Edgar Filing: QUANTA SERVICES INC

10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2016.

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

For the transition period from to .

Commission file no. 001-13831

Quanta Services, Inc.

(Exact name of registrant as specified in its charter)

Delaware

74-2851603

(State or other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

2800 Post Oak Boulevard, Suite 2600

Houston, Texas 77056

(Address of principal executive offices, including zip code)

(713) 629-7600

(Registrant’s telephone number, including area code)

N/A

(Former name, former address and former fiscal year, if changed since last report)

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 ¨

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 ¨

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


Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨ (Do not check if a smaller reporting company)	Smaller reporting company	¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

As of August 3, 2016, the number of outstanding shares of Common Stock of the Registrant was 144,194,115. As of the same date, 3,500,000 exchangeable shares of a Canadian subsidiary of the Registrant associated with one share of Series F Preferred Stock of the Registrant were outstanding, 449,929 exchangeable shares of a Canadian subsidiary of the Registrant associated with one share of Series G Preferred Stock of the Registrant were outstanding and an additional 2,926,113 exchangeable shares of certain other Canadian subsidiaries of the Registrant were outstanding.

QUANTA SERVICES, INC. AND SUBSIDIARIES

INDEX


		Page
	PART I. FINANCIAL INFORMATION

ITEM 1.	Financial Statements (Unaudited)

	Condensed Consolidated Balance Sheets		2

	Condensed Consolidated Statements of Operations		3

	Condensed Consolidated Statements of Comprehensive Income		4

	Condensed Consolidated Statements of Cash Flows		5

	Notes to Condensed Consolidated Financial Statements		6

ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		44

ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk		81

ITEM 4.	Controls and Procedures		82

	PART II. OTHER INFORMATION

ITEM 1.	Legal Proceedings		84

ITEM 1A.	Risk Factors		84

ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds		84

ITEM 3.	Defaults Upon Senior Securities		85

ITEM 4.	Mine Safety Disclosures		85

ITEM 5.	Other Information		85

ITEM 6.	Exhibits		85

Signature			87

PART I — FINANCIAL INFORMATION

Item 1.

Financial Statements.

QUANTA SERVICES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share information)

(Unaudited)


	June 30, 2016			December 31, 2015
ASSETS
Current Assets:
Cash and cash equivalents	$	162,344		$	128,771
Accounts receivable, net of allowances of $2,719 and $5,226		1,384,554			1,621,133
Costs and estimated earnings in excess of billings on uncompleted contracts		466,476			317,745
Inventories		74,976			75,285
Prepaid expenses and other current assets		156,037			134,585

Total current assets		2,244,387			2,277,519
Property and equipment, net of accumulated depreciation of $824,108 and $755,272		1,160,870			1,101,959
Other assets, net		93,033			76,333
Other intangible assets, net of accumulated amortization of $283,889 and $264,674		203,256			205,074
Goodwill		1,595,555			1,552,658

Total assets	$	5,297,101		$	5,213,543

LIABILITIES AND EQUITY
Current Liabilities:
Current maturities of long-term debt and short-term borrowings	$	5,603		$	7,067
Accounts payable and accrued expenses		811,521			782,134
Billings in excess of costs and estimated earnings on uncompleted contracts		388,314			399,230
Current liabilities of discontinued operations		2,651			15,313

Total current liabilities		1,208,089			1,203,744
Long-term debt and notes payable, net of current maturities		401,119			475,364
Deferred income taxes		200,683			186,491
Insurance and other non-current liabilities		284,036			260,129

Total liabilities		2,093,927			2,125,728

Commitments and Contingencies
Equity:
Common stock, $.00001 par value, 600,000,000 shares authorized, 228,951,159 and 227,898,509 shares issued, and 144,194,115 and 152,907,166 shares outstanding		2			2
Exchangeable Shares, no par value, 6,876,042 shares issued and outstanding		—			—
Series F Preferred Stock, $.00001 par value, 1 share authorized, issued and outstanding		—			—
Series G Preferred Stock, $.00001 par value, 1 share authorized, issued and outstanding		—			—
Additional paid-in capital		3,676,910			3,497,740
Retained earnings		1,714,756			1,677,698
Accumulated other comprehensive loss		(231,020	)		(294,689	)
Treasury stock, 84,757,044 and 74,991,343 common shares, at cost		(1,960,325	)		(1,795,257	)

Total stockholders’ equity		3,200,323			3,085,494
Non-controlling interests		2,851			2,321

Total equity		3,203,174			3,087,815

Total liabilities and equity	$	5,297,101		$	5,213,543

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

QUANTA SERVICES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share information)

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Revenues	$	1,792,430		$	1,872,340		$	3,506,167		$	3,733,726
Cost of services (including depreciation)		1,592,213			1,644,835			3,102,637			3,268,315

Gross profit		200,217			227,505			403,530			465,411
Selling, general and administrative expenses		156,607			149,923			315,131			295,386
Amortization of intangible assets		8,141			8,731			15,636			17,024

Operating income		35,469			68,851			72,763			153,001
Interest expense		(3,583	)		(1,675	)		(7,172	)		(3,075	)
Interest income		641			319			1,157			772
Equity in losses of unconsolidated affiliates		(378	)		(314	)		(559	)		(314	)
Other income (expense), net		(725	)		(134	)		(463	)		(346	)

Income from continuing operations before income taxes		31,424			67,047			65,726			150,038
Provision for income taxes		14,695			31,584			28,138			62,185

Net income from continuing operations		16,729			35,463			37,588			87,853
Net income from discontinued operations		—			14,102			—			19,897

Net income		16,729			49,565			37,588			107,750
Less: Net income attributable to non-controlling interests		167			3,456			530			8,157

Net income attributable to common stock	$	16,562		$	46,109		$	37,058		$	99,593

Amounts attributable to common stock:
Net income from continuing operations	$	16,562		$	32,007		$	37,058		$	79,696
Net income from discontinued operations		—			14,102			—			19,897

Net income attributable to common stock	$	16,562		$	46,109		$	37,058		$	99,593

Earnings per share attributable to common stock — basic and diluted:
Continuing operations	$	0.11		$	0.15		$	0.23		$	0.37
Discontinued operations		—			0.07			—			0.09

Net income attributable to common stock	$	0.11		$	0.22		$	0.23		$	0.46

Shares used in computing earnings per share:
Weighted average basic shares outstanding		156,128			213,047			159,577			214,257

Weighted average diluted shares outstanding		156,130			213,059			159,579			214,269

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

QUANTA SERVICES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Net income	$	16,729	$	49,565	$	37,588	$	107,750
Other comprehensive income (loss), net of tax provision:
Foreign currency translation adjustment, net of tax of $0, $0, $0 and $0		3,083		14,897		63,669		(74,052	)
Other, net of tax of $0, $(3), $0 and $(2)		—		8		—		3

Other comprehensive income (loss)		3,083		14,905		63,669		(74,049	)

Comprehensive income		19,812		64,470		101,257		33,701
Less: Comprehensive income attributable to non-controlling interests		167		3,456		530		8,157

Total comprehensive income attributable to Quanta stockholders	$	19,645	$	61,014	$	100,727	$	25,544

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

QUANTA SERVICES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Cash Flows from Operating Activities of Continuing Operations:
Net income	$	16,729		$	49,565		$	37,588		$	107,750
Adjustments to reconcile net income to net cash provided by operating activities of continuing operations —
Income from discontinued operations		—			(14,102	)		—			(19,897	)
Depreciation		42,759			41,030			83,929			80,428
Amortization of intangible assets		8,141			8,731			15,636			17,024
Equity in losses of unconsolidated affiliates		378			314			559			314
Amortization of debt issuance costs		338			273			678			546
(Gain) loss on sale of property and equipment		654			(7	)		547			(110	)
Foreign currency loss		558			523			668			713
Provision for (recovery of) doubtful accounts		56			126			(927	)		704
Deferred income tax provision (benefit)		(7,858	)		280			(5,142	)		992
Non-cash stock-based compensation		9,503			9,714			23,222			19,185
Tax impact of stock-based equity awards		(122	)		(3	)		(122	)		(4	)
Changes in operating assets and liabilities, net of non-cash transactions —
(Increase) decrease in —
Accounts and notes receivable		105,399			17,779			264,394			137,652
Costs and estimated earnings in excess of billings on uncompleted contracts		(82,456	)		(3,281	)		(134,923	)		(66,769	)
Inventories		(2,256	)		(9,869	)		2,281			(12,991	)
Prepaid expenses and other current assets		(13,513	)		(7,270	)		(11,687	)		(9,576	)
Increase (decrease) in —
Accounts payable and accrued expenses and other non-current liabilities		32,808			22,235			3,092			51,446
Billings in excess of costs and estimated earnings on uncompleted contracts		(48,465	)		(7,551	)		(12,527	)		(14,569	)
Other, net		3,875			(2,363	)		(999	)		(7,086	)

Net cash provided by operating activities of continuing operations		66,528			106,124			266,267			285,752

Cash Flows from Investing Activities of Continuing Operations:
Proceeds from sale of property and equipment		5,165			7,733			10,254			9,015
Additions of property and equipment		(60,855	)		(62,493	)		(108,550	)		(120,997	)
Cash paid for acquisitions, net of cash acquired		(35	)		(37,936	)		(39,710	)		(72,669	)
Investments in and return of equity from unconsolidated affiliates		(3,163	)		(1,784	)		(5,388	)		(2,593	)
Cash received from (paid for) other investments, net		503			2,871			1,080			3,193
Cash withdrawn from restricted cash		42			—			42			214
Cash paid for intangibles		—			(211	)		—			(211	)

Net cash used in investing activities of continuing operations		(58,343	)		(91,820	)		(142,272	)		(184,048	)

Cash Flows from Financing Activities of Continuing Operations:
Borrowings under credit facility		696,572			625,286			1,350,988			772,742
Payments under credit facility		(696,668	)		(528,741	)		(1,426,271	)		(632,684	)
Payments on other long-term debt		(692	)		(959	)		(5,547	)		(1,359	)
Payments on short-term debt		—			(4,248	)		(4,711	)		(5,170	)
Distributions to non-controlling interests		—			(2,500	)		—			(5,003	)
Tax impact of stock-based equity awards		122			3			122			4
Exercise of stock options		163			278			214			354
Repurchase of common stock		—			(172,279	)		—			(354,279	)

Net cash used in financing activities of continuing operations		(503	)		(83,160	)		(85,205	)		(225,395	)

Discontinued operations:
Net cash provided by operating activities		—			11,432			—			21,031
Net cash used in investing activities		(437	)		(13,517	)		(6,080	)		(21,181	)

Net cash used in discontinued operations		(437	)		(2,085	)		(6,080	)		(150	)
Effect of foreign exchange rate changes on cash and cash equivalents		(216	)		834			863			(1,247	)
Net increase (decrease) in cash and cash equivalents		7,029			(70,107	)		33,573			(125,088	)
Cash and cash equivalents, beginning of period		155,315			135,534			128,771			190,515

Cash and cash equivalents, end of period	$	162,344		$	65,427		$	162,344		$	65,427

Supplemental disclosure of cash flow information:
Cash (paid) received during the period for —
Interest paid related to continuing operations	$	(3,066	)	$	(1,422	)	$	(5,507	)	$	(2,610	)
Income taxes paid related to continuing operations	$	(27,038	)	$	(37,837	)	$	(33,524	)	$	(50,241	)
Income taxes paid related to discontinued operations	$	(437	)	$	(39	)	$	(6,080	)	$	(244	)
Income tax refunds related to continuing operations	$	785		$	10,293		$	1,679		$	10,738

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

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.	BUSINESS AND ORGANIZATION:

Quanta Services, Inc. (Quanta) is a leading provider of specialty contracting services, offering infrastructure solutions primarily to the electric power and oil and gas industries in the United States, Canada and Australia and select other international markets. Quanta reports its results under two reportable segments: (1) Electric Power Infrastructure Services and (2) Oil and Gas Infrastructure Services.

Electric Power Infrastructure Services Segment

The Electric Power Infrastructure Services segment provides comprehensive network solutions to customers in the electric power industry. Services performed by the Electric Power Infrastructure Services segment generally include the design, installation, upgrade, repair and maintenance of electric power transmission and distribution infrastructure and substation facilities along with other engineering and technical services. This segment also provides emergency restoration services, including the repair of infrastructure damaged by inclement weather, the energized installation, maintenance and upgrade of electric power infrastructure utilizing unique bare hand and hot stick methods and Quanta’s proprietary robotic arm technologies, and the installation of “smart grid” technologies on electric power networks. In addition, this segment designs, installs and maintains renewable energy generation facilities, consisting of solar, wind and certain types of natural gas generation facilities, and related switchyards and transmission infrastructure to transport power to demand centers. To a lesser extent, this segment provides services such as the construction of electric power generation facilities, the design, installation, maintenance and repair of commercial and industrial wiring, installation of traffic networks, the installation of cable and control systems for light rail lines and limited ancillary telecommunication infrastructure services.

Oil and Gas Infrastructure Services Segment

The Oil and Gas Infrastructure Services segment provides comprehensive network solutions to customers involved in the development and transportation of natural gas, oil and other pipeline products. Services performed by the Oil and Gas Infrastructure Services segment generally include the design, installation, repair and maintenance of pipeline transmission and distribution systems, gathering systems, production systems and compressor and pump stations, as well as related trenching, directional boring and automatic welding services. In addition, this segment’s services include pipeline protection, integrity testing, rehabilitation and replacement and fabrication of pipeline support systems and related structures and facilities. Quanta also serves the offshore and inland water energy markets, primarily providing services to oil and gas exploration platforms, including mechanical installation (or “hook-ups”), electrical and instrumentation, pre-commissioning and commissioning, coatings, fabrication, pipeline construction, integrity services and marine asset repair. To a lesser extent, this segment designs, installs and maintains fueling systems, as well as water and sewer infrastructure.

Acquisitions

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

During 2015, Quanta acquired 11 companies. The results of eight of the acquired companies are generally included in Quanta’s Electric Power Infrastructure Services segment. These companies include a foundation services company located in the United States, an electrical contracting company located in the United States, an electrical engineering company located in Australia, a powerline construction company located in the United States, an engineering company located in Canada, an engineering, procurement and construction services company based in the United States, an underground construction contracting company located in Canada, and a supplier and material procurement specialist for the power and utility industry in Canada. The results of the remaining three acquired companies are generally included in Quanta’s Oil and Gas Infrastructure Services segment. These companies include a company that services above-ground storage tanks in the United States, an underground utility distribution contractor that provides services to gas and electric utilities in Canada, and a company that specializes in the engineering, procurement, construction, and commissioning of compression and surface facilities for the high pressure gas industry in Australia.

Disposition — Fiber Optic Licensing Operations

On April 29, 2015, Quanta entered into a stock purchase agreement with Crown Castle International Corp. (Crown Castle) pursuant to which Quanta agreed to sell its fiber optic licensing operations. The purchase agreement contained customary representations and warranties, covenants and indemnities. On August 4, 2015, Quanta completed the sale for a purchase price of approximately $1 billion in cash, resulting in after-tax net proceeds of approximately $848 million. In the third quarter of 2015, Quanta recognized a net of tax gain of approximately $171 million. Quanta has presented the results of operations, financial position, cash flows and disclosures of the fiber optic licensing operations as discontinued operations for all periods in the accompanying unaudited condensed consolidated financial statements. These results were included in Quanta’s Fiber Optic Licensing and Other segment prior to the second quarter of 2015.

2.	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

Principles of Consolidation

The consolidated financial statements of Quanta include the accounts of Quanta Services, Inc. and its wholly owned subsidiaries, which are also referred to as its operating units. The consolidated financial statements also include the accounts of certain of Quanta’s investments in joint ventures, which are either consolidated or proportionately consolidated, as discussed in the following summary of significant accounting policies. Investments in affiliated entities in which Quanta does not have a controlling financial interest, but over which Quanta has significant influence, usually because Quanta holds a voting interest of between 20% and 50%, are accounted for using the equity method. All significant intercompany accounts and transactions have been eliminated in consolidation. Unless the context requires otherwise, references to Quanta include Quanta Services, Inc. and its consolidated subsidiaries.

Interim Condensed Consolidated Financial Information

These unaudited condensed consolidated financial statements have been prepared pursuant to the rules of the Securities and Exchange Commission (SEC). Certain information and footnote disclosures, normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States (US GAAP), have been condensed or omitted pursuant to those rules and regulations. Quanta believes that the disclosures made are adequate to make the information presented not misleading. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, necessary to fairly state the financial position, results of operations, comprehensive income and cash flows with respect to the interim

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

condensed consolidated financial statements have been included. The results of operations and comprehensive income for the interim periods are not necessarily indicative of the results for the entire fiscal year. The results of Quanta have historically been subject to significant seasonal fluctuations.

Quanta recommends that these unaudited condensed consolidated financial statements be read in conjunction with the audited consolidated financial statements and notes thereto of Quanta and its subsidiaries included in Quanta’s Annual Report on Form 10-K for the year ended December 31, 2015, which was filed with the SEC on February 29, 2016.

