferred payments under the Tax Receivable Agreement generally will accrue interest. If we were to defer substantial payment obligations under the Tax Receivable Agreement on an ongoing basis, the accrual of those obligations would reduce the availability of cash for other purposes, but we would not be prohibited from paying dividends on our Class A common stock.
We did not meet the threshold coverage ratio required to fund the first payment to NuDevco Retail Holdings under the Tax Receivable Agreement during the four-quarter period ending September 30, 2015. As such, the initial payment under the Tax Receivable Agreement due in late 2015 was deferred pursuant to the terms thereof.
We met the threshold coverage ratio required to fund the first TRA Payment to Retailco and NuDevco Retail under the Tax Receivable Agreement during the four-quarter period ending September 30, 2016, resulting in an initial TRA Payment of $1.4 million becoming due in December 2016. On November 6, 2016, Retailco and NuDevco Retail granted us the right to defer the TRA Payment until May 2018. During the period of time when we have elected to defer the TRA Payment, the outstanding payment amount will accrue interest at a rate calculated in the manner provided for under the Tax Receivable Agreement. The liability has been classified as non-current in our condensed consolidated balance sheet at March 31, 2017. See Note 13 "Transactions with Affiliates" in the notes to our condensed consolidated financial statements for additional details on the Tax Receivable Agreement. See also “Risk Factors—Risks Related to our Class A Common Stock” in our Annual Report on Form 10-K for the year ended December 31, 2016 for risks related to the Tax Receivable Agreement.
We do not expect to meet the threshold coverage ratio required to fund the payment to Retailco, LLC under the Tax Receivable Agreement during the four-quarter period ending September 30, 2017. As such the payment of $1.9 million under the Tax Receivable Agreement due in late 2017 will be deferred pursuant to the terms thereof.
Pacific Summit Energy LLC
Prior to March 31, 2017, the Major Energy Companies were party to three trade credit arrangements with Pacific Summit Energy LLC (“Pacific Summit”), which consisted of purchase agreements, operating agreements relating to purchasing terms, security agreements, lockbox agreements and guarantees, and provided for the exclusive supply of gas and electricity on credit by Pacific Summit to the Major Energy Companies for resale to end users.
The arrangements allowed the Major Energy Companies to purchase gas and electricity on credit at fixed prices or prices to be determined at the time of the transaction confirmation. Under the arrangements, when the costs that Pacific Summit paid to procure and deliver the gas and electricity exceeded the payments that the Major Energy Companies made attributable to the gas and electricity purchased, the Major Energy Companies incurred interest on the difference at the floating 90-day LIBOR rate plus 300 basis points. The outstanding balance of the difference may not have exceeded $15.0 million for Major Energy Services, LLC, and $20.0 million for each of Major Energy Electric Services, LLC and Respond Power, LLC. The operating agreements also allowed Pacific Summit to provide credit support, with a limit of $10.0 million for Major Energy Services, LLC and $20.0 million for each of Major Energy Electric Services, LLC and Respond Power, LLC, which also incurred interest at the floating 90-day LIBOR rate plus 300 basis points (except for certain credit support guaranties that do not bear interest). In connection with these arrangements, the Major Companies granted first liens to Pacific Summit on a substantial portion of the Major Companies’ assets, including present and future accounts receivable, inventory, liquid assets, and control agreements relating to bank accounts. As of March 31, 2017, we had aggregate outstanding payables under these arrangements of approximately $8.2 million, bearing an interest rate of 4.2%. We were also the beneficiary of various credit support guarantees issued by Pacific Summit under these arrangements as of such date.
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Pursuant to the operating agreements and the lockbox agreements, payments from the Major Energy Companies were placed into a secured lockbox. The Major Energy Companies were required to maintain a minimum balance in the lockbox accounts, and payments from the lockbox were made to Pacific Summit prior to any payment to the Major Energy Companies. To secure the payment obligations of the Major Energy Companies under the arrangements, Pacific Summit had a security interest, in among other things, funds in the lockbox account, certain accounts receivable and inventory supplied by Pacific Summit. Each of the Major Energy Companies had also guaranteed the payment obligations of the other Major Energy Companies under these arrangements.
On March 31, 2017, the Pacific Summit arrangements were terminated, and the credit requirements of Major Energy Companies were funded from our working capital.
Cash Flows
Our cash flows were as follows for the respective periods (in thousands):

| Three Months Ended March 31, |  |
| 2017 |  | 2016 |  | Change
Net cash provided by operating activities | $ | 24,380 |  |  | $ | 25,502 |  |  | $ | (1,122 | )
Net cash used in investing activities | $ | (9,612 | ) |  | $ | (833 | ) |  | $ | (8,779 | )
Net cash used in financing activities | $ | (8,797 | ) |  | $ | (26,194 | ) |  | $ | 17,397 |

Three Months Ended March 31, 2017 Compared to the Three Months Ended March 31, 2016
Cash Flows Provided by Operating Activities. Cash flows provided by operating activities for the three months ended March 31, 2017 decreased by $1.1 million compared to the three months ended March 31, 2016. The decrease was primarily the result of a decrease in net income, increased customer acquisition cost spending, and a decrease in the changes in working capital for the three months ended March 31, 2017 as compared to the three months ended March 31, 2016.
Cash Flows Used in Investing Activities. Cash flows used in investing activities increased by $8.8 million for the three months ended March 31, 2017, which was primarily due to earnout payments made during the three months ended March 31, 2017 related to the Provider Companies and the Major Energy Companies.
Cash Flows Used in Financing Activities. Cash flows used in financing activities decreased by $17.4 million for the three months ended March 31, 2017. The decrease in cash flows used in financing activities was primarily due to proceeds received from the issuance of our Series A Preferred Stock offset by additional dividends and distributions made to holders of our Class A and Class B common stock, respectively, and increased net payments under our Senior Credit Facility.
Senior Credit Facility
The Company, as guarantor, and Spark HoldCo (the “Borrower,” and together with Spark Energy, LLC, Spark Energy Gas, LLC, CenStar Energy Corp, CenStar Operating Company, LLC, Oasis Power Holdings, LLC and Oasis Power, LLC, Electricity Maine, LLC, Electricity N.H., LLC and Provider Power Mass, LLC, each a subsidiary of Spark HoldCo, the “Co-Borrowers”) are party to a senior secured revolving credit facility, as amended (“Senior Credit Facility”).
On June 1, 2016, the Company and the Co-Borrowers entered into Amendment No. 3 to the Senior Credit Facility to, among other things, increase the Working Capital Line from $60.0 million to $82.5 million in accordance with the Co-Borrowers' right to increase under the existing terms of the Senior Credit Facility. Amendment No. 3 also provides for the addition of new lenders and re-allocates working capital and revolving commitments among
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existing and new lenders. Amendment No. 3 also provides for additional representations of the Co-Borrowers and additional protections of the lenders of the Senior Credit Facility.
The Company and the Co-Borrowers entered into Amendment No. 4 to the Senior Credit Facility, effective August 1, 2016, to, among other things, provide for the acquisition of the Provider Companies and certain additional amendments automatically upon the closing of the acquisition of the Major Energy Companies. Upon the closing of the acquisition of the Major Energy Companies, the Major Energy Companies were designated unrestricted subsidiaries, as that term is defined in the Senior Credit Facility. Amendment No. 4 also raised the minimum availability under the Working Capital Line to $40.0 million.
At the Borrower’s election, the interest rate under the Working Capital Line is generally determined by reference to:

• | the Eurodollar rate plus an applicable margin of up to 3.00% per annum (based upon the prevailing utilization); or

• | the alternate base rate plus an applicable margin of up to 2.00% per annum (based upon the prevailing utilization). The alternate base rate is equal to the highest of (i) Société Générale’s prime rate, (ii) the federal funds rate plus 0.50% per annum, or (iii) the reference Eurodollar rate plus 1.00%; or

• | the rate quoted by Société Générale as its cost of funds for the requested credit plus up to 2.50% per annum (based upon the prevailing utilization).