Use of Estimates and Assumptions

The preparation of financial statements in conformity with US GAAP requires the use of estimates and assumptions by management in determining the reported amounts of assets and liabilities, disclosures of contingent assets and liabilities known to exist as of the date the financial statements are published, and the reported amounts of revenues and expenses recognized during the periods presented. Quanta reviews all significant estimates affecting its consolidated financial statements on a recurring basis and records the effect of any necessary adjustments prior to their publication. Judgments and estimates are based on Quanta’s beliefs and assumptions derived from information available at the time such judgments and estimates are made. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. Estimates are primarily used in Quanta’s assessment of the allowance for doubtful accounts, valuation of inventory, useful lives of assets, fair value assumptions in analyzing goodwill, other intangibles and long-lived asset impairments, equity and other investments, loan receivables, purchase price allocations, liabilities for self-insured and other claims and guarantees, multiemployer pension plan withdrawal liabilities, revenue recognition for construction contracts inclusive of contractual change orders and claims, share-based compensation, operating results of reportable segments, as well as the provision for income taxes and the calculation of uncertain tax positions.

Cash and Cash Equivalents

Quanta had cash and cash equivalents of $162.3 million and $128.8 million as of June 30, 2016 and December 31, 2015. Cash consisting of interest-bearing demand deposits is carried at cost, which approximates fair value. Quanta considers all highly liquid investments with an original maturity of three months or less at the time of purchase to be cash equivalents, which are carried at fair value. At June 30, 2016 and December 31, 2015, cash equivalents were $5.7 million and $1.4 million, and consisted primarily of money market investments and money market mutual funds and are discussed further in Fair Value Measurements below. As of June 30, 2016 and December 31, 2015, cash and cash equivalents held in domestic bank accounts were approximately $13.4 million and $16.1 million, and cash and cash equivalents held in foreign bank accounts were approximately $148.9 million and $112.7 million. As of June 30, 2016 and December 31, 2015, cash and cash equivalents held by Quanta’s investments in joint ventures, which are either consolidated or proportionately consolidated, were approximately $17.8 million and $24.9 million, of which $13.4 million and $11.9 million related to domestic joint ventures. Cash and cash equivalents held by the joint ventures are available to support the operations of the related joint ventures, and Quanta does not have access to that cash for its other operations. Under the terms of the partnership agreements, Quanta generally has no right to the joint ventures’ cash other than participating in distributions and in the event of dissolution.

Current and Long-Term Accounts and Notes Receivable and Allowance for Doubtful Accounts

Quanta provides an allowance for doubtful accounts when collection of an account or note receivable is considered doubtful, and receivables are written off against the allowance when deemed uncollectible. Inherent

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

in the assessment of the allowance for doubtful accounts are certain judgments and estimates regarding, among other factors, the customer’s access to capital, the customer’s willingness or ability to pay, general economic and market conditions, the ongoing relationship with the customer and uncertainties related to the resolution of disputed matters. Quanta considers accounts receivable delinquent after 30 days but does not generally include delinquent accounts in its analysis of the allowance for doubtful accounts unless the accounts receivable have been outstanding for at least 90 days. In addition to balances that have been outstanding for 90 days or more, Quanta also includes accounts receivable balances that relate to customers in bankruptcy or with other known difficulties in its analysis of the allowance for doubtful accounts. Material changes in Quanta’s customers’ business or cash flows, which may be impacted by negative economic and market conditions, could affect Quanta’s ability to collect amounts due from them. As of June 30, 2016 and December 31, 2015, Quanta had allowances for doubtful accounts on current receivables of approximately $2.7 million and $5.2 million. Long-term accounts receivable are included within other assets, net on the consolidated balance sheets.

Should customers experience financial difficulties or file for bankruptcy, or should anticipated recoveries relating to receivables in existing bankruptcies or other workout situations fail to materialize, Quanta could experience reduced cash flows and losses in excess of current allowances provided.

The balances billed but not paid by customers pursuant to retainage provisions in certain contracts are generally due upon completion of the contracts and acceptance by the customer. Based on Quanta’s experience with similar contracts in recent years, the majority of the retainage balances at each balance sheet date are expected to be collected within the next twelve months. Current retainage balances as of June 30, 2016 and December 31, 2015 were approximately $221.0 million and $250.1 million, and were included in accounts receivable. Retainage balances with settlement dates beyond the next twelve months were included in other assets, net, and as of June 30, 2016 and December 31, 2015 were $4.4 million and $4.5 million.

Within accounts receivable, Quanta recognizes unbilled receivables in circumstances such as when revenues have been earned and recorded but the amount cannot be billed under the terms of the contract until a later date; costs have been incurred but are yet to be billed under cost-reimbursement type contracts; or amounts arise from routine lags in billing (for example, work completed one month but not billed until the next month). These balances do not include revenues accrued for work performed under fixed-price contracts as these amounts are recorded as costs and estimated earnings in excess of billings on uncompleted contracts. At June 30, 2016 and December 31, 2015, the balances of unbilled receivables included in accounts receivable were approximately $228.0 million and $233.6 million.

Goodwill and Other Intangibles

Quanta has recorded goodwill in connection with its historical acquisitions of companies. Upon acquisition, these companies were either combined into one of Quanta’s existing operating units or managed on a stand-alone basis as an individual operating unit. Goodwill recorded in connection with these acquisitions is subject to an annual assessment for impairment, which Quanta performs at the operating unit level for each operating unit that carries a balance of goodwill. Each of Quanta’s operating units is organized into one of two internal divisions: the Electric Power Infrastructure Services Division and the Oil and Gas Infrastructure Services Division. As most of the companies acquired by Quanta provide multiple types of services for multiple types of customers, these divisional designations are based on the predominant type of work performed by each operating unit at the point in time the divisional designation is made. Goodwill is required to be measured for impairment at the reporting unit level, which represents the operating segment level or one level below the operating segment level for which discrete financial information is available. Quanta has determined that its individual operating units represent its reporting units for the purpose of assessing goodwill impairments.

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

Quanta has the option to first assess qualitative factors to determine whether it is necessary to perform the two-step fair value-based impairment test described below. If Quanta believes that, as a result of its qualitative assessment, it is more likely than not that the fair value of a reporting unit is less than its carrying amount, the quantitative impairment test is required. Otherwise, no further testing is required. Quanta can choose to perform the qualitative assessment on none, some or all of its reporting units. Quanta can also bypass the qualitative assessment for any reporting unit in any period and proceed directly to step one of the impairment test, and then resume the qualitative assessment in any subsequent period. Qualitative indicators, including deterioration in macroeconomic conditions, declining financial performance, or a sustained decrease in share price, among other things, may trigger the need for annual or interim impairment testing of goodwill associated with one or all of the reporting units.

Quanta’s goodwill impairment assessment is performed at year-end, or more frequently if events or circumstances arise which indicate that goodwill may be impaired. For instance, a decrease in Quanta’s market capitalization below book value, a significant change in business climate or loss of a significant customer, as well as the qualitative indicators referenced above, may trigger the need for interim impairment testing of goodwill for one or all of its reporting units. The first step of the two-step fair value based test involves comparing the fair value of each of Quanta’s reporting units with its carrying value, including goodwill. If the carrying value of the reporting unit exceeds its fair value, the second step is performed. The second step compares the carrying amount of the reporting unit’s goodwill to the implied fair value of its goodwill. If the implied fair value of goodwill is less than the carrying amount, an impairment loss would be recorded as a reduction to goodwill with a corresponding charge to operating expense.

Quanta determines the fair value of its reporting units using a weighted combination of the discounted cash flow, market multiple and market capitalization valuation approaches, with heavier weighting on the discounted cash flow method, as in management’s opinion, this method currently results in the most accurate calculation of a reporting unit’s fair value. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating margins, discount rates, weighted average costs of capital and future market conditions, among others. Quanta believes the estimates and assumptions used in its impairment assessments are reasonable and based on available market information, but variations in any of the assumptions could result in materially different calculations of fair value and determinations of whether or not an impairment is indicated.

Under the discounted cash flow method, Quanta determines fair value based on the estimated future cash flows of each reporting unit, discounted to present value using risk-adjusted industry discount rates, which reflect the overall level of inherent risk of a reporting unit and the rate of return an outside investor would expect to earn. Cash flow projections are derived from budgeted amounts and operating forecasts (typically a one-year model) plus an estimate of later period cash flows, all of which are evaluated by management. Subsequent period cash flows are developed for each reporting unit using growth rates that management believes are reasonably likely to occur, along with a terminal value derived from the reporting unit’s earnings before interest, taxes, depreciation and amortization (EBITDA). The EBITDA multiples for each reporting unit are based on trailing twelve-month comparable industry data.

Under the market multiple and market capitalization approaches, Quanta determines the estimated fair value of each of its reporting units by applying transaction multiples to each reporting unit’s projected EBITDA and then averaging that estimate with similar historical calculations using either a one, two or three year average. For the market capitalization approach, Quanta adds a reasonable control premium, which is estimated as the premium that would be received in a sale of the reporting unit in an orderly transaction between market participants.

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For recently acquired reporting units, a step one impairment test may indicate an implied fair value that is substantially similar to the reporting unit’s carrying value. Such similarities in value are generally an indication that management’s estimates of future cash flows associated with the recently acquired reporting unit remain relatively consistent with the assumptions that were used to derive its initial fair value.

During the fourth quarter of 2015, a two-step fair-value based goodwill impairment analysis was performed for each of Quanta’s reporting units, and no reporting units were evaluated solely on a qualitative basis. Step one of the analysis indicated that the implied fair value of each of Quanta’s reporting units, other than recently acquired reporting units and two other reporting units described below, was substantially in excess of its carrying value. After performing step two of the analysis, management concluded that goodwill was impaired at two reporting units in Quanta’s Oil and Gas Infrastructure Services Division. Accordingly, during the fourth quarter of 2015, Quanta recorded a $39.8 million non-cash charge for the impairment of goodwill which primarily resulted from lower forecasted oil and gas services revenues for its Gulf of Mexico operations and certain operations in Australia, due to the extended low commodity price environment.

As discussed generally above, when evaluating the 2015 step one impairment test results, management considered many factors in determining whether or not an impairment of goodwill for any reporting unit was reasonably likely to occur in future periods, including future market conditions and the economic environment in which Quanta’s reporting units were operating. Additionally, management considered the sensitivity of its fair value estimates to changes in certain valuation assumptions. After giving consideration to a 10% decrease in the fair value of each of Quanta’s reporting units, the results of the assessment at December 31, 2015 did not change. However, circumstances such as market declines, unfavorable economic conditions, the loss of a major customer or other factors could increase the risk of impairment of goodwill in future periods.

If an operating unit experiences prolonged periods of declining revenues, operating margins or both, it may be at risk of failing step one of the goodwill impairment test. Certain operating units have experienced declines over the short-term due to challenging macroeconomic conditions in certain geographic areas, the decline in oil prices which has negatively impacted customer spending, project delays and constrained customer capital spending as a result of an increasingly complex regulatory and permitting environment. Certain operating units within our Oil and Gas Infrastructure Services segment that primarily operate within the midstream and smaller-scale transmission market have continued to be negatively impacted by these factors. While no interim impairment charges were recorded during the six months ended June 30, 2016, Quanta will continue to monitor these conditions and others to determine if it is necessary to perform step one of the fair-value based impairment test for one or more operating units prior to the annual impairment assessment.

Quanta’s intangible assets include customer relationships, backlog, trade names, non-compete agreements, patented rights and developed technology, all subject to amortization. The value of customer relationships is estimated as of the date a business is acquired based on the value-in-use concept utilizing the income approach, specifically the excess earnings method. The excess earnings analysis consists of discounting to present value the projected cash flows attributable to the customer relationships, with consideration given to customer contract renewals and estimated customer attrition rates, the importance or lack thereof of existing customer relationships to Quanta’s business plan, income taxes and required rates of return. Quanta values backlog for acquired businesses as of the acquisition date based upon the contractual nature of the backlog within each service line, using the income approach to discount back to present value the cash flows attributable to the backlog. The value of trade names is estimated using the relief-from-royalty method of the income approach. This approach is based on the assumption that in lieu of ownership, a company would be willing to pay a royalty in order to exploit the related benefits of this intangible asset.

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Quanta amortizes intangible assets based upon the estimated consumption of the economic benefits of each intangible asset, or on a straight-line basis if the pattern of economic benefits consumption cannot otherwise be reliably estimated. Intangible assets subject to amortization are reviewed for impairment and are tested for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. For instance, a significant change in business climate or a loss of a significant customer, among other things, may trigger the need for interim impairment testing of intangible assets. An impairment loss would be recognized if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value.

During the fourth quarter of 2015, Quanta recorded an impairment charge of $12.1 million related to customer relationships, trade names and non-compete agreement intangible assets. These intangible asset impairments primarily resulted from lower forecasted oil and gas services revenues for Quanta’s Gulf of Mexico operations and certain operations in Australia, due to the extended low commodity price environment. The two reporting units impacted also had related goodwill impairments, as discussed above, and are in Quanta’s Oil and Gas Infrastructure Services Division.

Investments in Affiliates and Other Entities

In the normal course of business, Quanta enters into various types of investment arrangements, each having unique terms and conditions. These investments may include equity interests held by Quanta in business entities, including general or limited partnerships, contractual joint ventures, or other forms of equity or profit participation. These investments may also include Quanta’s participation in different financing structures such as the extension of loans to project specific entities, the acquisition of convertible notes issued by project specific entities, or other strategic financing arrangements. Quanta determines whether such investments involve a variable interest entity (VIE) based on the characteristics of the subject entity. If the entity is determined to be a VIE, then management determines if Quanta is the primary beneficiary of the entity and whether or not consolidation of the VIE is required. The primary beneficiary consolidating the VIE must normally have both (i) the power to direct the activities of a VIE that most significantly affect the VIE’s economic performance and (ii) the obligation to absorb losses of the VIE or the right to receive benefits from the VIE, in either case that could potentially be significant to the VIE. When Quanta is deemed to be the primary beneficiary, the VIE is consolidated and the other party’s equity interest in the VIE is accounted for as a non-controlling interest. In cases where Quanta determines that it has an undivided interest in the assets, liabilities, revenues and profits of an unincorporated VIE (e.g., a general partnership interest), such amounts are consolidated on a basis proportional to Quanta’s ownership interest in the unincorporated entity.

Investments in entities of which Quanta is not the primary beneficiary, but over which Quanta has the ability to exercise significant influence, are accounted for using the equity method of accounting. Quanta’s share of net income or losses from unconsolidated equity investments is included in equity in earnings (losses) of unconsolidated affiliates in the consolidated statements of operations when applicable. Equity investments are reviewed for impairment by assessing whether any decline in the fair value of the investment below the carrying value is other than temporary. In making this determination, factors such as the ability to recover the carrying amount of the investment and the inability of the investee to sustain an earnings capacity are evaluated in determining whether a loss in value should be recognized. Any impairment losses related to investments would be recognized in other expense. Equity method investments are carried at original cost and are included in other assets, net in the consolidated balance sheet and are adjusted for Quanta’s proportionate share of the investees’ income, losses and distributions.

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Revenue Recognition

Through its Electric Power Infrastructure Services and Oil and Gas Infrastructure Services segments, Quanta designs, installs and maintains networks for customers in the electric power and oil and gas industries. These services may be provided pursuant to master service agreements, repair and maintenance contracts and fixed price and non-fixed price installation contracts. Pricing under these contracts may be competitive unit price, cost-plus/hourly (or time and materials basis) or fixed price (or lump sum basis), and the final terms and prices of these contracts are frequently negotiated with the customer. Under unit-based contracts, the utilization of an output-based measurement is appropriate for revenue recognition. Under these contracts, Quanta recognizes revenue as units are completed based on pricing established between Quanta and the customer for each unit of delivery, which best reflects the pattern in which the obligation to the customer is fulfilled. Under cost-plus/hourly and time and materials type contracts, Quanta recognizes revenue on an input basis, as labor hours are incurred and services are performed.

Revenues from fixed price contracts are recognized using the percentage-of-completion method, measured by the percentage of costs incurred to date to total estimated costs for each contract. These contracts provide for a fixed amount of revenues for the entire project. Such contracts provide that the customer accept completion of progress to date and compensate Quanta for services rendered, which may be measured in terms of units installed, hours expended or some other measure of progress. Contract costs include all direct materials, labor and subcontract costs and those indirect costs related to contract performance, such as indirect labor, supplies, tools, repairs and depreciation costs. Much of the material associated with Quanta’s work is owner-furnished and is therefore not included in contract revenues and costs. The cost estimation process is based on professional knowledge and experience of Quanta’s engineers, project managers and financial professionals. Changes in job performance, job conditions and final contract settlements are factors that influence management’s assessment of total contract value and the total estimated costs to complete those contracts and therefore, Quanta’s profit recognition.

Actual revenues and project costs can vary, sometimes substantially, from previous estimates due to changes in a variety of factors including unforeseen circumstances not included in our cost estimates or covered by our contracts for which we cannot obtain adequate compensation, including concealed or unknown environmental conditions; changes in the cost of equipment, commodities, materials or labor; unanticipated costs or claims due to customer-caused delays, customer failure to provide required materials or equipment, errors in engineering, specifications or designs, project modifications, or contract termination and our inability to obtain reimbursement for such costs or recover on such claims; weather conditions; and quality issues requiring rework or replacement. These factors, along with other risks inherent in performing fixed price contracts may cause actual revenues and gross profits for a project to differ from previous estimates and could result in reduced profitability or losses on projects. Changes in these factors may result in revisions to costs and income, and their effects are recognized in the period in which the revisions are determined. These factors are routinely evaluated on a project by project basis throughout the project term, and the impact of corresponding revisions in management’s estimates of contract value, contract cost and contract profit are recorded as necessary in the period in which the revisions are determined. Provisions for losses on uncompleted contracts are made in the period in which such losses are determined to be probable and the amount can be reasonably estimated.

During the six months ended June 30, 2016, Quanta experienced performance issues on an ongoing power plant project in Alaska that resulted in the revision of its estimate of total costs necessary to complete this project. During the first six months of 2016 and as the project was planned to transition from final construction and testing to the commissioning phase, the project was negatively impacted by further third party engineering deficiencies that caused changes to Quanta’s planned scope of work and by performance failures by other

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contractors operating onsite. These issues resulted in higher than expected production costs and a related impact on production sequencing. In addition to these items, late in the second quarter of 2016 Quanta also experienced a claimed force majeure event which disrupted the project and Quanta provided the customer and its insurance providers with a notice of force majeure in order to seek schedule relief and cost recovery from disruptions. Quanta is also in the process of developing potential claims for damages that may have resulted from the third party engineering and other contractor performance issues; however, no revenues or cost recovery have been reflected in Quanta’s estimate of total project losses at June 30, 2016. The increase in estimated costs resulted in the recognition of a project loss of $30.5 million during the three months ended June 30, 2016. Project losses were $51.8 million during the six months ended June 30, 2016. At June 30, 2016, this project had a contract value of $201 million and was approximately 90% complete. This project is expected to be substantially completed near the end of the third quarter of 2016. As this project continues through the final construction and commissioning phases, it is possible that additional performance issues or other unforeseen circumstances could occur and result in the recognition of additional losses on this project; however, such amounts cannot currently be estimated.

Quanta’s operating results for the three and six months ended June 30, 2016 were negatively impacted by 9.2% and 6.7% as a result of aggregate changes in contract estimates related to projects that were in progress at December 31, 2015. Operating results for the three and six months ended June 30, 2016 included losses from the power plant construction project in Alaska mentioned above, offset by numerous individually immaterial changes in project profitability generally due to better than expected performance for projects that were ongoing at year-end. Quanta’s operating results for the three and six months ended June 30, 2015 were impacted by less than 5% as a result of aggregate changes in contract estimates related to projects that were in progress at December 31, 2014. Operating results for the three and six months ended June 30, 2015 included losses of $31.8 million and $48.2 million related to three projects as a result of increased costs associated with performance and site related factors that adversely impacted production. These projects included the ongoing power plant construction project in Alaska, an electric transmission project in Canada that was substantially completed in the third quarter of 2015, and a directional drilling project in Canada that was substantially completed in the fourth quarter of 2015. Operating results for the three and six months ended June 30, 2015 were impacted by positive changes in estimates of $8.5 million and $21.0 million as a result of better than expected performance on an electric transmission project in the United States that was substantially completed in the second quarter of 2015.

The current asset “Costs and estimated earnings in excess of billings on uncompleted contracts” represents revenues recognized in excess of amounts billed for fixed price contracts. The current liability “Billings in excess of costs and estimated earnings on uncompleted contracts” represents billings in excess of revenues recognized for fixed price contracts.

Quanta may incur costs subject to change orders, whether approved or unapproved by the customer, and/or claims related to certain contracts. Quanta determines the probability that such costs will be recovered based upon evidence such as past practices with the customer, specific discussions or preliminary negotiations with the customer or verbal approvals. Quanta treats items as a cost of contract performance in the period incurred if it is not probable that the costs will be recovered or will recognize revenue if it is probable that the contract price will be adjusted and can be reliably estimated. As of June 30, 2016 and December 31, 2015, Quanta had approximately $106.0 million and $137.2 million of change orders and/or claims that had been included as contract price adjustments on certain contracts which were in the process of being negotiated in the normal course of business. These aggregate contract price adjustments represent management’s best estimate of additional contract revenues which have been earned and which management believes are probable of collection. The amounts ultimately realized by Quanta upon final acceptance by its customers could be higher or lower than such estimated amounts; however, such amounts cannot currently be estimated.

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Income Taxes

Quanta follows the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recorded for future tax consequences of temporary differences between the financial reporting and tax bases of assets and liabilities and are measured using the enacted tax rates and laws that are expected to be in effect when the underlying assets or liabilities are recovered or settled.

Quanta regularly evaluates valuation allowances established for deferred tax assets for which future realization is uncertain. The estimation of required valuation allowances includes estimates of future taxable income. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Quanta considers projected future taxable income and tax planning strategies in making this assessment. If actual future taxable income differs from these estimates, Quanta may not realize deferred tax assets to the extent estimated.

Quanta records reserves for income taxes related to certain tax positions in those instances where Quanta considers it more likely than not that additional taxes may be due in excess of amounts reflected on income tax returns filed. When recording reserves for expected tax consequences of uncertain positions, Quanta assumes that taxing authorities have full knowledge of the position and all relevant facts. Quanta continually reviews exposure to additional tax obligations, and as further information is known or events occur, changes in tax reserves may be recorded. To the extent interest and penalties may be assessed by taxing authorities on any underpayment of income tax, such amounts have been accrued and are classified in the provision for income taxes.

As of June 30, 2016, the total amount of unrecognized tax benefits relating to uncertain tax positions was $57.9 million, an increase from December 31, 2015 of $3.4 million. This increase in unrecognized tax benefits resulted primarily from a $1.9 million increase due to tax positions expected to be taken for 2016 and a $1.9 million increase due to tax positions of an acquired company taken in periods prior to the acquisition. Quanta is currently under examination by the Internal Revenue Service (IRS) for tax years 2010, 2011 and 2012, and the federal statute of limitations for examination of all subsequent years remains open. Additionally, certain subsidiaries are under examination by various U.S. state, Canadian and other foreign tax authorities for multiple periods. Quanta believes it is reasonably possible that within the next 12 months unrecognized tax benefits may decrease by up to $25.9 million as a result of settlement of these examinations or as a result of the expiration of certain statute of limitations periods.

U.S. federal and state and foreign income tax laws and regulations are voluminous and are often ambiguous. As such, Quanta is required to make many subjective assumptions and judgments regarding its tax positions that could materially affect amounts recognized in its future consolidated balance sheets and statements of operations and comprehensive income.

Earnings Per Share

Basic earnings per share is computed using the weighted average number of common shares outstanding during the period, and diluted earnings per share is computed using the weighted average number of common shares outstanding during the period adjusted for all potentially dilutive common stock equivalents, except in cases where the effect of the common stock equivalents would be antidilutive.

Self-Insurance

Quanta is insured for employer’s liability, general liability, auto liability and workers’ compensation claims. Under these programs, the deductibles for general liability and auto liability are $10.0 million per occurrence, the

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deductible for workers’ compensation is $5.0 million per occurrence, and the deductible for employer’s liability is $1.0 million per occurrence. Quanta is generally self-insured for all claims that do not exceed the amount of the applicable deductible. Quanta also has employee health care benefit plans for most employees not subject to collective bargaining agreements, of which the primary plan is subject to a deductible of $400,000 per claimant per year.

Losses under all of these insurance programs are accrued based upon Quanta’s estimate of the ultimate liability for claims reported and an estimate of claims incurred but not reported, with assistance from third-party actuaries. These insurance liabilities are difficult to assess and estimate due to unknown factors, including the severity of an injury, the extent of damage, the determination of Quanta’s liability in proportion to other parties and the number of incidents not reported. The accruals are based upon known facts and historical trends, and management believes such accruals are adequate.

Collective Bargaining Agreements

Some of Quanta’s operating units are parties to various collective bargaining agreements with unions that represent certain of their employees. The collective bargaining agreements expire at various times and have typically been renegotiated and renewed on terms similar to those in the expiring agreements. The agreements require the operating units to pay specified wages, provide certain benefits to their union employees and contribute certain amounts to multiemployer pension plans and employee benefit trusts. Quanta’s multiemployer pension plan contribution rates generally are specified in the collective bargaining agreements (usually on an annual basis), and contributions are made to the plans on a “pay-as-you-go” basis based on its union employee payrolls. The location and number of union employees that Quanta employs at any given time and the plans in which they may participate vary depending on the projects Quanta has ongoing at that time and the need for union resources in connection with those projects. Therefore, Quanta is unable to accurately predict the union employee payroll and the amount of the resulting multiemployer pension plan contribution obligation for future periods.

Stock-Based Compensation

Quanta recognizes compensation expense for restricted stock, restricted stock units (RSUs) and performance units to be settled in common stock based on the fair value of the awards at the date of grant, net of estimated forfeitures. The fair value of restricted stock awards, RSUs and performance units to be settled in common stock is determined based on the number of shares, RSUs or performance units granted and the closing price of Quanta’s common stock on the date of grant. An estimate of future forfeitures is required in determining the period expense. Quanta uses historical data to estimate the forfeiture rate; however, these estimates are subject to change and may impact the value that will ultimately be realized as compensation expense. The resulting compensation expense from time-based RSU and performance unit awards is recognized on a straight-line basis over the requisite service period, which is generally the vesting period, while compensation expense from performance-based RSU awards is recognized using the graded vesting method over the requisite service period. The cash flows resulting from the tax deductions in excess of the compensation expense recognized for restricted stock, RSUs and performance units to be settled in common stock and stock options (excess tax benefit) are classified as financing cash flows.

Compensation expense associated with liability based awards, such as RSUs that are expected to or may settle in cash, is recognized based on a remeasurement of the fair value of the award at the end of each reporting period. Upon settlement, the holders receive for each RSU an amount in cash equal to the fair market value on

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the settlement date of one share of Quanta common stock, as specified in the applicable award agreement. For additional information on Quanta’s restricted stock, RSUs and performance unit awards, see Note 10.

Functional Currency and Translation of Financial Statements

The U.S. dollar is the functional currency for the majority of Quanta’s operations, which are primarily located within the United States. The functional currency for Quanta’s foreign operations, which are primarily located in Canada and Australia, is typically the currency of the country in which the foreign operating unit is located. Generally, the currency in which the operating unit transacts the majority of its activities, including billings, financing, payroll and other expenditures, would be considered the functional currency. The treatment of foreign currency translation gains or losses is dependent upon management’s determination of the functional currency of each operating unit. In preparing the consolidated financial statements, Quanta translates the financial statements of its foreign operating units from their functional currency into U.S. dollars. Statements of operations, comprehensive income and cash flows are translated at average monthly rates, while balance sheets are translated at month-end exchange rates. The translation of the balance sheet results in translation gains or losses, which are included as a separate component of equity under the caption “Accumulated other comprehensive income (loss).” Gains and losses arising from transactions which are not denominated in the operating units’ functional currencies are included within other income (expense) in the statements of operations.

Comprehensive Income

Components of comprehensive income include all changes in equity during a period except those resulting from changes in Quanta’s capital related accounts. Quanta records other comprehensive income (loss) for foreign currency translation adjustments related to its foreign operations and for other revenues, expenses, gains and losses that are included in comprehensive income, but excluded from net income.

Litigation Costs and Reserves

Quanta records reserves when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. Costs incurred for litigation are expensed as incurred. Further details are presented in Note 11.

Fair Value Measurements

The carrying values of cash equivalents, accounts receivable, accounts payable and accrued expenses approximate fair value due to the short-term nature of these instruments. The carrying value of variable rate debt also approximates fair value. For disclosure purposes, qualifying assets and liabilities are categorized into three broad levels based on the priority of the inputs used to determine their fair values. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). All of Quanta’s cash equivalents were categorized as Level 1 assets at June 30, 2016 and December 31, 2015, as all values were based on unadjusted quoted prices for identical assets in an active market that Quanta has the ability to access.

In connection with Quanta’s acquisitions, identifiable intangible assets acquired include goodwill, backlog, customer relationships, trade names, covenants not-to-compete, patented rights and developed technology. Quanta utilizes the fair value premise as the primary basis for its valuation procedures, which is a market-based approach to determine the price that would be received to sell an asset or paid to transfer a liability in an orderly

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transaction between market participants. Quanta periodically engages the services of an independent valuation firm when a new business is acquired to assist management with this valuation process, including assistance with the selection of appropriate valuation methodologies and the development of market-based valuation assumptions. Based on these considerations, management utilizes various valuation methods, including an income approach, a market approach and a cost approach, to determine the fair value of intangible assets acquired based on the appropriateness of each method in relation to the type of asset being valued. The assumptions used in these valuation methods are analyzed and compared, where possible, to available market data, such as industry-based weighted average costs of capital and discount rates, trade name royalty rates, public company valuation multiples and recent market acquisition multiples. In accordance with its annual impairment test during the quarter ended December 31, 2015, the carrying amounts of such assets, including goodwill, were compared to their fair values. The level of inputs used for these fair value measurements is the lowest level (Level 3). Quanta uses the assistance of third party specialists to develop valuation assumptions. Quanta believes that these valuation methods appropriately represent the methods that would be used by other market participants in determining fair value.

Quanta also uses fair value measurements in connection with the valuation of its investments in private company equity interests and financing instruments. These valuations require significant management judgment due to the absence of quoted market prices, the inherent lack of liquidity and the long-term nature of such assets. Typically, the initial costs of these investments are considered to represent fair market value, as such amounts are negotiated between willing market participants. On a quarterly basis, Quanta performs an evaluation of its investments to determine if an other-than-temporary decline in the value of each investment has occurred and whether the recorded amount of each investment will be realizable. If an other-than-temporary decline in the value of an investment occurs, a fair value analysis would be performed to determine the degree to which the investment was impaired and a corresponding charge to earnings would be recorded during the period. These types of fair market value assessments are similar to other nonrecurring fair value measures used by Quanta, which include the use of significant judgment and available relevant market data. Such market data may include observations of the valuation of comparable companies, risk adjusted discount rates and an evaluation of the expected performance of the underlying portfolio asset, including historical and projected levels of profitability or cash flows. In addition, a variety of additional factors may be reviewed by management, including, but not limited to, contemporaneous financing and sales transactions with third parties, changes in market outlook and the third-party financing environment.

3.	NEW ACCOUNTING PRONOUNCEMENTS:

Adoption of New Accounting Pronouncements

In February 2015, the FASB issued an update which amends existing consolidation guidance, including amending the guidance related to determining whether an entity is a variable interest entity. The guidance may be applied using a modified retrospective approach whereby the entity records a cumulative effect of adoption at the beginning of the fiscal year of initial application. A reporting entity may also apply the amendments on a full retrospective basis. Quanta adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on Quanta’s consolidated financial statements or related disclosures.

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issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. Quanta adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on Quanta’s consolidated financial statements or related disclosures.

In April 2015, the FASB issued an update that provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, then the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. An entity can elect to adopt the amendments either prospectively to all arrangements entered into or materially modified after the effective date or retrospectively. Quanta adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on Quanta’s consolidated financial statements or related disclosures.

In September 2015, the FASB issued an update that requires an acquiring company to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which such adjustments are determined. An acquiring company must record any effect on earnings from changes in depreciation or amortization or other income effects, calculated as if the accounting had been completed at the acquisition date. The acquiring company must also present separately on the face of the income statement or disclose in the notes the amount recorded in current-period earnings that would have been recorded in previous reporting periods if the adjustment had been recognized as of the acquisition date. The update is required to be adopted prospectively to adjustments that occur after the effective date with earlier application permitted for financial statements that have not yet been issued. Quanta adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on Quanta’s consolidated financial statements or related disclosures.

Accounting Standards Not Yet Adopted

In May 2014, the FASB issued an update that supersedes most current revenue recognition guidance as well as some cost recognition guidance. The update requires that an entity recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This update also requires new qualitative and quantitative disclosures about the nature, amount, timing and uncertainty of revenues and cash flows arising from customer contracts, including significant judgments and changes in judgments, information about contract balances and performance obligations, and assets recognized from costs incurred to obtain or fulfill a contract. In July 2015, the FASB affirmed its proposal to defer the effective date until fiscal years beginning on or after December 15, 2017. The guidance can be applied on a full retrospective or modified retrospective basis whereby the entity records a cumulative effect of initially applying this update at the date of initial application. Quanta is currently evaluating the potential impact of this authoritative guidance on its consolidated financial statements and will adopt this guidance effective January 1, 2018.

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entity’s ability to continue as a going concern for a period of one year after the date that the financial statements are issued (or available to be issued), along with the principal conditions or events that raise substantial doubt, management’s evaluation of the significance of those conditions or events in relation to the entity’s ability to meet its obligations and management’s plans that are intended to mitigate those conditions or events. The guidance is effective for annual and interim periods ending after December 15, 2016. This guidance will impact the disclosure and presentation of any substantial doubt by Quanta about its ability to continue as a going concern, if such substantial doubt were to exist. Quanta will adopt this guidance by December 31, 2016.

In July 2015, the FASB issued an update that requires inventory to be measured at the lower of either cost or net realizable value. When evidence exists that the net realizable value of inventory is lower than its cost, the difference will be recognized as a loss in earnings in the period in which it occurs. The update is required to be adopted prospectively and is effective for interim and annual reporting periods beginning after December 15, 2016, although early adoption is permitted. Quanta is currently evaluating the potential impact of this authoritative guidance on its consolidated financial statements and will adopt this guidance by January 1, 2017.

In January 2016, the FASB issued an update that addresses certain aspects of recognition, measurement, presentation, and disclosure of financial instruments. The new standard is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for financial statements of fiscal years or interim periods that have not been previously issued. Quanta is evaluating the impact of the new standard on its consolidated financial statements and will adopt the new standard by January 1, 2018.

In February 2016, the FASB issued an update that requires companies that lease assets to recognize on the balance sheet the assets and liabilities for the rights and obligations created by those assets. The new standard is effective for interim and annual periods beginning after December 15, 2018. Early adoption is permitted for financial statements of fiscal years or interim periods that have not been previously issued. Quanta is evaluating the impact of the new standard on its consolidated financial statements and will adopt the new standard by January 1, 2019.