The interest rate is generally reduced by 25 basis points if utilization under the Working Capital Line is below fifty percent.
Borrowings under the Acquisition Line are generally determined by reference to:

• | the Eurodollar rate plus an applicable margin of up to 3.75% per annum (based upon the prevailing utilization); or

• | the alternate base rate plus an applicable margin of up to 2.75% per annum (based upon the prevailing utilization). The alternate base rate is equal to the highest of (i) Société Générale's prime rate, (ii) the federal funds rate plus 0.50% per annum, or (iii) the reference Eurodollar rate plus 1.00%.

The Co-Borrowers pay an annual commitment fee of 0.375% or 0.50% on the unused portion of the Working Capital Line, depending upon the unused capacity, and 0.50% on the unused portion of the Acquisition Line. The lending syndicate under the Senior Credit Facility is entitled to several additional fees including an upfront fee, annual agency fee, and fronting fees based on a percentage of the face amount of letters of credit payable to any syndicate member that issues a letter a credit.
The Company has the ability to elect the availability under the Working Capital Line between $40.0 million to $82.5 million. On September 30, 2016, the Company and the Co-Borrowers elected to reduce the capacity of the Working Capital Line from $82.5 million to $60.0 million. At December 31, 2016, we elected up to the $70.0 million level. At March 31, 2017, the Company and the Co-Borrowers elected an availability of $82.5 million under the Working Capital Line. Availability under the working capital line is subject to borrowing base limitations. The borrowing base is calculated primarily based on 80% to 90% of the value of eligible accounts receivable and unbilled product sales (depending on the credit quality of the counterparties) and inventory and other working capital assets. The Co-Borrowers must generally seek approval of the agent or the lenders for permitted acquisitions to be financed under the Acquisition Line.
The Senior Credit Facility is secured by pledges of the equity of the portion of Spark HoldCo owned by the Company and of the equity of Spark HoldCo’s subsidiaries (excluding the Major Energy Companies) and the Co-Borrowers’ present and future subsidiaries, all of 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. The Major Energy Companies are excluded from the definition of "Borrowers" under the Senior Credit Facility. Accordingly, we do not factor in their working capital into our working capital covenants.
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The Senior Credit Facility also contains covenants that, among other things, require the maintenance of specified ratios or conditions as follows:

▪ | Minimum Net Working Capital. The Co-Borrowers must maintain minimum consolidated net working capital equal to the greater of $5.0 million or 15% of the elected availability under the Working Capital Line

▪ | Minimum Adjusted Tangible Net Worth. The Co-Borrowers must maintain a minimum consolidated adjusted tangible net worth at all times equal to the net cash proceeds from equity issuances occurring after the date of the Senior Credit Facility plus the greater of (i) 20% of aggregate commitments under the Working Capital Line plus 33% of borrowings under the Acquisition Line and (ii) $18.0 million.

▪ | Minimum Fixed Charge Coverage Ratio. Spark Energy, Inc. must maintain a minimum fixed charge coverage ratio of 1.25 to 1.00. The Fixed Charge Coverage Ratio is defined as the ratio of (a) Adjusted EBITDA to (b) the sum of consolidated interest expense (other than interest paid-in-kind in respect of any Subordinated Debt), letter of credit fees, commitment fees, acquisition earn-out payments, distributions and scheduled amortization payments.

▪ | Maximum Total Leverage Ratio. Spark Energy, Inc. must maintain a ratio of total indebtedness (excluding the Working Capital Facility and qualifying subordinated debt) to Adjusted EBITDA of a maximum of 2.50 to 1.00.

The Senior Credit Facility contains various negative covenants that limit the Company’s ability to, among other things, do any of the following:

• | incur certain additional indebtedness;

• | grant certain liens;

• | engage in certain asset dispositions;

• | merge or consolidate;

• | make certain payments, distributions, investments, acquisitions or loans;

• | enter into transactions with affiliates.