In March 2016, the FASB issued an update that requires companies with share-based payments to record all of the tax effects related to such share-based payments at settlement (or expiration) through the income statement rather than through equity. It is anticipated that companies will experience increased volatility of income tax expense upon adoption of this update. This change is required to be applied prospectively to all excess tax benefits and tax deficiencies resulting from settlements after the date of the adoption of the update and is effective for interim and annual reporting periods beginning after December 15, 2016, although early adoption is permitted. Quanta is currently evaluating the potential impact of this authoritative guidance on its consolidated financial statements and will adopt this guidance by January 1, 2017.

In June 2016, the FASB issued an update that will change the way companies measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The update will require companies to use an “expected loss” model for instruments measured at amortized cost and to record allowances for available-for-sale (AFS) debt securities rather than reduce the carrying amounts. The update will also require disclosure of information regarding how a company developed its allowance, including changes in the factors that influenced management’s estimate of expected credit losses and the reasons for those changes. Companies will apply this standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The new standard is effective for interim and annual reporting periods beginning after December 15, 2019, although early adoption is permitted for annual reporting periods beginning after December 15, 2018. Quanta is currently evaluating the potential impact

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(Unaudited)

of this authoritative guidance on its consolidated financial statements and will adopt this guidance by January 1, 2020.

4.	DISCONTINUED OPERATIONS:

On August 4, 2015, Quanta completed the sale of its fiber optic licensing operations to Crown Castle for an aggregate purchase price of approximately $1 billion in cash, resulting in estimated after-tax net proceeds of approximately $848 million. In the third quarter of 2015, Quanta recognized a pre-tax gain of approximately $272 million and a corresponding tax expense of approximately $101 million, which resulted in a gain on the sale, net of tax, of approximately $171 million.

Quanta has presented the results of operations, financial position, cash flows and disclosures related to its fiber optic licensing operations as discontinued operations in the accompanying unaudited condensed consolidated financial statements. The results were included in Quanta’s Fiber Optic Licensing and Other segment prior to the second quarter of 2015.

Quanta will remain liable for all taxes and insured claims associated with the fiber optic licensing operations arising on or before or outstanding as of August 4, 2015.

The following represents a reconciliation of the major classes of line items constituting income from discontinued operations related to Quanta’s fiber optic licensing operations (in thousands):


	Three Months Ended			Six Months Ended
	June 30, 2015			June 30, 2015
Major classes of line items constituting pretax income from discontinued operations:
Revenues	$	25,692		$	51,262
Expenses:
Cost of services (including depreciation)		10,896			21,711
Selling, general and administrative expenses		5,106			9,881
Amortization of intangible assets		413			825

Other income (expense) items that are not major		9			10

Income before taxes of discontinued operations		9,286			18,855
Provision for income taxes related to discontinued operations		(4,816	)		(1,042	)

Net income from discontinued operations as presented in the statements of operations	$	14,102		$	19,897

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(Unaudited)

There were no assets or non-current liabilities associated with fiber optic licensing operations at June 30, 2016 or December 31, 2015. The following represents a reconciliation of the carrying amounts of major classes of current liabilities of fiber optic licensing operations (in thousands):


	June 30, 2016		December 31, 2015
Carrying amounts of major classes of liabilities of discontinued operations:
Current liabilities:
Accounts payable and accrued expenses	$	2,651	$	15,313

Total current liabilities of discontinued operations	$	2,651	$	15,313

5.	ACQUISITIONS:

2016 Acquisitions

During the first quarter of 2016, Quanta completed three acquisitions. The results of two of the acquired companies are generally included in Quanta’s Electric Power Infrastructure Services segment. These companies included a full service medium- and high-voltage powerline contracting company located in the United States and a telecommunications company located in Canada. Quanta also acquired a pipeline service contractor located in the United States, the results of which are generally included in Quanta’s Oil and Gas Infrastructure Services segment. The aggregate consideration for these acquisitions consisted of approximately $42.2 million paid or payable in cash, subject to certain adjustments, and contingent consideration payments of up to $35 million, which will be paid if certain financial targets are achieved. Based on the estimated fair value of this contingent consideration, Quanta recorded a $15.4 million liability. As these transactions were effective during the first quarter of 2016, the results have been included in Quanta’s consolidated financial statements beginning on the respective dates of acquisition. These acquisitions should enable Quanta to further enhance its service offerings in the United States and Canada.

2015 Acquisitions

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(Unaudited)

respective dates of acquisition. These acquisitions should enable Quanta to further enhance its electric power and oil and gas infrastructure service offerings in the United States, Canada and Australia.

2016 and 2015 Acquisitions

Quanta is in the process of finalizing its assessments of the fair values of the acquired assets and assumed liabilities related to businesses acquired subsequent to June 30, 2015, and further adjustments to the purchase price allocations may occur. Quanta expects to complete the purchase accounting process as soon as practicable but no later than one year from the respective acquisition dates with possible updates primarily related to certain tax estimates. The aggregate purchase consideration related to the businesses acquired in 2015 subsequent to June 30, 2015 was preliminarily allocated to acquired assets and assumed liabilities, which resulted in a preliminary allocation of approximately $19.4 million of net tangible assets, $26.4 million of goodwill and $10.2 million of other intangible assets. Additionally, the aggregate purchase consideration related to the first quarter 2016 acquisitions was preliminarily allocated to acquired assets and assumed liabilities, which resulted in a preliminary allocation of approximately $23.2 million of net tangible assets, $26.1 million of goodwill and $8.3 million of other intangible assets.

The following table summarizes the aggregate consideration paid or payable as of June 30, 2016 for the 2016 and 2015 acquisitions and presents the allocation of these amounts to the net tangible and identifiable intangible assets based on their estimated fair values as of the respective acquisition dates. This allocation requires a significant use of estimates and is based on information that was available to management at the time these consolidated financial statements were prepared (in thousands).


	2016			2015
Consideration:
Value of Quanta common stock and exchangeable shares issued	$	—		$	10,127
Cash paid or payable		42,211			110,428
Contingent consideration		15,400			1,001

Fair value of total consideration transferred or estimated to be transferred	$	57,611		$	121,556

Current assets	$	16,489		$	35,188
Property and equipment		30,649			44,140
Other assets		1,972			4
Identifiable intangible assets		8,327			24,987
Current liabilities		(7,349	)		(24,633	)
Deferred tax liabilities, net		(13,267	)		(4,912	)
Other long-term liabilities		(5,326	)		(5,606	)
Non-controlling interests		—			747

Total identifiable net assets		31,495			69,915
Goodwill		26,116			51,641

	$	57,611		$	121,556

The fair value of current assets acquired in 2016 included accounts receivable with a fair value of $10.2 million. The fair value of current assets acquired in 2015 included accounts receivable with a fair value of $20.6 million.

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(Unaudited)

Goodwill represents the excess of the purchase price over the net amount of the fair values assigned to assets acquired and liabilities assumed. The 2016 and 2015 acquisitions strategically expanded Quanta’s Canadian, Australian and domestic electric power and oil and gas service offerings, which Quanta believes contributes to the recognition of the goodwill. In connection with the 2016 acquisitions, goodwill of $5.8 million was recorded for the businesses acquired that were included within Quanta’s Electric Power Infrastructure Services Division and $20.3 million was recorded for the business acquired that was included within Quanta’s Oil and Gas Infrastructure Services Division on the dates of acquisition. In connection with the 2015 acquisitions, goodwill of $31.2 million was recorded for the businesses acquired that were included within Quanta’s Electric Power Infrastructure Services Division and $20.4 million was recorded for businesses included within Quanta’s Oil and Gas Infrastructure Services Division on the dates of acquisition. Goodwill of approximately $0.4 million is expected to be deductible for income tax purposes related to the businesses acquired in the first six months of 2016, and goodwill of approximately $33.9 million is expected to be deductible for income tax purposes related to the businesses acquired in 2015.

The following table summarizes the estimated fair values of identifiable intangible assets and the related weighted average amortization periods by type as of the respective acquisition dates for the 2016 acquisitions (in thousands, except for weighted average amortization periods, which are in years).


	Estimated Fair Value at Acquisition Date		Weighted Average Amortization Period at Acquisition Date in Years
Customer relationships	$	4,814		3.3
Backlog		822		3.1
Trade names		2,448		15.0
Non-compete agreements		243		5.0

Total intangible assets subject to amortization acquired in 2016 acquisitions	$	8,327		6.8

The unaudited supplemental pro forma results of operations have been provided for illustrative purposes only and do not purport to be indicative of the actual results that would have been achieved by the combined companies for the periods presented or that may be achieved by the combined companies in the future. Future results may vary significantly from the results reflected in the following pro forma financial information because of future events and transactions, as well as other factors (in thousands, except per share amounts):


	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Revenues	$	1,792,430	$	1,916,000	$	3,513,472	$	3,835,457
Gross profit	$	200,217	$	235,282	$	403,682	$	484,237
Selling, general and administrative expenses	$	156,607	$	154,023	$	315,817	$	305,998
Amortization of intangible assets	$	8,141	$	9,910	$	15,792	$	19,648
Net income from continuing operations	$	16,729	$	37,053	$	37,069	$	91,347
Net income from continuing operations attributable to common stock	$	16,562	$	33,597	$	36,539	$	83,190
Earnings per share from continuing operations attributable to common stock — basic and diluted	$	0.11	$	0.16	$	0.23	$	0.39

The pro forma combined results of operations for the three and six months ended June 30, 2016 and 2015 have been prepared by adjusting the historical results of Quanta to include the historical results of the 2016

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(Unaudited)

acquisitions as if they occurred January 1, 2015. The pro forma combined results of operations for the three and six months ended June 30, 2015 have also been prepared by adjusting the historical results of Quanta to include the historical results of the 2015 acquisitions as if they occurred January 1, 2014. These pro forma combined historical results were also adjusted for the following: a reduction of interest expense as a result of the repayment of outstanding indebtedness of the acquired businesses, a reduction of interest income as a result of the cash consideration paid net of cash received, an increase in amortization expense due to the incremental intangible assets recorded related to the 2016 and 2015 acquisitions, an increase or decrease in depreciation expense within cost of services related to the net impact of adjusting acquired property and equipment to the acquisition date fair value and conforming depreciable lives with Quanta’s accounting policies, an increase in the number of outstanding shares of Quanta common stock and exchangeable shares and certain reclassifications to conform the acquired companies’ presentation to Quanta’s accounting policies. The pro forma results of operations do not include any adjustments to eliminate the impact of acquisition related costs or any cost savings or other synergies that may result from the 2016 and 2015 acquisitions. As noted above, the pro forma results of operations do not purport to be indicative of the actual results that would have been achieved by the combined company for the periods presented or that may be achieved by the combined company in the future.

Revenues of approximately $18.9 million and income before taxes of approximately $1.5 million were included in Quanta’s consolidated results of operations for the three months ended June 30, 2016 related to the three 2016 acquisitions following their respective dates of acquisition. Revenues of approximately $24.5 million and a loss before taxes of approximately $1.0 million were included in Quanta’s consolidated results of operations for the six months ended June 30, 2016 related to the three 2016 acquisitions following their respective dates of acquisition.

6.	GOODWILL AND OTHER INTANGIBLE ASSETS:

A summary of changes in Quanta’s goodwill is as follows (in thousands):


	Electric Power Infrastructure Services Division		Oil and Gas Infrastructure Services Division			Total
Balance at December 31, 2015:
Goodwill	$	1,226,245	$	366,306		$	1,592,551
Accumulated impairment		—		(39,893	)		(39,893	)

		1,226,245		326,413			1,552,658
Goodwill acquired during 2016		5,829		20,287			26,116
Purchase price allocation adjustments ⁽¹⁾		—		(214	)		(214	)
Foreign currency translation adjustments		10,702		6,293			16,995


Balance at June 30, 2016:
Goodwill		1,242,776		392,964			1,635,740
Accumulated impairment		—		(40,185	)		(40,185	)

	$	1,242,776	$	352,779		$	1,595,555

⁽¹⁾	Adjustments represent changes in deferred tax liability estimates and would have had no impact on the consolidated financial statements in prior periods had these adjustments been booked at the respective acquisition dates.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

As described in Note 2, Quanta’s operating units are organized into one of Quanta’s two internal divisions and, accordingly, the goodwill associated with its operating units has been aggregated on a divisional basis and reported in the table above. These divisions are closely aligned with Quanta’s reportable segments and are based on the predominant type of work performed by each operating unit. From time to time, operating units may be reorganized between these internal divisions as business environments evolve.

Quanta’s intangible assets subject to amortization and the remaining weighted average amortization periods related to such assets were as follows (in thousands except for weighted average amortization periods, which are in years):


	As of							As of							As of
	June 30, 2016							December 31, 2015							June 30, 2016
	Intangible Assets		Accumulated Amortization			Intangible Assets, Net		Intangible Assets		Accumulated Amortization			Intangible Assets, Net		Remaining Weighted Average Amortization Period in Years
Customer relationships	$	247,198	$	(101,744	)	$	145,454	$	236,731	$	(90,840	)	$	145,891		9.1
Backlog		133,623		(131,086	)		2,537		130,818		(126,954	)		3,864		0.8
Trade names		54,547		(11,313	)		43,234		51,192		(9,525	)		41,667		18.0
Non-compete agreements		29,280		(24,890	)		4,390		28,560		(23,507	)		5,053		3.3
Patented rights and developed technology		22,497		(14,856	)		7,641		22,447		(13,848	)		8,599		4.5

Total intangible assets subject to amortization	$	487,145	$	(283,889	)	$	203,256	$	469,748	$	(264,674	)	$	205,074		10.6

Amortization expense for intangible assets was $8.1 million and $8.7 million for the three months ended June 30, 2016 and 2015 and $15.6 million and $17.0 million for the six months ended June 30, 2016 and 2015.

The estimated future aggregate amortization expense of intangible assets subject to amortization as of June 30, 2016 is set forth below (in thousands):


For the Fiscal Year Ending December 31,
Remainder of 2016	$	15,288
2017		25,203
2018		24,394
2019		22,363
2020		21,046
Thereafter		94,962

Total	$	203,256

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

7.	PER SHARE INFORMATION:


	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Amounts attributable to common stock:
Net income from continuing operations	$	16,562	$	32,007	$	37,058	$	79,696
Net income from discontinued operations		—		14,102		—		19,897

Net income attributable to common stock	$	16,562	$	46,109	$	37,058	$	99,593

Weighted average shares:
Weighted average shares outstanding for basic earnings per share		156,128		213,047		159,577		214,257
Effect of dilutive stock options		2		12		2		12

Weighted average shares outstanding for diluted earnings per share		156,130		213,059		159,579		214,269

For purposes of calculating diluted earnings per share, there were no adjustments required to derive Quanta’s net income attributable to common stock. Outstanding exchangeable shares that were issued pursuant to certain of Quanta’s historical acquisitions (as further discussed in Note 9), which are exchangeable on a one-for-one basis with shares of Quanta common stock, have been included in weighted average shares outstanding for basic and diluted earnings per share for the three and six months ended June 30, 2016 and 2015. Weighted average shares outstanding for basic and diluted earnings per share for the three and six months ended June 30, 2016 were reduced by the additional shares received in settlement of Quanta’s accelerated share repurchase arrangement (as further described in Note 9) as of April 12, 2016.

8.	DEBT OBLIGATIONS:

Quanta’s long-term debt obligations consisted of the following (in thousands):


	June 30, 2016		December 31, 2015
Borrowings under credit facility	$	398,028	$	466,850
Other long-term debt, interest rates ranging from 3.5% to 4.3%		3,917		5,401
Capital leases, interest rates ranging from 2.5% to 6.2%		4,777		5,351

Total long-term debt obligations		406,722		477,602
Less — Current maturities of long-term debt		5,603		2,238

Total long-term debt obligations, net of current maturities	$	401,119	$	475,364

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(Unaudited)

Quanta’s current maturities of long-term debt and short-term borrowings consisted of the following (in thousands):


	June 30, 2016		December 31, 2015
Short-term borrowings	$	—	$	4,829
Current maturities of long-term debt		5,603		2,238

Current maturities of long-term debt and short-term borrowings	$	5,603	$	7,067

Credit Facility

On December 18, 2015, Quanta entered into an amended and restated credit agreement with various lenders that provides for a $1.81 billion senior secured revolving credit facility maturing on December 18, 2020. The entire amount available under the facility may be used by Quanta for revolving loans and letters of credit in U.S. dollars and certain alternative currencies. Up to $600.0 million of the facility may be used by certain subsidiaries of Quanta for revolving loans and letters of credit in certain alternative currencies. Up to $100.0 million of the facility may be used for swing line loans in U.S. dollars, up to $50.0 million of the facility may be used for swing line loans in Canadian dollars and up to $30.0 million of the facility may be used for swing line loans in Australian dollars. In addition, subject to the conditions specified in the credit agreement, Quanta has the option to increase the revolving commitments by up to $400.0 million from time to time upon receipt of additional commitments from new or existing lenders. Borrowings under the credit agreement are to be used to refinance existing indebtedness and for working capital, capital expenditures and other general corporate purposes.