Spark Energy, Inc. is entitled to pay cash dividends to the holders of the Class A common stock and Series A Preferred Stock, and Spark HoldCo is entitled to make cash distributions to us, NuDevco Retail Holdings, LLC so long as: (a) no default exists or would result from such a payment; (b) the Co-Borrowers are in pro forma compliance with all financial covenants before and after giving effect to such payment and (c) the outstanding amount of all loans and letters of credit does not exceed the borrowing base limits. Spark HoldCo’s inability to satisfy certain financial covenants or the existence of an event of default, if not cured or waived, under the Senior Credit Facility could prevent the Company from paying dividends to holders of the Class A common stock.
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, change in control in which affiliates of our Founder own less than 40% of the outstanding voting interests in the Company, certain events of bankruptcy, certain events under ERISA, material judgments in excess of $5.0 million, certain events with respect to material contracts, actual or asserted failure of any guaranty or security document supporting the Senior Credit Facility to be in full force and effect and changes of 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.
Master Service Agreement with Retailco Services, LLC
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We entered into a Master Service Agreement (the “Master Service Agreement”), effective January 1, 2016, with Retailco Services, LLC ("Retailco Services"), which is wholly owned by our Founder. The Master Service Agreement is for a one-year term and renews automatically for successive one-year terms unless the Master Service Agreement is terminated by either party. On January 31, 2017, the Master Service Agreement renewed automatically pursuant to its terms for a one year period ending on December 31, 2017.
Retailco Services provides us with operational support services such as: enrollment and renewal transaction services; customer billing and transaction services; electronic payment processing services; customer services and information technology infrastructure and application support services under the Master Service Agreement.
During the three months ended March 31, 2017, the Company recorded general and administrative expense of $7.3 million, in connection with the Master Service Agreement. For the three months ended March 31, 2017, Penalty Payments totaled $0.1 million and Damage Payments totaled zero.
Additionally, under the Master Service Agreement, we capitalized $0.1 million during the three months ended March 31, 2017 of property and equipment for software and consultant time used in the application, development and implementation of various systems including customer billing and resource management systems.
Ongoing Obligations in Connection with Acquisitions
The Company is obligated to make earnout and installment payments in connection with the acquisitions of the Major Energy Companies and Provider Companies as more fully described in this Quarterly Report on Form 10-Q. In the case of the Major Energy Companies acquisition, these payments could be as much as $35 million depending upon operating results and the customer counts through 2019. See further discussion related to the valuation of the earnouts in Note 9 "Fair Value Measurements."
Convertible Subordinated Notes to Affiliate
The Company from time to time issues subordinated debt to affiliates of Retailco, which owns a majority of the Company’s outstanding common stock and is indirectly owned by our Founder, who serves as the Chairman of the Board of Directors of the Company. The Company’s Senior Credit Facility requires that at least 25% of permitted acquisitions thereunder be financed with either cash on hand or subordinated debt.
On July 8, 2015, the Company issued a convertible subordinated note to Retailco Acquisition Co, LLC ("RAC"), which is wholly owned by our Founder, for $2.1 million. The convertible subordinated note was scheduled to mature on July 8, 2020, and carried interest at an annual rate of 5%, payable semiannually. The convertible subordinated note was convertible into shares of the Company’s Class B common stock (and a related unit of Spark HoldCo) at a conversion price of $16.57, at any time following the eighteen month anniversary of issuance. Shares of Class A common stock resulting from the conversion of the shares of Class B common stock issued as a result of the conversion right under the convertible subordinated note are entitled to registration rights identical to the registration rights currently held by Retailco on shares of Class A common stock it receives upon conversion of its existing shares of Class B common stock. On October 5, 2016, RAC issued to the Company an irrevocable commitment to convert the convertible subordinated note into 134,731 shares of Class B common stock. RAC assigned the convertible subordinated note to Retailco on January 4, 2017, and on January 8, 2017, the convertible subordinated note was converted into 134,731 shares of Class B common stock.
On July 31, 2015, the Company issued a convertible subordinated note to RAC for $5.0 million. The convertible subordinated note was scheduled to mature on July 31, 2020, and carried interest at a rate of 5% per annum, payable semi-annually. The convertible subordinated note was convertible into shares of Class B common stock (and a related unit of Spark HoldCo) at a conversion rate of $14.00 per share, at any time following the eighteen month anniversary of issuance. Shares of Class A common stock resulting from the conversion of the shares of Class B common stock issued as a result of the conversion right under the convertible subordinated note are entitled to registration rights identical to the registration rights currently held by Retailco on shares of Class A common stock
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it receives upon conversion of its existing shares of Class B common stock. On October 5, 2016, RAC issued to the Company an irrevocable commitment to convert the convertible subordinated note into 383,090 shares of Class B common stock. RAC assigned the convertible subordinated note to Retailco on January 4, 2017, and on January 31, 2017, the convertible subordinated note was converted into 383,090 shares of Class B common stock.
Subordinated Debt Facility
On December 27, 2016, the Company and Spark HoldCo jointly issued to Retailco, an entity owned by our Founder, a 5% subordinated note in the principal amount of up to $25.0 million. The subordinated note allows us and Spark HoldCo to draw advances in increments of no less than $1.0 million per advance up to the maximum principal amount of the subordinated note. The subordinated note matures approximately 3 ½ years following the date of issuance, and 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 note. The subordinated note 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 note so long as we are in compliance with our covenants under the Senior Credit Facility, are not in default under the Senior Credit Facility and have minimum availability of $5.0 million under our borrowing base under the Senior Credit Facility. Payment of principal and interest under the subordinated note is accelerated upon the occurrence of certain change of control transactions.
We plan to use the Subordinated Facility to enhance working capital, for growth initiatives, and for capital optimization. As of March 31, 2017, there was zero in outstanding borrowings under the subordinated note.
Investment in ESM
The Company and Spark HoldCo, together with eREX Co., Ltd., a Japanese company, are joint venture partners in eREX Spark Marketing Co., Ltd ("ESM"). Operations for ESM began on April 1, 2016 in connection with the deregulation of the Japanese power market. As of March 31, 2017, the Company has contributed 156.4 million Japanese Yen, or $1.4 million, for 20% ownership of ESM. As of March 31, 2017, ESM has approximately 50,000 customers, which are currently excluded from our RCEs.
Off-Balance Sheet Arrangements
As of March 31, 2017, we had no material off-balance sheet arrangements.
Related Party Transactions
For a discussion of related party transactions, see Note 13 "Transactions with Affiliates" in the unaudited condensed consolidated financial statements.
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 Annual Report on Form 10-K for the year ended December 31, 2016. There have been no changes to these policies and estimates since the date of our Annual Report on Form 10-K for the year ended December 31, 2016.
Recent Accounting Pronouncements
Adopted Standards
In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718) ("ASU 2016-09"). ASU 2016-09 includes provisions intended to simplify various aspects of accounting for shared-based payments, including income tax consequences, classification of awards as either equity or liability and classification on the statement of cash flows. This guidance is effective for annual and interim reporting periods of public entities
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beginning after December 15, 2016, with early adoption permitted. The Company adopted ASU 2016-09 in the first quarter of 2017.
The new standard requires prospective recognition of excess tax benefits resulting from stock-based compensation vesting and exercises to be recognized as a reduction of income taxes and reflected in operating cash flows. Previously, these amounts were recognized in additional paid-in capital and presented as a financing activity on the statement of cash flows. No net excess tax benefits were recognized as a reduction of income taxes for the three months ended March 31, 2017. Prior periods have not been adjusted.
The Company has elected to continue to estimate the number of stock-based awards expected to vest, as permitted by ASU 2016-09, rather than electing to account for forfeitures as they occur.
ASU 2016-09 requires that employee taxes paid when an employer withholds shares for tax-withholding purposes to be reported as financing activities in the statement of cash flows. Previously, these cash flows were included in operating activities. The Company has elected to adopt this prospectively, as permitted by ASU 2016-09. This change resulted in no impact on the statement of cash flow for the three months ended March 31, 2017.
In October 2016, the FASB issued ASU No. 2016-17, Consolidation (Topic 810): Interests Held through Related Parties that Are under Common Control ("ASU 2016-17"). ASU 2016-17 amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity ("VIE") should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. Under ASU 2016-17, a single decision maker of a VIE is required to consider indirect economic interests in the entity held through related parties on a proportionate basis when determining whether it is the primary beneficiary of that VIE. If a single decision maker and its related party are under common control, the single decision maker is required to consider indirect interests in the entity held through those related parties to be the equivalent of direct interests in their entirety. The amendments are effective for public business entities for fiscal years beginning after December 15, 2016 (the Company's first quarter of fiscal 2017), including interim periods within those fiscal years. Early adoption is permitted. The standard may be applied retrospectively or through a cumulative effect adjustment to retained earnings as of the beginning of the fiscal year of adoption. The Company adopted ASU 2016-17 effective January 1, 2017, and the adoption did not have a material impact on the Company's consolidated financial statements.
Standards Being Evaluated/Standards Not Yet Adopted
In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The standard permits the use of either the retrospective or cumulative effect transition method. In August 2015, the FASB issued ASU No. 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, which deferred the effective date to periods beginning after December 15, 2017. Early adoption is permitted only as of annual reporting periods beginning after December 15, 2016. In December 2016, the FASB further issued ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers, to increase stakeholders' awareness of the proposals and to expedite improvements to ASU 2014-09. After assessing the new standard, the Company expects that there will be no material impacts to our revenue recognition procedures.
The FASB issued additional amendments to ASU No. 2014-09, as amended by ASU No. 2015-14:

• | March 2016 - ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) ("ASU 2016-08"). ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations. The guidance includes indicators to assist an entity in determining whether it controls a specified good or service before it is transferred to customers.