As of June 30, 2016, Quanta had approximately $317.3 million of outstanding letters of credit and bank guarantees, $217.6 million of which were denominated in U.S. dollars and $99.7 million of which were denominated in Australian or Canadian dollars. Quanta also had $398.0 million of outstanding revolving loans under the credit facility, $300.0 million of which were denominated in U.S. dollars and $98.0 million of which were denominated in Canadian dollars. The remaining $1.09 billion was available for revolving loans or issuing new letters of credit or bank guarantees. Information on borrowings under Quanta’s credit facility and the applicable interest rates during the three and six months ended June 30, 2016 and 2015 is as follows (dollars in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Maximum amount outstanding during the period	$	465,599		$	330,473		$	518,607		$	330,473
Average daily amount outstanding under the credit facility	$	426,172		$	171,638		$	449,101		$	132,213
Weighted-average interest rate		2.17	%		2.01	%		2.08	%		2.13	%

Under the current credit agreement, amounts borrowed in U.S. dollars bear interest, at Quanta’s option, at a rate equal to either (i) the Eurocurrency Rate (as defined in the credit agreement) plus 1.125% to 2.125%, as determined based on Quanta’s Consolidated Leverage Ratio (as described below), or (ii) the Base Rate (as described below) plus 0.125% to 1.125%, as determined based on Quanta’s Consolidated Leverage Ratio. Amounts borrowed as revolving loans under the credit agreement in any currency other than U.S. dollars bear interest at a rate equal to the Eurocurrency Rate plus 1.125% to 2.125%, as determined based on Quanta’s Consolidated Leverage Ratio. Standby letters of credit issued under the credit agreement are subject to a letter of

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(Unaudited)

credit fee of 1.125% to 2.125%, based on Quanta’s Consolidated Leverage Ratio, and Performance Letters of Credit (as defined in the credit agreement) issued under the credit agreement in support of certain contractual obligations are subject to a letter of credit fee of 0.675% to 1.275%, based on Quanta’s Consolidated Leverage Ratio. Quanta is also subject to a commitment fee of 0.20% to 0.40%, based on its Consolidated Leverage Ratio, on any unused availability under the credit agreement.

The Consolidated Leverage Ratio is the ratio of Quanta’s Consolidated Funded Indebtedness to Consolidated EBITDA (as those terms are defined in the credit agreement). For purposes of calculating Quanta’s Consolidated Leverage Ratio, Consolidated Funded Indebtedness is reduced by available cash and Cash Equivalents (as defined in the credit agreement) in excess of 25.0 million. The Base Rate equals the highest of (i) the Federal Funds Rate (as defined in the credit agreement) plus 0.5%, (ii) the prime rate publicly announced by Bank of America, N.A. and (iii) the Eurocurrency Rate plus 1.00%.

Subject to certain exceptions, the credit agreement is secured by substantially all the assets of Quanta and Quanta’s wholly owned U.S. subsidiaries and by a pledge of all of the capital stock of Quanta’s wholly owned U.S. subsidiaries and 65% of the capital stock of direct foreign subsidiaries of Quanta’s wholly owned U.S. subsidiaries. Quanta’s wholly owned U.S. subsidiaries also guarantee the repayment of all amounts due under the credit agreement. Subject to certain conditions, all collateral will automatically be released from the liens at any time Quanta maintains an Investment Grade Rating (defined in the credit agreement as two of the following three conditions being met: (i) a corporate credit rating that is BBB- or higher by Standard & Poor’s Rating Services, (ii) a corporate family rating that is Baa3 or higher by Moody’s Investors Services, Inc. or (iii) a corporate credit rating that is BBB- or higher by Fitch Ratings, Inc.).

The credit agreement contains certain covenants, including a maximum Consolidated Leverage Ratio and a minimum Consolidated Interest Coverage Ratio (as defined in the credit agreement). The credit agreement also limits certain acquisitions, mergers and consolidations, indebtedness, asset sales and prepayments of indebtedness and, subject to certain exceptions, prohibits liens on Quanta’s assets. The credit agreement allows cash payments for dividends and stock repurchases subject to compliance with the following requirements (after giving effect to the dividend or stock repurchase): (i) no default or event of default under the credit agreement; (ii) continued compliance with the financial covenants in the credit agreement; and (iii) at least $100.0 million of availability under the credit agreement and/or cash and cash equivalents on hand. As of June 30, 2016, Quanta was in compliance with all of the covenants in the credit agreement.

The credit agreement provides for customary events of default and contains cross-default provisions with Quanta’s underwriting, continuing indemnity and security agreement with its sureties and all of Quanta’s other debt instruments exceeding $100.0 million in borrowings or availability. If an Event of Default (as defined in the credit agreement) occurs and is continuing, on the terms and subject to the conditions set forth in the credit agreement, the lenders may declare all amounts outstanding and accrued and unpaid interest immediately due and payable, require that Quanta provide cash collateral for all outstanding letter of credit obligations, terminate the commitments under the credit agreement, and foreclose on the collateral.

9.	EQUITY:

Exchangeable Shares and Series F and Series G Preferred Stock

In connection with certain Canadian acquisitions, the former owners of the acquired companies received exchangeable shares of certain Canadian subsidiaries of Quanta, which may be exchanged at the option of the holders for Quanta common stock on a one-for-one basis. The holders of exchangeable shares can make an

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(Unaudited)

exchange only once in any calendar quarter and must exchange a minimum of either 50,000 shares or, if less, the total number of remaining exchangeable shares registered in the name of the holder making the request. Additionally, in connection with two of such acquisitions, Quanta issued one share of Quanta Series F preferred stock and one share of Quanta Series G preferred stock (the Preferred Stock) to voting trusts on behalf of the respective holders of the exchangeable shares issued in such acquisitions. Each share of the Preferred Stock provides the holders of such exchangeable shares voting rights in Quanta common stock equivalent to the number of exchangeable shares outstanding at that time.

The holders of exchangeable shares associated with the Preferred Stock have rights equivalent to Quanta common stockholders with respect to voting, dividends and other economic rights. The holders of exchangeable shares not associated with the Preferred Stock have rights equivalent to Quanta common stockholders with respect to dividends and other economic rights but do not have voting rights.

As of June 30, 2016, both shares of the Preferred Stock remained outstanding and 6,876,042 exchangeable shares remained outstanding, of which 3,949,929 were associated with the Preferred Stock.

Treasury Stock

Under the stock incentive plans described in Note 10, the tax withholding obligations of employees upon vesting of restricted stock awards and RSUs settled in common stock are typically satisfied by Quanta making such tax payments and withholding a number of vested shares having a value on the date of vesting equal to the tax withholding obligation. For the settlement of these employee tax liabilities, Quanta withheld 352,061 and 345,083 shares of Quanta common stock during the six months ended June 30, 2016 and 2015, with a total market value of $7.2 million and $9.9 million. These shares and the related costs to acquire them were accounted for as adjustments to the balance of treasury stock. Under Delaware corporate law, treasury stock is not counted for quorum purposes or entitled to vote.

During the fourth quarter of 2013, Quanta’s board of directors approved a stock repurchase program authorizing Quanta to purchase, from time to time through December 31, 2016, up to $500.0 million of its outstanding common stock (the 2013 Repurchase Program). During the nine months ended September 30, 2015, Quanta repurchased 14.3 million shares of its common stock at a cost of $406.5 million in the open market under the 2013 Repurchase Program and completed the 2013 Repurchase Program.

During the third quarter of 2015, Quanta’s board of directors approved a new stock repurchase program authorizing Quanta to purchase, from time to time through February 28, 2017, up to $1.25 billion of its outstanding common stock (the 2015 Repurchase Program). Repurchases under the 2015 Repurchase Program can be made in open market or privately negotiated transactions, including pursuant to an accelerated share repurchase arrangement, an issuer repurchase plan or otherwise, at management’s discretion, based on market and business conditions, applicable contractual and legal requirements and other factors. The 2015 Repurchase Program does not obligate Quanta to acquire any specific amount of common stock and may be modified or terminated by Quanta’s board of directors at any time at its sole discretion and without notice. During the third and fourth quarters of 2015, Quanta repurchased 19.2 million shares of its common stock at a cost of $449.9 million in the open market under the 2015 Repurchase Program.

Also during the third quarter of 2015, Quanta entered into an accelerated share repurchase arrangement (the ASR) to repurchase $750.0 million of its common stock under the 2015 Repurchase Program. Under the terms of the ASR, Quanta paid $750.0 million to JPMorgan Chase Bank, National Association, London Branch

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(JPMorgan) and initially received 25.7 million shares of its common stock. The fair market value of these 25.7 million shares at the time of delivery was approximately $600.0 million, and the repurchased shares and the related cost to acquire them were accounted for as an adjustment to the balance of treasury stock during the quarter ended September 30, 2015, reducing the weighted-average number of basic and diluted common shares used to calculate Quanta’s earnings per share. The $150.0 million remaining under the ASR was recorded as an adjustment to additional paid-in capital (APIC) during the quarter ended September 30, 2015 and was reclassified from APIC to treasury stock on April 12, 2016 as a result of the final settlement of the ASR. On April 12, 2016, upon final settlement of the ASR and based on the final volume-weighted average share price during the term of the ASR, minus a discount and subject to other adjustments pursuant to the terms and conditions of the ASR, Quanta received 9.4 million additional shares of its common stock from JPMorgan.

As of April 12, 2016, after final settlement of the ASR, Quanta had repurchased 54.3 million shares of its common stock at a cost of $1.20 billion under the 2015 Repurchase Program, and approximately $50.1 million remained available under the 2015 Repurchase Program.

Non-controlling Interests

Quanta holds investments in several joint ventures that provide infrastructure services under specific customer contracts. Quanta has determined that certain of these joint ventures are VIEs, with Quanta providing the majority of the infrastructure services to the joint venture, which management believes most significantly influences the economic performance of the joint venture. Management has concluded that Quanta is the primary beneficiary of each of the joint ventures determined to be VIEs and has accounted for each on a consolidated basis. The other parties’ equity interests in these joint ventures have been accounted for as non-controlling interests in the condensed consolidated financial statements. Income attributable to the other joint venture members in the amounts of $0.2 million and $3.5 million for the three months ended June 30, 2016 and 2015 and $0.5 million and $8.2 million for the six months ended June 30, 2016 and 2015 has been accounted for as a reduction of net income in deriving net income attributable to common stock. Equity in the consolidated assets and liabilities of these joint ventures that is attributable to the other joint venture members has been accounted for as non-controlling interests within total equity in the accompanying balance sheets.

The carrying value of the investments held by Quanta in all of its VIEs was approximately $2.9 million and $2.3 million at June 30, 2016 and December 31, 2015. The carrying value of investments held by the non-controlling interests in these variable interest entities at June 30, 2016 and December 31, 2015 was $2.9 million and $2.3 million. During the three months ended June 30, 2016 and 2015, distributions to non-controlling interests were none and $2.5 million. During the six months ended June 30, 2016 and 2015, distributions to non-controlling interests were none and $5.0 million. There were no other changes in equity as a result of transfers to/from the non-controlling interests during the six months ended June 30, 2016 or 2015. See Note 11 for further disclosures related to Quanta’s joint venture arrangements.

10.

EQUITY-BASED COMPENSATION:

Stock Incentive Plans

On May 19, 2011, Quanta’s stockholders approved the 2011 Omnibus Equity Incentive Plan (the 2011 Plan). The 2011 Plan provides for the award of non-qualified stock options, incentive (qualified) stock options, stock appreciation rights, restricted stock, RSUs, stock bonus awards, performance compensation awards (including performance units and cash bonus awards) or any combination of the foregoing. The purpose of the 2011 Plan is to provide participants with additional performance incentives by increasing their proprietary

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interest in Quanta. Employees, directors, officers, consultants or advisors of Quanta or its affiliates are eligible to participate in the 2011 Plan, as are prospective employees, directors, officers, consultants or advisors of Quanta who have agreed to serve Quanta in those capacities. An aggregate of 11,750,000 shares of Quanta common stock may be issued pursuant to awards granted under the 2011 Plan.

Additionally, pursuant to the Quanta Services, Inc. 2007 Stock Incentive Plan (the 2007 Plan), which was adopted on May 24, 2007, Quanta may award restricted stock, incentive stock options and non-qualified stock options to eligible employees, directors, and certain consultants and advisors. An aggregate of 4,000,000 shares of common stock may be issued pursuant to awards granted under the 2007 Plan. Quanta also has a Restricted Stock Unit Plan (the RSU Plan), pursuant to which RSUs may be awarded to certain employees and consultants of Quanta’s Canadian operations.

The 2011 Plan, the 2007 Plan and the RSU Plan, together with certain plans assumed by Quanta in acquisitions, are referred to as the Plans.

Restricted Stock and RSUs to be Settled in Common Stock

During each of the three months ended June 30, 2016 and 2015, Quanta granted 0.1 million of RSUs to be settled in common stock under the Plans with weighted average grant date fair values of $23.59 and $29.96. During the six months ended June 30, 2016 and 2015, Quanta granted 1.8 million and 1.2 million of RSUs to be settled in common stock under the Plans with weighted average grant date fair values of $22.11 and $27.90. The grant date fair value for awards of restricted stock and RSUs to be settled in common stock is based on the market value of Quanta common stock on the date of grant. Restricted stock and RSU awards to be settled in common stock are subject to forfeiture, restrictions on transfer and certain other conditions until vesting, which generally occurs in equal installments over a two-year or three-year period following the date of grant. During the restriction period, holders of restricted stock are entitled to vote and receive dividends on such shares.

During each of the three months ended June 30, 2016 and 2015, vesting activity consisted of 0.1 million of shares of restricted stock and RSUs settled in common stock with an approximate fair value at the time of vesting of $1.1 million and $2.3 million. During the six months ended June 30, 2016 and 2015, vesting activity consisted of 1.3 million and 1.1 million of shares of restricted stock and RSUs settled in common stock with an approximate fair value at the time of vesting of $26.4 million and $33.8 million.

During the three months ended June 30, 2016 and 2015, Quanta recognized $8.5 million and $9.0 million on non-cash stock compensation expense related to restricted stock and RSUs to be settled in common stock. During the six months ended June 30, 2016 and 2015, Quanta recognized $21.7 million and $17.8 million in non-cash stock compensation expense related to restricted stock and RSUs to be settled in common stock. As of June 30, 2016, there was approximately $44.0 million of total unrecognized compensation cost related to unvested restricted stock and RSUs to be settled in common stock granted to both employees and non-employees. This cost is expected to be recognized over a weighted average period of 1.97 years.

Performance Units to be Settled in Common Stock

Performance units awarded pursuant to the 2011 Plan provide for the issuance of shares of common stock upon vesting. These performance units cliff-vest at the end of a three-year performance period based on achievement of three-year company financial performance targets and strategic initiatives established by the Compensation Committee. The final amount of earned and vested performance units can range from 0% to 200% of the initial amount awarded based on the level of achievement of performance goals, as determined by the Compensation Committee.

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During the three months ended June 30, 2016 and 2015, Quanta granted 0.1 million and no performance units to be settled in common stock under the 2011 Plan, with a weighted average grant date fair value of $24.11 for the performance units granted during the three months ended June 30, 2016. During the six months ended June 30, 2016 and 2015, Quanta granted 0.3 million and 0.2 million performance units to be settled in common stock under the 2011 Plan, with a weighted average grant date fair value of $22.86 and $28.16. The grant date fair value for awards of performance units to be settled in common stock is based on the market value of Quanta common stock on the date of grant applied to the total number of shares that Quanta anticipates will fully vest. This fair value is expensed ratably over the vesting term and is adjusted for fair value changes, so that the expense recognized for each award is equivalent to the fair value of the final number of earned and vested performance units. During the three months ended June 30, 2016 and 2015, Quanta recognized $1.0 million and $0.7 million in compensation expense associated with performance units to be settled in common stock. During the six months ended June 30, 2016 and 2015, Quanta recognized $1.5 million and $1.4 million in compensation expense associated with performance units to be settled in common stock. No performance units vested, and no shares of common stock were issued in connection with performance units, during the three and six months ended June 30, 2016 and 2015, as applicable performance periods had not yet concluded.

RSUs to be Settled in Cash

Certain RSUs granted by Quanta under the Plans are settled solely in cash. These cash-settled RSUs are intended to provide plan participants with cash performance incentives that are substantially equivalent to the risks and rewards of equity ownership in Quanta, typically vest in equal installments over a two-year or three-year period following the date of grant, and are subject to forfeiture under certain conditions, primarily termination of service. Additionally, subject to certain restrictions, Quanta’s non-employee directors may elect to cash settle a portion of their RSU awards, which generally vest upon conclusion of the director service year. For all RSUs settled in cash, the holders receive for each vested RSU an amount in cash equal to the fair market value on the settlement date of one share of Quanta common stock, as specified in the applicable award agreement.

Compensation expense related to RSUs to be settled in cash was $1.4 million and $1.2 million for the three months ended June 30, 2016 and 2015 and $2.9 million and $2.5 million for the six months ended June 30, 2016 and 2015. Such expense is recorded in selling, general and administrative expenses. RSUs that are anticipated to be settled in cash are not included in the calculation of earnings per share, and the estimated earned value of such RSUs is classified as a liability. Quanta paid $2.4 million and $1.6 million to settle liabilities related to cash-settled RSUs in the three months ended June 30, 2016 and 2015 and $3.4 million and $2.5 million to settle liabilities related to cash-settled RSUs in the six months ended June 30, 2016 and 2015. Accrued liabilities for the estimated earned value of outstanding RSUs to be settled in cash were $2.2 million and $2.7 million at June 30, 2016 and December 31, 2015.

11.

COMMITMENTS AND CONTINGENCIES:

Investments in Affiliates and Other Entities

As described in Note 9, Quanta holds investments in certain joint ventures with third parties for the purpose of providing infrastructure services under certain customer contracts. Losses incurred by these joint ventures are generally shared ratably based on the percentage ownership of the joint venture members. However, each member of the joint venture typically is jointly and severally liable for all of the obligations of the joint venture under the contract with the customer, and therefore can be liable for full performance of the contract with the customer. In circumstances where Quanta’s participation in a joint venture qualifies as a general partnership, the

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joint venture partners are jointly and severally liable for all of the obligations of the joint venture, including obligations owed to the customer or any other person or entity. Quanta is not aware of circumstances that would lead to future claims against it for material amounts in connection with these joint and several liabilities.

In the joint venture arrangements entered into by Quanta, typically each joint venturer indemnifies the other party for any liabilities incurred in excess of the liabilities such other party is obligated to bear under the respective joint venture agreement. It is possible, however, that Quanta could be required to pay or perform obligations in excess of its share if the other joint venturer failed or refused to pay or perform its share of the obligations. Quanta is not aware of circumstances that would lead to future claims against it for material amounts that would not be indemnified.

During the fourth quarter of 2014, a limited partnership in which Quanta is a partner was selected for an engineering, procurement and construction (EPC) electric transmission project to construct approximately 500 kilometers of transmission line and two 500 kV substations. Quanta will provide turnkey EPC services for the entire project. As of June 30, 2016, Quanta had made aggregate contributions to this unconsolidated affiliate of $8.4 million and had received $2.3 million as a return of capital. Also as of June 30, 2016, Quanta had outstanding additional capital commitments associated with investments in an unconsolidated affiliate related to this project as follows (in thousands):


	Capital Commitments
Year Ending December 31 —
Remainder of 2016	$	6,852
2017 ⁽¹⁾		33,199
2018		—
2019		24,511

Total capital commitments associated with investments in an unconsolidated affiliate related to an EPC electrical transmission project	$	64,562

⁽¹⁾	A return of capital from unconsolidated affiliates of approximately $43.8 million is anticipated in August 2017 and is not included in these amounts.

Additionally, as of June 30, 2016, Quanta had outstanding capital commitments associated with investments in unconsolidated affiliates related to planned oil and gas infrastructure projects of approximately $5.0 million, $0.9 million of which is expected to be paid in the third quarter of 2016. Quanta is unable to determine the exact timing of the remaining $4.1 million of these capital commitments but anticipates them to be paid by June 30, 2017.

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Leases

Quanta leases certain land, buildings and equipment under non-cancelable lease agreements, including related party leases. The terms of these agreements vary from lease to lease, including some with renewal options and escalation clauses. The following schedule shows the future minimum lease payments under these leases as of June 30, 2016 (in thousands):


	Operating Leases
Year Ending December 31 —
Remainder of 2016	$	55,908
2017		78,221
2018		56,538
2019		34,412
2020		19,433
Thereafter		26,281

Total minimum lease payments	$	270,793

Rent expense related to operating leases was approximately $58.4 million and $50.9 million for the three months ended June 30, 2016 and 2015 and approximately $114.8 million and $100.2 million for the six months ended June 30, 2016 and 2015.

Quanta has guaranteed the residual value on certain of its equipment operating leases. Quanta has agreed to pay any difference between this residual value and the fair market value of the underlying asset at the date of termination of the leases. At June 30, 2016, the maximum guaranteed residual value was approximately $538.7 million. Quanta believes that no significant payments will be made as a result of the difference between the fair market value of the leased equipment and the guaranteed residual value. However, there can be no assurance that significant payments will not be required in the future.

Committed Expenditures

Quanta has capital commitments for the expansion of its vehicle fleet in order to accommodate manufacturer lead times on certain types of vehicles. As of June 30, 2016, Quanta issued approximately $3.6 million of production orders with expected delivery dates in 2016. Although Quanta has committed to purchase these vehicles at the time of their delivery, Quanta anticipates that these orders will be assigned to third party leasing companies and made available to Quanta under certain of its master equipment lease agreements, thereby releasing Quanta from its capital commitments.

Legal Proceedings

Quanta is from time to time party to various lawsuits, claims and other legal proceedings that arise in the ordinary course of business. These actions typically seek, among other things, compensation for alleged personal injury, breach of contract and/or property damages, employment-related damages, punitive damages, civil penalties or other losses, or injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, Quanta records a reserve when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. In addition, Quanta discloses matters for which management believes a material loss is at least reasonably possible. Except as otherwise stated below, none of these proceedings,

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separately or in the aggregate, are expected to have a material adverse effect on Quanta’s consolidated financial position, results of operations or cash flows. In all instances, management has assessed the matter based on current information and made a judgment concerning its potential outcome, giving due consideration to the nature of the claim, the amount and nature of damages sought and the probability of success. Management’s judgment may prove materially inaccurate, and such judgment is made subject to the known uncertainties of litigation.

Lorenzo Benton v. Telecom Network Specialists, Inc., et al. In June 2006, plaintiff Lorenzo Benton filed a class action complaint in the Superior Court of California, County of Los Angeles, alleging various wage and hour violations against Telecom Network Specialists (TNS), a former subsidiary of Quanta. Benton seeks to represent a class of workers that includes all persons who worked on TNS projects between June 2002 and the present, including individuals that TNS retained through 29 staffing agencies. An amended complaint was filed in August 2007, naming two additional class representatives, one of whom has since settled directly with his employer. The plaintiffs’ motion for class certification was heard and denied in May 2012; however, that decision was appealed, and the case was ultimately remanded for reconsideration. In September 2015, after a hearing in the remanded proceeding, the trial court certified the class as to workers from the various staffing companies at issue. The plaintiffs seek approximately $16 million for class damages and $5 million in attorneys’ fees. Quanta retained liability associated with this matter pursuant to the terms of Quanta’s sale of TNS in December 2012.

Additionally, in November 2007, TNS filed cross complaints for indemnity against the staffing agencies, which employed many of the individuals in question. In December 2012, the trial court heard cross-motions for summary judgment filed by TNS and the staffing agencies pertaining to TNS’s demand for indemnity. The court denied TNS’s motion and granted the motions filed by the staffing agencies. TNS appealed the court’s ruling, and in April 2015, the California Appellate Court reversed the trial court’s decision, vacated its award of attorneys’ fees, and instructed the trial court to reconsider its earlier ruling on TNS’s indemnity claims. At this time, Quanta does not believe this matter will have a material adverse effect on its consolidated financial position, results of operations or cash flows.

SEC Notice. On March 10, 2014, the SEC notified Quanta of an inquiry into certain aspects of Quanta’s activities in certain foreign jurisdictions, including South Africa and the United Arab Emirates. The SEC also requested that Quanta take necessary steps to preserve and retain categories of relevant documents, including those pertaining to Quanta’s U.S. Foreign Corrupt Practices Act compliance program. The SEC has not alleged any violations of law by Quanta or its employees. Quanta has complied with the preservation request and is cooperating with the SEC.

For additional information regarding other pending legal proceedings, see Collective Bargaining Agreements in this Note 11.

Concentrations of Credit Risk

Quanta is subject to concentrations of credit risk related primarily to its cash and cash equivalents and accounts receivable, including amounts related to unbilled accounts receivable and costs and estimated earnings in excess of billings on uncompleted contracts. Substantially all of Quanta’s cash investments are managed by what it believes to be high credit quality financial institutions. In accordance with Quanta’s investment policies, these institutions are authorized to invest this cash in a diversified portfolio of what Quanta believes to be high quality investments, which consist primarily of interest-bearing demand deposits, money market investments,

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money market mutual funds and investment grade commercial paper with original maturities of three months or less. Although Quanta does not currently believe the principal amount of these investments is subject to any material risk of loss, changes in economic conditions could impact the interest income Quanta receives from these investments. In addition, Quanta grants credit under normal payment terms, generally without collateral, to its customers, which include electric power and oil and gas companies, governmental entities, general contractors, and builders, owners and managers of commercial and industrial properties located primarily in the United States, Canada and Australia. Consequently, Quanta is subject to potential credit risk related to changes in business and economic factors throughout the United States, Canada and Australia, which may be heightened as a result of uncertain economic and financial market conditions that have existed in recent years. However, Quanta generally has certain statutory lien rights with respect to services provided. Historically, some of Quanta’s customers have experienced significant financial difficulties, and others may experience financial difficulties in the future. These difficulties expose Quanta to increased risk related to collectability of billed and unbilled receivables and costs and estimated earnings in excess of billings on uncompleted contracts for services Quanta has performed.

At June 30, 2016 and December 31, 2015, one customer accounted for approximately 18% and 12% of Quanta’s consolidated net position. The services provided to this customer related primarily to Quanta’s Electric Power Infrastructure Services segment. No customers represented 10% or more of Quanta’s revenues for the three and six months ended June 30, 2016 and 2015, and no other customers represented 10% or more of Quanta’s consolidated net position as of June 30, 2016 or December 31, 2015.

Self-Insurance

As discussed in Note 2, Quanta is insured for employer’s liability, group health, general liability, auto liability and workers’ compensation claims. As of June 30, 2016 and December 31, 2015, the gross amount accrued for insurance claims totaled $212.9 million and $209.0 million with $158.2 million and $153.5 million considered to be long-term and included in other non-current liabilities. Related insurance recoveries/receivables as of June 30, 2016 and December 31, 2015 were $9.2 million and $8.6 million, of which $0.6 million and $0.6 million were included in prepaid expenses and other current assets and $8.6 million and $8.0 million were included in other assets, net.

Letters of Credit

Certain of Quanta’s vendors require letters of credit to ensure reimbursement for amounts they are disbursing on its behalf, such as to beneficiaries under its self-funded insurance programs. In addition, from time to time, certain customers require Quanta to post letters of credit to ensure payment to its subcontractors and vendors and to guarantee performance under its contracts. Such letters of credit are generally issued by a bank or similar financial institution, typically pursuant to Quanta’s credit facility. Each letter of credit commits the issuer to pay specified amounts to the holder of the letter of credit if the holder demonstrates that Quanta has failed to perform specified actions. If this were to occur, Quanta would be required to reimburse the issuer of the letter of credit. Depending on the circumstances of such a reimbursement, Quanta may also be required to record a charge to earnings for the reimbursement. Quanta does not believe that it is likely that any material claims will be made under a letter of credit in the foreseeable future.

As of June 30, 2016, Quanta had $317.3 million in outstanding letters of credit and bank guarantees under its credit facility to secure its casualty insurance program and various contractual commitments. These are irrevocable stand-by letters of credit with maturities generally expiring at various times throughout 2016 and 2017. Upon maturity, it is expected that the majority of the letters of credit related to the casualty insurance program will be renewed for subsequent one-year periods.

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Performance Bonds and Parent Guarantees

In certain circumstances, Quanta is required to provide performance bonds in connection with its contractual commitments. Quanta has indemnified its sureties for any expenses paid out under these performance bonds. These performance bonds expire at various times ranging from mechanical completion of the related projects to a period extending beyond contract completion in certain circumstances, and as such a determination of maximum potential amounts outstanding requires the use of certain estimates and assumptions. Such amounts can also fluctuate from period to period based upon the mix and level of Quanta’s bonded operating activity. As of June 30, 2016, the total amount of the outstanding performance bonds was estimated to be approximately $2.7 billion. Quanta’s estimated maximum exposure as it relates to the value of the performance bonds outstanding is lowered on each bonded project as the cost to complete is reduced, and each of its commitments under the performance bonds generally extinguishes concurrently with the expiration of its related contractual obligation. The estimated cost to complete these bonded projects was approximately $667 million as of June 30, 2016.

Additionally, from time to time, Quanta guarantees the obligations of its wholly owned subsidiaries, including obligations under certain contracts with customers, certain lease obligations and, in some states, obligations in connection with obtaining contractors’ licenses. Quanta is not aware of any material obligations for performance or payment asserted against it under any of these guarantees.

Employment Agreements

Quanta has various employment agreements with certain executives and other employees, which provide for compensation and certain other benefits and for severance payments under certain circumstances. Certain employment agreements also contain clauses that become effective upon a change of control of Quanta. Quanta may be obligated to pay certain amounts to such employees upon the occurrence of any of the defined events in the various employment agreements.

Collective Bargaining Agreements

Some of Quanta’s operating units are parties to various collective bargaining agreements with unions that represent certain of their employees. The collective bargaining agreements expire at various times and have typically been renegotiated and renewed on terms similar to those in the expiring agreements. From time to time, Quanta is a party to grievance actions based on claims arising out of the collective bargaining agreements. The agreements require the operating units to pay specified wages, provide certain benefits to their union employees and contribute certain amounts to multiemployer pension plans and employee benefit trusts. Quanta’s multiemployer pension plan contribution rates generally are specified in the collective bargaining agreements (usually on an annual basis), and contributions are made to the plans on a “pay-as-you-go” basis based on its union employee payrolls. The location and number of union employees that Quanta employs at any given time and the plans in which they may participate vary depending on the projects Quanta has ongoing at any time and the need for union resources in connection with those projects. Therefore, Quanta is unable to accurately predict its union employee payroll and the amount of the resulting multiemployer pension plan contribution obligation for future periods.

The Pension Protection Act of 2006 (PPA) also added special funding and operational rules generally applicable to plan years beginning after 2007 for multiemployer plans that are classified as “endangered,” “seriously endangered” or “critical” status based on multiple factors (including, for example, the plan’s funded percentage, cash flow position and whether it is projected to experience a minimum funding deficiency). Plans in these classifications must adopt measures to improve their funded status through a funding improvement or

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rehabilitation plan, as applicable, which may require additional contributions from employers (which may take the form of a surcharge on benefit contributions) and/or modifications to retiree benefits. Certain plans to which Quanta contributes or may contribute in the future are in “endangered,” “seriously endangered” or “critical” status. The amount of additional funds, if any, that Quanta may be obligated to contribute to these plans in the future cannot be estimated due to uncertainty of the future levels of work that require the specific use of union employees covered by these plans, as well as the future contribution levels and possible surcharges on contributions applicable to these plans.

Quanta may be subject to additional liabilities imposed by law as a result of its participation in multiemployer defined benefit pension plans. For example, the Employee Retirement Income Security Act of 1974, as amended by the Multiemployer Pension Plan Amendments Act of 1980, imposes certain liabilities upon an employer who is a contributor to a multiemployer pension plan if the employer withdraws from the plan or the plan is terminated or experiences a mass withdrawal. These liabilities include an allocable share of the unfunded vested benefits in the plan for all plan participants, not merely the benefits payable to a contributing employer’s own retirees. As a result, participating employers may bear a higher proportion of liability for unfunded vested benefits if other participating employers cease to contribute or withdraw, with the reallocation of liability being more acute in cases when a withdrawn employer is insolvent or otherwise fails to pay its withdrawal liability. Other than as described below, Quanta is not aware of any material amounts of withdrawal liability that have been incurred as a result of a withdrawal by any of Quanta’s operating units from any multiemployer defined benefit pension plans.

2011 Central States Plan Withdrawal Liability. In the fourth quarter of 2011, certain Quanta subsidiaries withdrew from the Central States, Southeast and Southwest Areas Pension Plan (the Central States Plan). This withdrawal event was the result of an amendment to a collective bargaining agreement with the International Brotherhood of Teamsters (Teamsters) that eliminated certain employers’ obligations to contribute to the Central States Plan, which was then in critical status and significantly underfunded as to its vested benefit obligations. The amendment was negotiated by the Pipe Line Contractors Association (PLCA) on behalf of its members, which include certain Quanta subsidiaries. Because certain other Quanta subsidiaries continued participation in the Central States Plan into 2012, the Quanta subsidiaries’ withdrawals in 2011 effected only a partial withdrawal on behalf of Quanta for 2011. Quanta believed that the partial withdrawal was advantageous because it limited exposure to increased liability resulting from a future withdrawal event, at which point the Central States Plan could have been further underfunded. Quanta and other PLCA members now contribute to a different multiemployer pension plan on behalf of the affected Teamsters employees. While certain additional Quanta subsidiaries continued participation in the Central States Plan into 2012, Quanta believes that such subsidiaries withdrew from the Central States Plan in 2012, thereby effecting a complete withdrawal as of December 30, 2012 for all Quanta subsidiaries.

In connection with the partial withdrawal in 2011, Quanta recorded a withdrawal liability of approximately $32.6 million in the fourth quarter of 2011 based on estimates received from the Central States Plan. The Central States Plan subsequently asserted that the withdrawal of the PLCA members, and thus Quanta’s partial withdrawal, was not effective in 2011. The PLCA and Quanta believed at that time that a legally effective withdrawal had occurred during the fourth quarter of 2011, and this issue was litigated in the federal district court for the Northern District of Illinois, Eastern Division. In September 2013, the district court ruled in favor of the Central States Plan, and that decision was appealed by the PLCA. In July 2014, the Central States Plan provided Quanta with a Notice and Demand claiming partial withdrawal liability in the amount of $39.6 million and requiring Quanta to make payments on this assessment while the dispute is ongoing. In September 2015, the United States Court of Appeals for the Seventh Circuit ruled in favor of the PLCA and reversed the district

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court’s previous ruling which had been in favor of the Central States Plan. Based on the outcome of the appeal, in January 2016, the Central States Plan issued a revised Notice and Demand claiming partial withdrawal liability in the amount of $32.9 million.