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• | April 2016 - ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing ("ASU 2016-10"). ASU 2016-10 covers two specific topics: performance obligations and licensing. This amendment includes guidance on immaterial promised goods or services, shipping or handling activities, separately identifiable performance obligations, functional or symbolic intellectual property licenses, sales-based and usage-based royalties, license restrictions (time, use, geographical) and licensing renewals.

• | May 2016 - ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients ("ASU 2016-12"). ASU 2016-12 clarifies certain core recognition principles including collectability, sales tax presentation, noncash consideration, contract modifications and completed contracts at transition and disclosures no longer required if the full retrospective transition method is adopted.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) ("ASU 2016-02"). ASU 2016-02 amends the existing accounting standards for lease accounting by requiring entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to not recognize leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous guidance. ASU 2016-02 also requires qualitative disclosures along with certain specific quantitative disclosures for both lessees and lessors. The amendments in this ASU are effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and are effective for interim periods in the year of adoption. The ASU should be applied using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments ("ASU 2016-13"). ASU 2016-13 requires entities to use a current expected credit loss ("CECL") model, which is a new impairment model based on expected losses rather than incurred losses. The model requires financial assets measured at amortized cost be presented at the net amount expected to be collected. The allowance for credit losses is a valuation account that is deducted from the amortized cost basis. The income statement reflects the measurement of credit losses for newly recognized financial assets, as well as the expected credit losses during the period. The measurement of expected losses is based upon historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. This guidance is effective for interim and annual reporting periods beginning after December 15, 2019, with early adoption permitted for annual reporting periods beginning after December 15, 2018. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments ("ASU 2016-15"). ASU 2016-15 provides guidance on the presentation and classification of eight specific cash flow issues in the statement of cash flows. Those issues are cash payment for debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instrument or other debt instrument with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; cash proceeds from the settlement of insurance claims, cash received from settlement of corporate-owned life insurance policies; distribution received from equity method investees; beneficial interest in securitization transactions; and classification of cash receipts and payments that have aspects of more than one class of cash flows. The guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied using a retrospective transition method for each period presented. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In October 2016, the FASB issued ASU No. 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory (“ASU 2016-16”). ASU 2016-16 requires immediate recognition of the current and deferred income tax consequences of intercompany asset transfers other than inventory. Current U.S. GAAP prohibits the
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recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This guidance is effective for annual and interim reporting periods of public entities beginning after December 15, 2017, with early adoption permitted as of the beginning of an annual reporting period for which financial statements (interim or annual) have not been issued or made available for issuance. This ASU should be applied using a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash ("ASU 2016-18"). ASU 2016-18 is intended to add and clarify guidance on the classification and presentation of restricted cash on the statement of cash flows. ASU 2016-18 requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amendments are effective for public business entities for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business ("ASU 2017-01"). ASU 2017-01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The definition of a business affects many areas of accounting, including acquisitions, disposals, goodwill, and consolidation. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods, and the amendments should be applied prospectively on or after the effective date. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-03, Accounting Changes and Error Corrections (Topic 250) and Investments - Equity Method and Joint Ventures (Topic 323) ("ASU 2017-03"). ASU 2017-03 offers amendments to SEC paragraphs pursuant to staff announcements at the September 22, 2016 and November 17, 2016 EITF meetings for clarification purposes. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In January 2017, the FASB issued ASU No. 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment ("ASU 2017-04"). ASU 2017-04 simplifies the subsequent measurement of goodwill by eliminating Step 2 from the goodwill impairment test. Under the amendments in this update, an entity should perform its annual or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value. However, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. ASU 2017-04 should be applied on a prospective basis and is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
In February 2017, the FASB issued ASU No. 2017-05, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) : Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets ("ASU 2017-05"). ASU 2017-05 clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. Subtopic 610-20 was issued in May 2014 as part of ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) and provides guidance for recognizing gains and losses from the transfer of nonfinancial assets in contracts with noncustomers. The amendments in ASU 2017-05 clarify that a financial asset is within the scope of Subtopic 610-20 if it meets the definition of an in substance nonfinancial asset. The amendments also clarify that nonfinancial assets within the scope of Subtopic 610-20 may
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include nonfinancial assets transferred within a legal entity to a counterparty. The amendments in ASU 2017-05 are effective at the same time as the amendments in ASU 2014-09, which are effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. Early adoption is permitted for interim or annual reporting periods beginning after December 15, 2016. An entity may elect to apply the amendments in ASU 2017-05 either retrospectively to each period presented in the financial statements in accordance with the guidance on accounting changes (retrospective approach) or retrospectively with a cumulative-effect adjustment to retained earnings as of the beginning of the fiscal year of adoption (modified retrospective approach). The Company is currently evaluating the impact of adopting this guidance on its consolidated financial statements.
Contingencies
In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including regulatory and other matters. As of March 31, 2017, management does 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 litigation and governmental investigations, see Note 12 "Commitments and Contingencies" in the Company’s unaudited condensed consolidated financial statements.
Emerging Growth Company Status
We are an “emerging growth company” within the meaning of the federal securities laws. For as long as we are an emerging growth company, we will not be required to comply with certain requirements that are applicable to other public companies that are not “emerging growth companies” including, but not limited to, not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act, the reduced disclosure obligations regarding executive compensation in our periodic reports and proxy statements and the exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and stockholder approval of any golden parachute payments not previously approved. In addition, Section 107 of the JOBS Act provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards, but we have irrevocably opted out of the extended transition period and, as a result, we will adopt new or revised accounting standards on the relevant dates on which adoption of such standards is required for other public companies.
We intend to take advantage of these exemptions until we are no longer an emerging growth company. We will cease to be an “emerging growth company” upon the earliest of: (i) the last day of the fiscal year in which we have $1.0 billion or more in annual revenues; (ii) the date on which we become a “large accelerated filer” (the fiscal year-end on which the total market value of our common equity securities held by non-affiliates is $700 million or more as of June 30); (iii) the date on which we issue more than $1.0 billion of non-convertible debt over a three-year period; or (iv) the last day of 2019.
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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 policies and procedures to manage our exposure to these risks.
Commodity Price Risk
We hedge and procure our energy requirements from various wholesale energy markets, including both physical and financial markets and through short and long term contracts. Our financial results are largely dependent on the margin we are able to realize between the wholesale purchase price of natural gas and electricity plus related costs and the retail sales price we charge our customers. 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 a few years, depending on the instrument. Our asset optimization group utilizes similar derivative contracts in connection with its trading activities to attempt to generate incremental gross margin by effecting transactions in markets where we have a retail presence. Generally, any of such instruments that are entered into to support our retail electricity and natural gas business are categorized as having been entered into for non-trading purposes, and instruments entered into for any other purpose are categorized as having been entered into for trading purposes. Our net (loss) gain on non-trading derivative instruments net of cash settlements was $(13.5) million and $1.7 million for the three months ended March 31, 2017 and 2016, 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 Annual Report on Form 10-K for the year ended December 31, 2016.
We measure the commodity risk of our non-trading energy derivatives using a sensitivity analysis on our net open position. As of March 31, 2017, our Gas Non-Trading Fixed Price Open Position (hedges net of retail load) was a long position of 961,465 MMBtu. An increase of 10% in the market prices (NYMEX) from their March 31, 2017 levels would have increased the fair market value of our net non-trading energy portfolio by $0.3 million. Likewise, a decrease of 10% in the market prices (NYMEX) from their March 31, 2017 levels would have decreased the fair market value of our non-trading energy derivatives by $0.3 million. As of March 31, 2017, our Electricity Non-Trading Fixed Price Open Position (hedges net of retail load) was a long position of 20,378 MWhs. An increase of 10% in the forward market prices from their March 31, 2017 levels would have increased the fair market value of our net non-trading energy portfolio by $0.2 million. Likewise, a decrease of 10% in the forward market prices from their March 31, 2017 levels would have decreased the fair market value of our non-trading energy derivatives by $0.2 million.
We measure the commodity risk of our trading energy derivatives using a sensitivity analysis on our net open position. As of March 31, 2017, we did not have a Gas Trading Fixed Price Open Position.
Credit Risk
In many of the utility services territories where we conduct business, POR programs have been established, whereby the local regulated utility purchases our receivables, and becomes responsible for billing the customer and collecting payment from the customer. This service results in substantially all of our credit risk being linked to the applicable utility and not to our end-use customer in these territories. Approximately 63% of our retail revenues were derived from territories in which substantially all of our credit risk was directly linked to local regulated utility companies for three months ended March 31, 2017, all of which had investment grade ratings as of such date. During the same period, we paid these local regulated utilities a weighted average discount of approximately 1.31% of total revenues for customer credit risk protection. In certain of the POR markets in which we operate, the utilities
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limit their collections exposure by retaining the ability to transfer a delinquent account back to us for collection when collections are past due for a specified period.
If our collection efforts are unsuccessful, we return the account to the local regulated utility for termination of service. Under these service programs, we are exposed to credit risk related to payment for services rendered during the time between when the customer is transferred to us by the local regulated utility and the time we return the customer to the utility for termination of service, which is generally one to two billing periods. We may also realize a loss on fixed-price customers in this scenario due to the fact that we will have already fully hedged the customer’s expected commodity usage for the life of the contract.
In non-POR markets (and in POR markets where we may choose to direct bill our customers), we manage customer credit risk through formal credit review in the case of commercial customers, and credit score screening, deposits and disconnection for non-payment, in the case of residential customers. Economic conditions may affect our customers’ ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in bad debt expense. Our bad debt expense for the three months ended March 31, 2017 was approximately less than 1.0% of non-POR market retail revenues. See “Management's Discussion and Analysis of Financial Condition and Results of Operations — Drivers of Our Business” for an analysis of our bad debt expense related to non-POR markets during the three months ended March 31, 2017.
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 March 31, 2017, approximately 88% of our total exposure of $8.5 million was either with an investment grade customer or otherwise secured with collateral or a guarantee.
Interest Rate Risk
We are exposed to fluctuations in interest rates under our variable-price debt obligations. At March 31, 2017, we were co-borrowers under the Senior Credit Facility, under which $22.2 million of variable rate indebtedness was outstanding. Based on the average amount of our variable rate indebtedness outstanding during the three months ended March 31, 2017, a 1% percent increase in interest rates would have resulted in additional annual interest expense of approximately $0.2 million. We do not currently employ interest rate hedges, although we may choose to do so in the future.
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ITEM 4. 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 the company's management, including its 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 March 31, 2017 at the reasonable assurance level.
Management believes the unaudited condensed consolidated financial statements included in this Quarterly Report on Form 10-Q fairly represent in all material respects our financial condition, results of operations and cash flows at and for the periods presented in accordance with GAAP.
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 March 31, 2017 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.
We are the subject of lawsuits and claims arising in the ordinary course of business from time to time. Management cannot predict the ultimate outcome of such lawsuits and claims. 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 except as described below. See Note 12 "Commitments and Contingencies" to the unaudited consolidated financial statements for a description of certain other proceedings.
The Company is the subject of the following lawsuits:
John Melville et al v. Spark Energy Inc. and Spark Energy Gas, LLC is a purported class action filed on December 17, 2015 in the United States District Court for the District of New Jersey alleging, among other things, that (i) sales representatives engaged as independent contractors for Spark Energy Gas, LLC engaged in deceptive acts in violation of the New Jersey Consumer Fraud Act, (ii) Spark Energy Gas, LLC breach its contract with plaintiff, including a breach of the covenant of good faith and fair dealing. Plaintiffs are seeking unspecified compensatory and punitive damages for the purported class, injunctive relief and/or declaratory relief, disgorgement of revenues and/or profits and attorneys’ fees. Initial discovery is ongoing. Spark Energy Inc. and Spark Energy Gas, LLC intend to vigorously defend this matter and the allegations asserted therein. Given the early stages of this matter, we cannot predict the outcome or consequences of this case at this time.
Halifax-American Energy Company, LLC et al v. Provider Power, LLC, Electricity N.H., LLC, Electricity Maine, LLC, Emile Clavet and Kevin Dean is a lawsuit initially filed on June 12, 2014, in the Rockingham County Superior Court, State of New Hampshire, alleging various claims related to the Provider Companies’ employment of a sales contractor formerly employed with one or more of the plaintiffs, including misappropriation of trade secrets and tortious interference with a contractual relationship. The dispute occurred prior to the Company's acquisition of the Provider Companies. Portions of the original claim proceeded to trial and on January 19, 2016, a jury found in favor of the plaintiff. Damages totaling approximately $0.6 million and attorney’s fees totaling approximately $0.3 million were awarded to the plaintiff. On May 4, 2016, following post-verdict motions, the defendants filed an appeal in the State of New Hampshire Supreme Court, appealing, among other things the failure of the trial court to direct a verdict for the defendants, to set aside the verdict, or grant judgment for the defendants, and the trial court's award of certain attorneys' fees. As of December 31, 2016 and March 31, 2017, respectively, the Company has accrued approximately $1.0 million in contingent liabilities related to this litigation. Initial damages and attorney's fees have been factored into the purchase price for the Provider Companies, and the Company has full indemnity coverage and set-off rights against future price installments for any actual exposure in the appeal.
Katherine Veilleux and Jennifer Chon, individually and on behalf of all other similarly situated v. Electricity Maine. LLC, Provider Power, LLC, Spark Holdco, LLC, Kevin Dean and Emile Clavet is a purported class action lawsuit filed on November 18, 2016 in the United States District Court of Maine, alleging that Electricity Maine, LLC, an entity acquired by Spark Holdco, LLC in mid 2016, enrolled customers through fraudulent and misleading advertising and promotions prior to the acquisition. Plaintiffs allege the following claims against all Defendants: violation of the Maine Unfair Trade Practices Act, violation of RICO, negligence, negligent misrepresentation, fraudulent misrepresentation, unjust enrichment and breach of contract. Plaintiffs seek unspecified damages for themselves and the purported class, rescission of contracts with Electricity Maine, injunctive relief, restitution, and attorney’s fees. Discovery has not yet commenced in this matter. Spark HoldCo intends to vigorously defend this matter and the allegations asserted therein. Given the early stages of this matter, we cannot predict the outcome or consequences of this case at this time. Under the terms of the acquisition, Spark HoldCo is indemnified for losses and expenses in connection with this action subject to certain limits.
Gillis et al. v. Respond Power, LLC is a purported class action lawsuit that was originally filed on May 21, 2014 in the Philadelphia Court of Common Pleas. On June 23, 2014, the case was removed to the United States District
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Court for the Eastern District of Pennsylvania. On September 15, 2014, the plaintiffs filed an amended class action complaint seeking a declaratory judgment that the disclosure statement contained in Respond Power, LLC’s variable rate contracts with Pennsylvania consumers limited the variable rate that could be charged to no more than the monthly rate charged by the consumers’ local utility company. The plaintiffs also allege that Respond Power, LLC (i) breached its variable rate contract with Pennsylvania consumers, and the covenant of good faith and fair dealing therein, by charging rates in excess of the monthly rate charged by the consumers’ local utility company; (ii) engaged in deceptive conduct in violation of the Pennsylvania Unfair Trade Practices and Consumer Protection Law; and (iii) engaged in negligent misrepresentation and fraudulent concealment in connection with purported promises of savings. The amount of damages sought is not specified. By order dated August 31, 2015, the district court denied class certification. The plaintiffs appealed the district court’s denial of class certification to the United States Court of Appeals for the Third Circuit. The United States Court of Appeals for the Third Circuit vacated the district court’s denial of class certification and remanded the matter to the district court for further proceedings.