Separately, in December 2013, the Central States Plan filed lawsuits against two of Quanta’s other subsidiaries in connection with their withdrawal in 2012. In the first lawsuit, the Central States Plan alleged that the subsidiary elected to participate in the Central States Plan pursuant to the collective bargaining agreement under which it participated. Quanta argued that no such election was made and that any payments made to the Central States Plan were made in error. In July 2014, the parties reached an agreement to settle the lawsuit, and the court dismissed the case with prejudice. In the second lawsuit, the Central States Plan alleged that contributions made by the Quanta subsidiary to a new industry fund created after Quanta withdrew from the Central States Plan should have been made to the Central States Plan. This arguably would have extended the withdrawal date for this subsidiary to at least the end of 2013. Quanta disputed these allegations on the basis that it properly paid contributions to the new industry fund based on the terms of the collective bargaining agreement under which it participated and asserted that it terminated its obligation to contribute to the Central States Plan by the end of 2012. The parties both moved for summary judgment, and in March 2015, the court entered judgment in favor of Quanta. The Central States Plan filed a notice of appeal in April 2015, and in December 2015, the Central States Plan agreed to dismiss the appeal with prejudice.

The ultimate liability associated with the complete withdrawal of Quanta’s subsidiaries from the Central States Plan will depend on various factors, including interpretations of the terms of the collective bargaining agreements under which the subsidiaries participated and whether exemptions from withdrawal liability applicable to construction industry employers will be available. In March 2014, the Central States Plan provided revised estimates indicating that the total withdrawal liability based on certain withdrawal scenarios from 2011 through 2014 could range between $40.1 million and $55.4 million, which Quanta believes to be the range of reasonably possible loss for this matter. Additionally, based on those estimates and allowing for the exclusion of amounts believed by management to have been improperly included in such estimates, Quanta recorded an adjustment to cost of services during the three months ended March 31, 2014 to increase the recognized withdrawal liability to an amount within the range communicated to Quanta by the Central States Plan. Given the unknown nature of some of the factors mentioned above, the final withdrawal liability cannot yet be determined with certainty. Accordingly, it is reasonably possible that the amount owed upon final resolution of these matters could be materially higher than the expense Quanta had recognized through June 30, 2016. Although Quanta disputes the total liability owed to the Central States Plan, it continues to make monthly payments according to the terms of the January 2016 Notice and Demand while the parties determine the final withdrawal liability. As of June 30, 2016, Quanta had made payments totaling $13.7 million toward the withdrawal liability assessment.

2013 Central States Plan Withdrawal Liability. On October 9, 2013, Quanta acquired a company that experienced a complete withdrawal from the Central States Plan prior to the date of acquisition. Prior to the acquisition, the Central States Plan issued a Notice and Demand to the acquired company claiming a withdrawal liability in the total amount of $6.9 million and requiring payments to be made on this assessment while the dispute is ongoing. In connection with the acquisition, Quanta recorded an initial liability of $4.8 million related to this withdrawal liability, and approximately $2.1 million of the purchase price for the acquired company was deposited into an escrow account to fund any withdrawal obligation in excess of the initial liability recorded. In January 2016, the Central States Plan issued a revised Notice and Demand claiming withdrawal liability in the amount of $4.8 million. Although Quanta continues to dispute the total liability owed to the Central States Plan, it continues to make monthly payments according to the terms of this revised Notice and Demand while the parties determine the final withdrawal liability. As of June 30, 2016, payments totaling $3.1 million had been made toward the withdrawal liability assessment.

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

The final amount of withdrawal liability payable in connection with this matter remains the subject of a pending arbitration proceeding and will ultimately depend on various factors, including the outcome of the PLCA litigation described above. However, the acquired company’s withdrawal from the Central States Plan is not expected to have a material impact on Quanta’s financial condition, results of operations or cash flows.

Indemnities

Quanta generally indemnifies its customers for the services it provides under its contracts, as well as other specified liabilities, which may subject Quanta to indemnity claims and liabilities and related litigation. Additionally, in connection with certain acquisitions and dispositions, Quanta has indemnified various parties against specified liabilities that those parties might incur in the future. The indemnities under acquisition or disposition agreements are usually contingent upon the other party incurring liabilities that reach specified thresholds. As of June 30, 2016, except as otherwise set forth above in Legal Proceedings, Quanta does not believe any material liabilities for claims exist against it in connection with any of these indemnity obligations.

In the normal course of Quanta’s acquisition transactions, Quanta obtains rights to indemnification from the sellers or former owners of acquired companies for certain risks, liabilities and obligations arising from their prior operations, such as performance, operational, safety, workforce or tax issues, some of which Quanta may not have discovered during due diligence. However, the indemnities may not cover all of Quanta’s exposure for such pre-acquisition matters and the indemnitors may be unwilling or unable to pay the amounts owed to Quanta. Accordingly, Quanta may incur expenses for which it is not reimbursed. Quanta is currently in the process of identifying certain pre-acquisition obligations associated with non-U.S. payroll taxes that may be due from a business acquired by Quanta in 2013. As of June 30, 2016, Quanta recorded $11.4 million as its best estimate of the pre-acquisition tax obligations and a corresponding indemnification asset, as management expects to recover from the indemnity counterparties any amounts that Quanta may be required to pay in connection with any such obligations.

12.

SEGMENT INFORMATION:

Quanta presents its operations under two reportable segments: (1) Electric Power Infrastructure Services and (2) Oil and Gas Infrastructure Services. This structure is generally based on the broad end-user markets for Quanta’s services. See Note 1 for additional information regarding Quanta’s reportable segments.

Quanta’s segment results are derived from the types of services provided across its operating units in each of the end user markets described above. Quanta’s entrepreneurial business model allows each of its operating units to serve the same or similar customers and to provide a range of services across end user markets. Quanta’s operating units are organized into one of two internal divisions, namely, the Electric Power Infrastructure Services Division and the Oil and Gas Infrastructure Services Division. These internal divisions are closely aligned with the reportable segments described above based on their operating units’ predominant type of work.

Reportable segment information, including revenues and operating income by type of work, is gathered from each operating unit for the purpose of evaluating segment performance in support of Quanta’s market strategies. These classifications of Quanta’s operating unit revenues by type of work for segment reporting purposes can at times require judgment on the part of management. Quanta’s operating units may perform joint infrastructure service projects for customers in multiple industries, deliver multiple types of network services under a single customer contract or provide service across industries, for example, joint trenching projects to install distribution lines for electric power and natural gas customers. In addition, Quanta’s integrated operations

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

and common administrative support at each of its operating units require that certain allocations of shared and indirect costs, such as facility costs and indirect operating expenses, including depreciation and general and administrative costs, be made to determine operating segment profitability. Corporate costs, such as payroll and benefits, employee travel expenses, facility costs, professional fees, acquisition costs and amortization related to intangible assets are not allocated.

Summarized financial information for Quanta’s reportable segments is presented in the following table (in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Revenues:
Electric Power Infrastructure Services	$	1,159,087		$	1,222,324		$	2,346,089		$	2,462,616
Oil and Gas Infrastructure Services		633,343			650,016			1,160,078			1,271,110

Consolidated	$	1,792,430		$	1,872,340		$	3,506,167		$	3,733,726

Operating income (loss):
Electric Power Infrastructure Services	$	75,934		$	88,027		$	163,258		$	197,019
Oil and Gas Infrastructure Services		11,899			35,981			17,740			60,128
Corporate and non-allocated costs		(52,364	)		(55,157	)		(108,235	)		(104,146	)

Consolidated	$	35,469		$	68,851		$	72,763		$	153,001

Depreciation:
Electric Power Infrastructure Services	$	22,937		$	22,072		$	45,882		$	42,989
Oil and Gas Infrastructure Services		17,254			16,783			33,055			33,252
Corporate and non-allocated costs		2,568			2,175			4,992			4,187

Consolidated	$	42,759		$	41,030		$	83,929		$	80,428

Separate measures of Quanta’s assets and cash flows by reportable segment, including capital expenditures, are not produced or utilized by management to evaluate segment performance. Quanta’s fixed assets, which are held at the operating unit level, include operating machinery, equipment and vehicles, as well as office equipment, buildings and leasehold improvements, and are used on an interchangeable basis across its reportable segments. As such, for reporting purposes, total depreciation expense is allocated each quarter among Quanta’s reportable segments based on the ratio of each reportable segment’s revenue contribution to consolidated revenues.

Foreign Operations

During the three months ended June 30, 2016 and 2015, Quanta derived $335.6 million and $359.2 million of its revenues from foreign operations. During the six months ended June 30, 2016 and 2015, Quanta derived $688.0 million and $892.7 million of its revenues from foreign operations. Of Quanta’s foreign revenues, approximately 67% and 84% was earned in Canada during the three months ended June 30, 2016 and 2015 and approximately 73% and 86% was earned in Canada during the six months ended June 30, 2016 and 2015. In addition, Quanta held property and equipment of $334.1 million and $317.6 million in foreign countries, primarily Canada, as of June 30, 2016 and December 31, 2015.

QUANTA SERVICES, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

(Unaudited)

13.

SUBSEQUENT EVENTS:

Acquisitions

During the third quarter of 2016, Quanta has completed two acquisitions. Quanta acquired an electrical infrastructure services company located in Australia and a utility contracting company located in Canada. The results of these businesses will generally be included in Quanta’s Electric Power Infrastructure Services segment. The aggregate consideration paid or payable for these acquisitions was approximately $34.3 million, subject to certain adjustments and certain contingent consideration payments of up to $4.5 million, which may be paid if certain financial targets are achieved. At Quanta’s election, a portion of the consideration and any contingent consideration may include shares of Quanta common stock. As these transactions were closed during the third quarter of 2016, the results will be included in Quanta’s consolidated financial statements beginning on the respective dates of acquisition. These acquisitions should enable Quanta to further enhance its electric power infrastructure service offerings in Australia and Canada.

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 our condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q (Quarterly Report) and with our Annual Report on Form 10-K for the year ended December 31, 2015, which was filed with the Securities and Exchange Commission (SEC) on February 29, 2016 and is available on the SEC’s website at www.sec.gov and on our website, which is www.quantaservices.com. The discussion below contains forward-looking statements that are based upon our current expectations and are subject to uncertainty and changes in circumstances. Actual results may differ materially from these expectations due to inaccurate assumptions and known or unknown risks and uncertainties, including those identified in Uncertainty of Forward-Looking Statements and Information below and Item 1A. Risk Factors of Part II of this Quarterly Report.

Introduction

We are a leading provider of specialty contracting services, offering infrastructure solutions primarily to the electric power and oil and gas industries in the United States, Canada and Australia and select other international markets. The services we provide include the design, installation, upgrade, repair and maintenance of infrastructure within each of the industries we serve, such as electric power transmission and distribution networks, substation facilities, renewable energy facilities, pipeline transmission and distribution systems and facilities, and infrastructure services for the offshore and inland water energy markets.

We report our results under two reportable segments: (1) Electric Power Infrastructure Services and (2) Oil and Gas Infrastructure Services. This structure is generally focused on broad end-user markets for our services. Our consolidated revenues for the six months ended June 30, 2016 were approximately $3.51 billion, of which 66.9% was attributable to the Electric Power Infrastructure Services segment and 33.1% to the Oil and Gas Infrastructure Services segment.

Our customers include many of the leading companies in the industries we serve. We have developed strong strategic alliances with numerous customers and strive to develop and maintain our status as a preferred vendor to our customers. We enter into various types of contracts, including competitive unit price, hourly rate, cost-plus (or time and materials basis), and fixed price (or lump sum basis), the final terms and prices of which are frequently negotiated with the customer. Although the terms of our contracts vary considerably, most are made on either a unit price or fixed price basis in which we agree to do the work for a price per unit of work performed (unit price) or for a fixed amount for the entire project (fixed price). We complete a substantial majority of our fixed price projects, other than certain large transmission projects, within one year, while we frequently provide maintenance and repair work under open-ended unit price or cost-plus master service agreements that are renewable periodically.

We recognize revenue on our unit price and cost-plus contracts as units are completed or services are performed. For our fixed price contracts, we record revenues as work on the contract progresses on a percentage-of-completion basis. Under this method, revenue is recognized based on the percentage of total costs incurred to date in proportion to total estimated costs to complete the contract. Fixed price contracts generally include retainage provisions under which a percentage of the contract price is withheld until the project is complete and has been accepted by our customer.

For internal management purposes, we are organized into two internal divisions, namely, the Electric Power Infrastructure Services Division and the Oil and Gas Infrastructure Services Division. These internal divisions are closely aligned with the reportable segments described above based on the predominant type of work provided by the operating units within each division.

These classifications of our operating unit revenues by type of work for segment reporting purposes can at times require judgment on the part of management. Our operating units may perform joint infrastructure service projects for customers in multiple industries, deliver multiple types of infrastructure services under a single customer contract or provide services across industries, for example, joint trenching projects to install distribution lines for electric power and natural gas customers. Our integrated operations and common administrative support at each of our operating units requires that certain allocations, including allocations of shared and indirect costs, such as facility costs, indirect operating expenses including depreciation, and general and administrative costs, be made to determine operating segment profitability. Corporate costs, such as payroll and benefits, employee travel expenses, facility costs, professional fees, acquisition costs and amortization related to intangible assets are not allocated.

The Electric Power Infrastructure Services segment provides comprehensive network solutions to customers in the electric power industry. Services performed by the Electric Power Infrastructure Services segment generally include the design, installation, upgrade, repair and maintenance of electric power transmission and distribution infrastructure and substation facilities along with other engineering and technical services. This segment also provides emergency restoration services, including the repair of infrastructure damaged by inclement weather, the energized installation, maintenance and upgrade of electric power infrastructure utilizing unique bare hand and hot stick methods and our proprietary robotic arm technologies, and the installation of “smart grid” technologies on electric power networks. In addition, this segment designs, installs and maintains renewable energy generation facilities, consisting of solar, wind and certain types of natural gas generation facilities, and related switchyards and transmission infrastructure. To a lesser extent, this segment provides services such as the construction of electric power generation facilities, the design, installation, maintenance and repair of commercial and industrial wiring, installation of traffic networks and the installation of cable and control systems for light rail lines and limited ancillary telecommunication infrastructure services.

The Oil and Gas Infrastructure Services segment provides comprehensive network solutions to customers involved in the development and transportation of natural gas, oil and other pipeline products. Services performed by the Oil and Gas Infrastructure Services segment generally include the design, installation, repair and maintenance of pipeline transmission and distribution systems, gathering systems, production systems, storage systems and compressor and pump stations, as well as related trenching, directional boring and automatic welding services. In addition, this segment’s services include pipeline protection, integrity testing, rehabilitation and replacement, and fabrication of pipeline support systems and related structures and facilities. We also serve the offshore and inland water energy markets, primarily providing services to oil and gas exploration platforms, including mechanical installation (or “hook-ups”), electrical and instrumentation, pre-commissioning and commissioning, coatings, fabrication, pipeline construction, integrity services and marine asset repair. To a lesser extent, this segment designs, installs and maintains fueling systems, as well as water and sewer infrastructure.

Recent Investments, Acquisitions and Divestitures

Acquisitions

During the first quarter of 2016, we completed three acquisitions. The results of two of the acquired companies are generally included in our Electric Power Infrastructure Services segment. These companies included a full service medium- and high-voltage powerline contracting company located in the United States and a telecommunications company located in Canada. We also acquired a pipeline service contractor located in the United States, the results of which are generally included in our Oil and Gas Infrastructure Services segment. The aggregate consideration for these acquisitions consisted of approximately $42.2 million paid or payable in cash, subject to certain adjustments, and contingent consideration payments of up to $35 million, which will be paid if certain financial targets are achieved. Based on the estimated fair value of this contingent consideration, we have recorded a $15.4 million liability. As these transactions were effective during the first quarter of 2016, the results have been included in our consolidated financial statements beginning on the respective dates of acquisition. These acquisitions should enable us to further enhance our service offerings in the United States and Canada.

During 2015, we acquired 11 companies. The results of eight of the acquired companies are generally included in our Electric Power Infrastructure Services segment. These companies include a foundation services company located in the United States, an electrical contracting company located in the United States, an electrical engineering company located in Australia, a powerline construction company located in the United States, an engineering company located in Canada, an engineering, procurement and construction services company based in the United States, an underground construction contracting company located in Canada and a supplier and material procurement specialist for the power and utility industry in Canada. The results of the remaining three acquired companies are generally included in our Oil and Gas Infrastructure Services segment. These companies include a company that services above-ground storage tanks in the United States, an underground utility distribution contractor that provides services to gas and electric utilities in Canada, and a company that specializes in the engineering, procurement, construction, and commissioning of compression and surface facilities for the high pressure gas industry in Australia. The aggregate consideration for these acquisitions consisted of approximately $110.4 million paid or payable in cash, subject to net working capital adjustments, 461,037 shares of Quanta common stock valued on the settlement dates of the acquisitions at approximately $10.1 million, and $1.0 million in contingent consideration. As these transactions were effective during 2015, the results have been included in our consolidated financial statements beginning on the respective dates of acquisition. These acquisitions should enable us to further enhance our electric power and oil and gas infrastructure service offerings in the United States, Canada and Australia.

Disposition — Fiber Optic Licensing Operations

On April 29, 2015, we entered into a stock purchase agreement with Crown Castle International Corp. pursuant to which we agreed to sell our fiber optic licensing operations. The purchase agreement contained customary representations and warranties, covenants and indemnities. On August 4, 2015, we completed the sale for a purchase price of approximately $1 billion in cash, resulting in after-tax net proceeds of approximately $848 million. In the third quarter of 2015, we recognized a net of tax gain of approximately $171 million. We have presented the results of operations, financial position, cash flows and disclosures of the fiber optic licensing operations as discontinued operations for all periods in our unaudited condensed consolidated financial statements.

Backlog

Backlog is not a term recognized under United States generally accepted accounting principles (US GAAP); however, it is a common measurement used in our industry. Our methodology for determining backlog may not be comparable to the methodologies used by other companies.