We currently cannot predict the outcome or consequences of this case at this time. The Company is indemnified for Major litigation matters, subject to certain limitations by original owners of the Major Energy Companies.
Item 1A. Risk Factors.
Security holders and potential investors in our securities should carefully consider the risk factors under "Risk Factors" in our 2016 Annual Report on Form 10-K. Except as provided below, there has been no material change in our risk factors from those described in the 2016 Annual Report on Form 10-K. These 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.
Risks Related to the Series A Preferred Stock
The Series A Preferred Stock represent perpetual equity interests in us, and investors should not expect us to redeem the Series A Preferred Stock on the date the Series A Preferred Stock becomes redeemable by us or on any particular date afterwards.
The Series A Preferred Stock represent perpetual equity interests in us, and they have no maturity or mandatory redemption date and are not redeemable at the option of investors under any circumstances. As a result, unlike our indebtedness, the Series A Preferred Stock do not give rise to a claim for payment of a principal amount at a particular date. As a result, holders of the Series A Preferred Stock may be required to bear the financial risks of an investment in the Series A Preferred Stock for an indefinite period of time. In addition, the Series A Preferred Stock rank junior to all our current and future indebtedness (including indebtedness outstanding under our Senior Credit Facility) and other liabilities. The Series A Preferred Stock also rank junior to any other senior securities we may issue in the future with respect to assets available to satisfy claims against us.
The Series A Preferred Stock have not been rated.
We have not sought to obtain a rating for the Series A Preferred Stock, and the Series A Preferred Stock may never be rated. It is possible, however, that one or more rating agencies might independently determine to assign a rating to the Series A Preferred Stock or that we may elect to obtain a rating of the Series A Preferred Stock in the future. In addition, we may elect to issue other securities for which we may seek to obtain a rating. If any ratings are assigned to the Series A Preferred Stock in the future or if we issue other securities with a rating, such ratings, if they are lower than market expectations or are subsequently lowered or withdrawn, could adversely affect the market for or the market value of the Series A Preferred Stock. Ratings only reflect the views of the issuing rating agency or agencies and such ratings could at any time be revised downward or withdrawn entirely at the discretion of the issuing rating agency. A rating is not a recommendation to purchase, sell or hold any particular security, including the Series A Preferred Stock. Ratings do not reflect market prices or suitability of a security for a particular investor and any future rating of the Series A Preferred Stock may not reflect all risks related to us and our business, or the structure or market value of the Series A Preferred Stock.
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We could be prevented from paying cash dividends on the Series A Preferred Stock.
Holders of shares of Series A Preferred Stock do not have a right to dividends on such shares unless declared or set aside for payment by our Board of Directors. Under Delaware law, cash dividends on capital stock may only be paid from “surplus” or, if there is no “surplus,” from the corporation’s net profits for the then-current or the preceding fiscal year. Unless we operate profitably, our ability to pay cash dividends on the Series A Preferred Stock would require the availability of adequate “surplus,” which is defined as the excess, if any, of net assets (total assets less total liabilities) over capital. Our business may not generate sufficient cash flow from operations to enable us to pay dividends on the Series A Preferred Stock when payable. Further, even if adequate surplus is available to pay cash dividends on the Series A Preferred Stock, we may not have sufficient cash to pay dividends on the Series A Preferred Stock.
Furthermore, no dividends on Series A Preferred Stock shall be authorized by our board of directors or paid, declared or set aside for payment by us at any time when the authorization, payment, declaration or setting aside for payment would be unlawful under Delaware law or any other applicable law, or when the terms and provisions of any agreement of ours, including any agreement relating to our indebtedness, prohibit the authorization, payment, declaration or setting aside for payment thereof or provide that the authorization, payment, declaration or setting aside for payment thereof would constitute a breach of such document or a default under such document.
The Series A Preferred Stock are subordinated to our existing and future debt obligations, and your interests could be diluted by the issuance of additional shares, including additional Series A Preferred Stock, and by other transactions.
The Series A Preferred Stock are subordinated to all of our existing and future indebtedness (including indebtedness outstanding under our Senior Credit Facility). Therefore, if we become bankrupt, liquidate our assets, reorganize or enter into certain other transactions, our assets will be available to pay our obligations with respect to the Series A Preferred Stock only after we have paid all of our existing and future indebtedness in full. There may be insufficient assets remaining following such payments to make any payments to holders of the Series A Preferred Stock then outstanding.
The issuance of additional equity on a parity with or senior to the Series A Preferred Stock would dilute the interests of the holders of shares of Series A Preferred Stock, and any issuance of equity on parity with or senior to the Series A Preferred Stock, or additional indebtedness could affect our ability to pay distributions on, redeem or pay the liquidation preference on the Series A Preferred Stock. Only the limited conversion right upon a change of control relating to the Series A Preferred Stock protects the holders of the Series A Preferred Stock in the event of a highly leveraged or other transaction, including a merger or the sale, lease or conveyance of all or substantially all our assets or business, which might adversely affect the holders of the Series A Preferred Stock.
We are a holding company. Our sole material asset is our equity interest in Spark Holdco and we are accordingly dependent upon distributions from Spark Holdco to pay dividends on the Series A Preferred Stock.
We are a holding company and have no material assets other than our equity interest in Spark Holdco. We have no independent means of generating revenue. None of our subsidiaries has guaranteed or otherwise become obligated with respect to the Series A Preferred Stock. As a result, the Series A Preferred Stock effectively rank junior to all existing and future indebtedness and other liabilities of our subsidiaries, including our operating subsidiaries, CenStar Energy Corp., SEG, SE, Oasis Power Holdings, LLC, the Provider Companies and the Major Energy Companies, and any capital stock of our subsidiaries not held by us. Accordingly, our right to receive assets from any of our subsidiaries upon our bankruptcy, liquidation or reorganization, and the right of holders of Series A Preferred Stock to participate in those assets, is structurally subordinated to claims of that subsidiary’s creditors, including trade creditors. Even if we were a creditor of any of our subsidiaries, our rights as a creditor would be subordinate to any security interest in the assets of that subsidiary and any indebtedness of that subsidiary senior to that held by us.
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Holders of Series A Preferred Stock have extremely limited voting rights.
Your voting rights as a holder of shares of Series A Preferred Stock are extremely limited. Our Class A common stock and our Class B common stock are the only classes of our securities carrying full voting rights. Holders of the Series A Preferred Stock generally have no voting rights except for certain limited protective voting rights if the Series A Preferred Stock is delisted or there is a dividend penalty event as specified in the Certificate of Designations relating to the Series A Preferred Stock.
Future issuances of preferred stock, including future issuances of shares of Series A Preferred Stock, may reduce the value of the Series A Preferred Stock.
We may sell additional shares of preferred stock, including shares of Series A Preferred Stock, on terms that may differ from those previously offered. Such shares could rank on parity with or, subject to the voting rights referred to above, senior to the Series A Preferred Stock as to distribution rights or rights upon liquidation, winding up or dissolution. The subsequent issuance of additional shares of Series A Preferred Stock, or the creation and subsequent issuance of additional classes of preferred stock on parity with the Series A Preferred Stock, could dilute the interests of the holders of Series A Preferred Stock. Any issuance of preferred stock that is senior to the Series A Preferred Stock would not only dilute the interests of the holders of Series A Preferred Stock, but also could affect our ability to pay distributions on, redeem or pay the liquidation preference on the Series A Preferred Stock.
The Series A Preferred Stock are a new issuance and do not have an established trading market, which may negatively affect their market value and your ability to transfer or sell your Series A Preferred Stock. In addition, the lack of a fixed redemption date for the Series A Preferred Stock increase your reliance on the secondary market for liquidity purposes.
The Series A Preferred Stock is a new issue of securities. An active trading market on the NASDAQ for the Series A Preferred Stock may not develop or, even if it develops, may not last, in which case the trading price of the Series A Preferred Stock could be adversely affected and your ability to transfer your Series A Preferred Stock would be limited. If an active trading market does develop on the NASDAQ, the Series A Preferred Stock may trade at prices lower than the price at which you purchase Series A Preferred Stock. In addition, since the securities have no stated maturity date, investors seeking liquidity are limited to selling their shares of Series A Preferred Stock in the secondary market absent redemption by us.
The trading price of the Series A Preferred Stock would depend on many factors, including:

• | prevailing interest rates;

• | the market for similar securities;

• | general economic and financial market conditions;

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

• | our financial condition, results of operations and prospects.

Market interest rates may adversely affect the value of the Series A Preferred Stock.
One of the factors that influence the price of the Series A Preferred Stock is the distribution yield on the Series A Preferred Stock (as a percentage of the price of the Series A Preferred Stock) relative to market interest rates. An increase in market interest rates, which are currently at low levels relative to historical rates, may lead prospective purchasers of shares of Series A Preferred Stock to expect a higher distribution yield, and higher interest rates would likely increase our borrowing costs and potentially decrease funds available for distribution. Accordingly, higher market interest rates could cause the market price of the Series A Preferred Stock to decrease.
The limited conversion right upon a change of control may make it more difficult for a party to acquire us or discourage a party from acquiring us.
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The limited conversion rights upon a change of control as provided in the Certificate of Designations may have the effect of discouraging a third party from making an acquisition proposal for us or of delaying, deferring or preventing certain change of control transactions under circumstances that otherwise could provide the holders of our Series A Preferred Stock with the opportunity to realize a premium over the then-current market price of such equity securities or that stockholders may otherwise believe is in their best interests.
If we are unable to redeem the Series A Preferred Stock on or after April 15, 2022, a substantial increase in the Three-Month LIBOR Rate could negatively impact our ability to pay dividends on the Series A Preferred Stock.
If we do not repurchase or redeem our Series A Preferred Stock on or after April 15, 2022, a substantial increase in the Three-Month LIBOR Rate could negatively impact our ability to pay distributions on such stock. We cannot assure you that we will have adequate sources of capital to repurchase or redeem the Series A Preferred Stock on or after April 15, 2022. If we are unable to repurchase or redeem the Series A Preferred Stock and our ability to pay dividends on the Series A Preferred Stock is negatively impacted, the market value of the Series A Preferred Stock could be materially adversely impacted.
We may not have sufficient earnings and profits in order for dividends on the Series A Preferred Stock to be treated as dividends for U.S. federal income tax purposes.
The dividends payable by us on the Series A Preferred Stock may exceed our current and accumulated earnings and profits, as calculated for U.S. federal income tax purposes. If that occurs, it will result in the amount of the dividends that exceed such earnings and profits being treated for U.S. federal income tax purposes first as a return of capital to the extent of the beneficial owner’s adjusted tax basis in the Series A Preferred Stock, and the excess, if any, over such adjusted tax basis as capital gain. Such treatment will generally be unfavorable for corporate beneficial owners and may also be unfavorable to certain other beneficial owners.
You may be subject to tax if we make or fail to make certain adjustments to the conversion rate of the Series A Preferred Stock even though you do not receive a corresponding cash distribution.
The conversion rate for the Series A Preferred Stock as provided in the Certificate of Designations is subject to adjustment in certain circumstances. A failure to adjust (or to adjust adequately) the conversion rate after an event that increases your proportionate interest in us could be treated as a deemed taxable dividend to you. If you are a non-U.S. holder (as defined in “Material U.S. federal income tax considerations”), any deemed dividend may be subject to U.S. federal withholding tax at a 30% rate, or such lower rate as may be specified by an applicable treaty, which may be set off against subsequent payments on the Series A Preferred Stock. In April 2016, the Internal Revenue Service issued new proposed income tax regulations in regard to the taxability of changes in conversion rights that will apply to the Series A Preferred Stock when published in final form and may be applied to us before final publication in certain instances.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
None.
Item 3. Defaults Upon Senior Securities.
None.
Item 4. Mine Safety Disclosures.
Not applicable.
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Item 5. Other Information.
Verde Membership Interest and Stock Purchase Agreement
On May 5, 2017, the Company and CenStar Energy Corp., a New York corporation ("CenStar") entered into a Membership Interest and Stock Purchase Agreement (the “Verde Purchase Agreement”) with Verde Energy USA Holdings, LLC (the “Seller”), as a seller of all interests in and to the companies listed therein (the “Verde Companies”). Pursuant to the terms of the Verde Purchase Agreement, CenStar has agreed to purchase, and the Seller has agreed to sell, all of the outstanding membership interests and stock in the Verde Companies. The Company acts as a guarantor of CenStar's obligations under the Verde Purchase Agreement. The transactions under the Verde Purchase Agreement are expected to close on or before August 31, 2017, subject to the satisfaction of customary closing conditions, and subject to extension.
The aggregate purchase price, subject to adjustment as provided in the Verde Purchase Agreement, is approximately $65 million, plus working capital and potential earnout payments. Spark will pay cash of $45.0 million at closing and installment payments totaling $20 million over 18 months, a portion of which will be paid into an escrow account to satisfy any claims by CenStar over the 18 months subsequent to closing. Additionally, CenStar will pay 100% of the Adjusted EBITDA earned by the Verde Companies for the 18 months after closing that exceeds certain thresholds, subject to the Verde Companies' ability to achieve defined customer count criteria over the 18 months subsequent to closing.
CenStar and the Seller have made customary representations, warranties and covenants in the Verde Purchase Agreement. The Seller has made certain additional customary covenants, including, among others, covenants to conduct the Verde Companies’ business in the ordinary course between the execution of the Verde Purchase Agreement and the closing and not to engage in certain kinds of transactions during that period, subject to certain exceptions.
Consummation of the transactions contemplated by the Verde Purchase Agreement is subject to various conditions, including, among others, (1) the accuracy of representations and warranties of the parties as of the closing date, including the absence of any seller material adverse effect, (2) receipt of all required approvals, (3) the negotiation and execution of certain ancillary documents and (4) other customary closing conditions. The Verde Purchase Agreement also contains termination provisions and indemnification provisions.
The Verde Purchase Agreement has been filed as an exhibit to this quarterly report on Form 10-Q to provide investors and security holders with more complete information regarding its terms, and the description herein is qualified by reference to the full text of the Verde Purchase Agreement. The Verde Purchase Agreement is not intended to provide any other factual information about CenStar or the Company. The representations, warranties and covenants contained in the Verde Purchase Agreement were made only for purposes of the Verde Purchase Agreement and as of specific dates, were solely for the benefit of the parties to the respective agreements, and may be subject to limitations agreed upon by the contracting parties, including being qualified by confidential disclosures exchanged between the parties in connection with the execution of the Verde Purchase Agreement. The representations and warranties may have been made for the purposes of allocating contractual risk between the parties instead of establishing these matters as facts, and may be subject to standards of materiality applicable to the contracting parties that differ from those applicable to investors. Investors are not third-party beneficiaries under the Verde Purchase Agreement and should not rely on the representations, warranties and covenants or any descriptions thereof as characterizations of the actual state of facts or condition of the Company, CenStar or any of their respective subsidiaries or affiliates. Moreover, information concerning the subject matter of the representations and warranties may change after the date of the Verde Purchase Agreement, which subsequent information may or may not be fully reflected in the public disclosures of the Company.
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Item 6. Exhibits
|  |  |  | Incorporated by Reference
Exhibit |  |  | Exhibit Description |  | Form | Exhibit Number | Filing Date | SEC File No.
2.1# |  |  | Membership Interest Purchase Agreement, by and among Spark Energy, Inc., Spark HoldCo, LLC, Provider Power, LLC, Kevin B. Dean and Emile L. Clavet, dated as of May 3, 2016. |  | 10-Q |  | 2.1 | 5/5/2016 | 001-36559
2.2# |  |  | Membership Interest Purchase Agreement, by and among Spark Energy, Inc., Spark HoldCo, LLC, Retailco, LLC and National Gas & Electric, LLC, dated as of May 3, 2016. |  | 10-Q |  | 2.2 | 5/5/2016 | 001-36559
2.3# |  |  | Amendment No. 1 to the Membership Interest Purchase Agreement, dated as of July 26, 2016, by and among Spark Energy, Inc., Spark HoldCo, LLC, Provider Power, LLC, Kevin B. Dean and Emile L. Clavet. |  | 8-K |  | 2.1 | 8/1/2016 | 001-36559
2.4*# |  |  | Membership Interest and Stock Purchase Agreement, by and among Spark Energy, Inc., CenStar Energy Corp. and Verde Energy USA Holdings, LLC, dated as of May 5, 2017. |  |  |  |  |  |
3.1 |  |  | Amended and Restated Certificate of Incorporation of Spark Energy, Inc. |  | 8-K |  | 3.1 | 8/4/2014 | 001-36559
3.2 |  |  | Amended and Restated Bylaws of Spark Energy, Inc. |  | 8-K |  | 3.2 | 8/4/2014 | 001-36559
3.3 |  |  | Certificate of Designations of Rights and Preferences of 8.75% Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock |  | 8-A |  | 5 | 3/11/2017 | 001-36559
4.1 |  |  | Class A Common Stock Certificate |  | S-1 |  | 4.1 | 6/30/2014 | 333-196375
10.1* |  |  | Spark HoldCo. Third Amended and Restated Limited Liability Agreement, dated as of March 15, 2017, by and among Spark Energy, Inc., Retailco, LLC and NuDevco Retail, LLC. |  |  |  |  |  |
31.1* |  |  | Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934. |  |  |  |  |  |
31.2* |  |  | Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934. |  |  |  |  |  |
32** |  |  | Certifications pursuant to 18 U.S.C. Section 1350. |  |  |  |  |  |
101.INS* |  |  | XBRL Instance Document. |  |  |  |  |  |
101.SCH* |  |  | XBRL Schema Document. |  |  |  |  |  |
101.CAL* |  |  | XBRL Calculation Document. |  |  |  |  |  |
101.LAB* |  |  | XBRL Labels Linkbase Document. |  |  |  |  |  |
101.PRE* |  |  | XBRL Presentation Linkbase Document. |  |  |  |  |  |
101.DEF* |  |  | XBRL Definition Linkbase Document. |  |  |  |  |  |

* Filed herewith
** Furnished herewith
# The registrant agrees to furnish supplementally a copy of any omitted schedule to the Commission upon request
† Compensatory plan or arrangement or managerial contract
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APPENDIX A
CFTC. The Commodity Futures Trading Commission.
ERCOT. The Electric Reliability Council of Texas, the independent system operator and the regional coordinator of various electricity systems within Texas.
FERC. The Federal Energy Regulatory Commission, a regulatory body that regulates, among other things, the transmission and wholesale sale of electricity and the transportation of natural gas by interstate pipelines in the United States.
ISO. An independent system operator. An ISO manages and controls transmission infrastructure in a particular region.
MMBtu. One million British Thermal Units, a standard unit of heating equivalent measure for natural gas. A unit of heat equal to 1,000,000 Btus, or 1 MMBtu, is the thermal equivalent of approximately 1,000 cubic feet of natural gas.
MWh. One megawatt hour, a unit of electricity equal to 1,000 kilowatt hours (kWh), or the amount of energy equal to one megawatt of constant power expended for one hour of time.
Non-POR Market. A non-purchase of accounts receivable market.
NYPSC. Public Service Commission of the State of New York.
POR Market. A purchase of accounts receivable market.
RCE. A residential customer equivalent, refers to a natural gas customer with a standard consumption of 100 MMBtus per year or an electricity customer with a standard consumption of 10 MWhs per year.
REP. A retail electricity provider.
RTO. A regional transmission organization. A RTO, similar to an ISO, is a third party entity that manages transmission infrastructure in a particular region.
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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.

| Spark Energy, Inc.
May 8, 2017 |  |  | /s/ Robert Lane
|  |  | Robert Lane
|  |  | Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)

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