Our backlog represents the amount of consolidated revenues that we expect to realize from future work under construction contracts, long-term maintenance contracts and master service agreements (MSAs). These estimates include revenues from the remaining portion of firm orders not yet completed and on which work has not yet begun, as well as revenues from change orders, renewal options, and funded and unfunded portions of government contracts to the extent that they are reasonably expected to occur. For purposes of calculating backlog, we include 100% of estimated revenues attributable to consolidated joint ventures and variable interest entities (VIEs). The following table presents our total backlog by reportable segment as of June 30, 2016 and December 31, 2015, along with an estimate of the backlog amounts expected to be realized within 12 months of each balance sheet date (in thousands):


	Backlog as of June 30, 2016				Backlog as of December 31, 2015
	12 Month		Total		12 Month		Total
Electric Power Infrastructure Services	$	3,270,243	$	6,347,190	$	3,307,837	$	6,312,947
Oil and Gas Infrastructure Services		2,437,586		3,408,477		1,900,845		3,073,950

Total	$	5,707,829	$	9,755,667	$	5,208,682	$	9,386,897

Revenue estimates included in our backlog can be subject to change as a result of project accelerations, cancellations or delays due to various factors, including but not limited to commercial issues, regulatory requirements and adverse weather. These factors can also cause revenue amounts to be realized in periods and at levels different than originally projected. Generally, our customers are not contractually committed to specific volumes of services under our MSAs, and most of our contracts may be terminated, typically upon 30 to 90 days’ notice, even if we are not in default under the contract. We determine the estimated amount of backlog for work under MSAs by using recurring historical trends inherent in current MSAs, factoring in seasonal demand and projected customer needs based upon ongoing communications with the customer. In addition, many of our MSAs are subject to renewal options. As of June 30, 2016 and December 31, 2015, MSAs accounted for approximately 41% and 45% of our estimated 12 month backlog and approximately 50% of total backlog. There can be no assurance as to our customers’ actual requirements or that our estimates are accurate.

Seasonality; Fluctuations of Results; Economic Conditions

Our revenues and results of operations can be subject to seasonal and other variations. These variations are influenced by weather, customer spending patterns, bidding seasons, receipt of required regulatory approvals, permits and rights of way, project timing and schedules, and holidays. Typically, our revenues are lowest in the first quarter of the year because cold, snowy or wet conditions can cause delays on projects. In addition, many of our customers develop their capital budgets for the coming year during the first quarter and do not begin infrastructure projects in a meaningful way until their capital budgets are finalized. Second quarter revenues are typically higher than those in the first quarter, as some projects begin, but continued cold and wet weather can often impact second quarter productivity. Third quarter revenues are typically the highest of the year, as a greater number of projects are underway, and weather is more accommodating. Generally, revenues during the fourth quarter of the year are lower than the third quarter but higher than the second quarter. Many projects are completed in the fourth quarter, and revenues are often impacted positively by customers seeking to spend their capital budgets before the end of the year; however, the holiday season and inclement weather can sometimes cause delays, reducing revenues and increasing costs. Any quarter may be positively or negatively affected by atypical weather patterns in any of the areas we serve, such as severe weather, excessive rainfall or warmer winter weather, making it difficult to predict these variations and their effect on particular projects quarter to quarter. The timing of project awards and unanticipated changes in project schedules as a result of delays or accelerations can also create variations in the level of operating activity from quarter to quarter.

These seasonal impacts are typical for our U.S. operations, but as our foreign operations continue to grow, we may see a lessening of this pattern impacting our quarterly revenues. For example, revenues in Canada are often higher in the first quarter as projects are accelerated so that work can be completed prior to the break up, or seasonal thaw, as productivity is adversely affected by wet ground conditions during the warmer spring and summer months. Also, although revenues from Australia and other international operations have not been significant relative to our overall revenues to date, their seasonal patterns may differ from those in North America and may impact our seasonality more in the future.

Additionally, our industry can be highly cyclical. Our volume of business may be adversely affected by declines or delays in new projects due to cyclicality, which may vary by geographic region, including the United States, Canada and Australia. Project schedules, particularly in connection with larger, longer-term projects, can also create fluctuations in the services provided, which may adversely affect us in a given period. For example, in connection with larger, more complicated projects, the timing of obtaining permits and other approvals may be delayed, and we may need to maintain a portion of our workforce and equipment in an underutilized capacity to ensure we are strategically positioned to deliver on such projects when they move forward. Examples of other items that may cause our results to fluctuate materially from quarter to quarter include: the financial condition of our customers and their access to capital; variations in the margins of projects performed during any particular period; regional, national and global economic and market conditions; the timing of acquisitions, the timing and magnitude of acquisition and integration costs associated with acquisitions; dispositions; fluctuations in our equity in earnings (losses) of unconsolidated affiliates; impairments of goodwill, intangible assets, long-lived

assets or investments; and interest rate fluctuations. Accordingly, our operating results in any particular period may not be indicative of the results that can be expected for any other period.

We and our customers continue to operate in a fluid business environment, with gradual improvement in the United States economy, yet continuing uncertainty in the marketplace overall. Significant decreases in oil and natural gas prices since mid-2014 have adversely impacted certain of our end markets. The decline in oil prices has negatively impacted the Canadian economy in particular due to the influence of the energy industry on the country’s economy, which in turn has adversely impacted both our electric power and oil and gas infrastructure services operations in Canada. However, we believe our Canadian operations have stabilized, and there are additional signs of recovery. These economic conditions have negatively affected our financial condition, results of operations and cash flows in the past and may continue to do so in the future. We are closely monitoring our customers and the effect that changes in economic and market conditions have or may have on them. Certain of our customers have reduced or delayed spending in recent years, which we attribute primarily to regulatory and permitting hurdles and negative economic and market conditions, and we anticipate that these issues may continue to affect demand for some of our services in the near term. As mentioned previously, there have been significant decreases in oil prices and natural gas prices since mid-2014. We have experienced a decrease in demand for some of our services, primarily infrastructure services in Australia, Canada and the Gulf of Mexico, as a result of low oil prices. Further declines in prices or continued low prices could result in further reduction of our customers’ capital spending on large pipeline and/or other midstream infrastructure, such as gathering systems and other related infrastructure, resulting in less demand for our services. We believe that most of our customers, many of whom are regulated utilities, remain financially stable in general and will be able to continue with their business plans in the long term. You should read Outlook and Understanding Margins for additional discussion of trends and challenges that may affect our financial condition, results of operations and cash flows.

Understanding Margins

Our gross margin is gross profit expressed as a percentage of revenues, and our operating margin is operating income expressed as a percentage of revenues. Cost of services, which is subtracted from revenues to obtain gross profit, consists primarily of salaries, wages and benefits to employees, depreciation, fuel and other equipment expenses, equipment rentals, subcontracted services, insurance, facilities expenses, materials and parts and supplies. Selling, general and administrative expenses and amortization of intangible assets are then subtracted from gross profit to obtain operating income. Various factors — some controllable, some not — can impact our margins on a quarterly or annual basis.

Seasonal and geographical. As discussed previously, seasonal patterns can have a significant impact on margins. Generally, business is slower in the winter months versus the warmer months of the year, resulting in lower productivity and consequently reducing our ability to cover fixed costs. This can be offset somewhat by increased demand for electrical service and repair work resulting from severe weather. Additionally, project schedules, including when projects begin and when they are completed, may impact margins. The mix of business conducted in the areas we serve will also affect margins, as some of the areas we serve offer the opportunity for higher margins than others due to the geographic characteristics associated with the physical location where the work is being performed. Such characteristics include whether the project is performed in an urban versus a rural setting or in a mountainous area or in open terrain. Site conditions, including unforeseen underground conditions, can also impact margins.

Weather. Adverse or favorable weather conditions can impact gross margins in a given period. For example, snowfall or rainfall in the areas in which we operate may negatively impact our revenues and margins due to reduced productivity, as projects may be delayed or temporarily placed on hold until weather conditions improve. Conversely, in periods when weather remains dry and temperatures are accommodating, more work can be done, sometimes with less cost, which would have a favorable impact on margins. In some cases, severe weather, such as hurricanes and ice storms, can provide us with higher margin emergency restoration service work, which generally has a positive impact on margins.

Revenue mix. The mix of revenues derived from the industries we serve and the types of services we provide within an industry will impact margins, as certain industries and services provide higher margin opportunities. Additionally, changes in our customers’ spending patterns in each of the industries we serve can cause an imbalance in supply and demand and, therefore, affect margins and mix of revenues by industry served.

Service and maintenance versus installation. Installation work is often performed on a fixed price basis, while maintenance work is often performed under pre-established or negotiated prices or cost-plus pricing arrangements. Margins for installation work may vary from project to project, and may be higher than maintenance work, as work obtained on a fixed price basis has higher risk than other types of pricing arrangements. We typically derive approximately 30% of our annual revenues from maintenance work, but a higher portion of installation work in any given period may affect our gross margins for that period.

Subcontract work. Work that is subcontracted to other service providers generally yields lower margins. An increase in subcontract work in a given period may contribute to a decrease in margins. We typically subcontract approximately 20% to 25% of our work to other service providers.

Materials versus labor. Typically, our customers are responsible for supplying their own materials on projects; however, for some of our contracts, we may agree to procure all or part of the required materials. Margins may be lower on projects where we furnish a significant amount of materials, as our mark-up on materials is generally lower than on our labor costs. In a given period, an increase in the percentage of work with higher materials procurement requirements may decrease our overall margins.

Size, scope and complexity of projects. We may experience a decrease or fluctuations in margins when larger, more complex electric transmission and pipeline projects across the industries we serve experience significant delays. Larger projects with higher voltage capacities, larger diameter throughput capacities, increased construction or design complexities, more difficult terrain requirements or longer distance requirements typically yield opportunities for higher margins as we assume a greater degree of performance risk and allow for a higher degree of utilization of our resources for longer construction time-frames. Conversely, smaller or less complex electric transmission and pipeline projects typically provide lower margin opportunities as there are a higher number of competitors that are capable of performing in this market and as competitors more aggressively pursue available volumes of work to absorb fixed costs. A greater mix of smaller scale or less complex electric transmission and pipeline work also could negatively impact margins due to the inefficiency of transitioning between a higher volume of smaller projects versus the continuous production on fewer larger projects. Our margins may be further impacted by delays in the timing of larger projects or temporary decreases in capital spending by our customers, as we may choose to maintain a portion of our workforce and equipment in an underutilized capacity to ensure we are strategically positioned to deliver on larger, more complicated electric transmission or pipeline projects when they move forward.

Depreciation. We include depreciation in cost of services. This is common practice in our industry, but it can make comparability of our margins to those of other companies difficult. This must be taken into consideration when comparing us to other companies.

Insurance. As discussed in Liquidity and Capital Resources — Self-Insurance, we are insured for employer’s liability, general liability, auto liability and workers’ compensation claims. We also have employee health care benefit plans for most employees not subject to collective bargaining agreements. Margins could be impacted by fluctuations in insurance accruals as additional claims arise and as circumstances and conditions of existing claims change.

Performance risk. Margins may fluctuate because of the volume of work and the impacts of pricing and job productivity, which can be affected both favorably and negatively by weather, geography, customer decisions and crew productivity. For example, when comparing a service contract between a current quarter and the comparable prior year’s quarter, factors affecting the gross margins associated with the revenues generated by the

contract may include pricing under the contract, the volume of work performed under the contract, the mix of the type of work specifically being performed and the productivity of the crews performing the work. Productivity can be influenced by many factors, including where the work is performed (e.g., rural versus urban area or mountainous or rocky area versus open terrain), whether the work is on an open or encumbered right of way, the impacts of inclement weather or the effects of environmental restrictions or regulatory delays. These types of factors are not practicable to quantify through accounting data, but each of these items may individually or in the aggregate have a direct impact on the gross margin of a specific project.

Foreign currency risk. Our financial performance is reported on a U.S. dollar-denominated basis and is subject to fluctuation in foreign currency exchange rates. Fluctuations in exchange rates relative to the U.S. dollar, primarily the Canadian and Australian dollars, could cause material fluctuations in comparisons of our results of operations between periods.

Selling, General and Administrative Expenses

Selling, general and administrative expenses consist primarily of compensation and related benefits to management, administrative salaries and benefits, marketing, office rent and utilities, communications, professional fees, bad debt expense, acquisition costs, gains and losses on the sale of property and equipment, letter of credit fees and maintenance, training and conversion costs related to the implementation of an information technology solution.

Results of Operations

As previously discussed, we have acquired certain businesses, the results of which have been included in the following results of operations beginning on their respective acquisition dates. Additionally, the results of operations for our fiber optic licensing operations, which were disposed of on August 4, 2015, have been reclassified from continuing operations to income from discontinued operations for all periods presented. The following table sets forth selected statements of operations data and such data as a percentage of revenues for the three and six month periods indicated (dollars in thousands):

Consolidated Results


	Three Months Ended June 30,										Six Months Ended June 30,
	2016					2015					2016					2015
Revenues	$	1,792,430		100.0	%	$	1,872,340		100.0	%	$	3,506,167		100.0	%	$	3,733,726		100.0	%
Cost of services (including depreciation)		1,592,213		88.8			1,644,835		87.8			3,102,637		88.5			3,268,315		87.5

Gross profit		200,217		11.2			227,505		12.2			403,530		11.5			465,411		12.5
Selling, general and administrative expenses		156,607		8.7			149,923		8.0			315,131		9.0			295,386		7.9
Amortization of intangible assets		8,141		0.5			8,731		0.5			15,636		0.4			17,024		0.5

Operating income		35,469		2.0			68,851		3.7			72,763		2.1			153,001		4.1
Interest expense		(3,583	)	(0.2	)		(1,675	)	(0.1	)		(7,172	)	(0.2	)		(3,075	)	(0.1	)
Interest income		641		—			319		—			1,157		—			772		—
Equity in losses of unconsolidated affiliates		(378	)	—			(314	)	—			(559	)	—			(314	)	—
Other income (expense), net		(725	)	—			(134	)	—			(463	)	—			(346	)	—

Income from continuing operations before income taxes		31,424		1.8			67,047		3.6			65,726		1.9			150,038		4.0
Provision for income taxes		14,695		0.9			31,584		1.7			28,138		0.8			62,185		1.6

Net income from continuing operations		16,729		0.9			35,463		1.9			37,588		1.1			87,853		2.4
Net income from discontinued operations		—		—			14,102		0.7			—		—			19,897		0.5

Net income		16,729		0.9			49,565		2.6			37,588		1.1			107,750		2.9
Less: Net income attributable to non-controlling interests		167		—			3,456		0.1			530		—			8,157		0.2

Net income attributable to common stock	$	16,562		0.9	%	$	46,109		2.5	%	$	37,058		1.1	%	$	99,593		2.7	%

Three months ended June 30, 2016 compared to the three months ended June 30, 2015

Revenues. Revenues decreased $79.9 million, or 4.3%, to $1.79 billion for the three months ended June 30, 2016. This decrease was primarily attributable to a decrease in electric power infrastructure services revenues resulting from reduced customer spending associated with larger electric transmission projects as customers in this industry continue to face heightened regulatory and environmental requirements from state and federal agencies and more stringent permitting processes with various regional system operators. This increased regulatory environment impacted the timing of existing projects and delayed the development of other necessary infrastructure projects, which had a corresponding negative impact on the level of demand for our services. Also contributing to the decrease were lower oil and gas infrastructure services revenues due to fluctuations in larger pipeline project timing and regulatory delays comparable to those in our Electric Power Infrastructure Services segment. To a lesser extent, oil and gas infrastructure services revenues were also negatively impacted by project delays due to forest fires in Alberta, Canada. In addition, revenues contributed by our international operations

were negatively impacted by approximately $14 million due to less favorable foreign currency translation rates as compared to the prior year period, calculated on a constant currency basis, primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. Partially offsetting these decreases for the three months ended June 30, 2016 was the favorable impact of approximately $40 million in revenues generated by acquired companies, primarily in the Electric Power Infrastructure Services segment.

Gross profit. Gross profit decreased $27.3 million, or 12.0%, to $200.2 million for the three months ended June 30, 2016. Gross profit as a percentage of revenues decreased to 11.2% for the three months ended June 30, 2016 from 12.2% for the three months ended June 30, 2015. The reduction in gross profit and gross profit as a percentage of revenues was primarily due to the previously mentioned decrease in revenues from larger pipeline projects and larger electric transmission projects, which typically yield higher margins. Gross profit from oil and gas infrastructure services was also negatively impacted by increased project costs associated with challenging site conditions and project completion efforts on certain pipeline projects that were ongoing during the second quarter of 2016. In addition, margins continued to be negatively impacted as competitors more aggressively pursued volumes of work to absorb fixed costs. Gross profit and gross profit as a percentage of revenues were also negatively impacted by additional project losses of $30.5 million related to a power plant construction project in Alaska during the three months ended June 30, 2016, which is discussed further in the results of operations for the Electric Power Infrastructure Services segment, compared to project losses of $25.1 million during the three months ended June 30, 2015 related to the same power plant construction project in Alaska and an electric transmission project in Canada completed in the third quarter of 2015.

Selling, general and administrative expenses. Selling, general and administrative expenses increased $6.7 million, or 4.5%, to $156.6 million for the three months ended June 30, 2016. This increase was primarily attributable to $2.8 million in higher costs associated with ongoing technology and business development initiatives and $2.2 million in incremental general and administrative costs associated with acquired companies. Selling, general and administrative expenses as a percentage of revenues increased to 8.7% for the three months ended June 30, 2016 from 8.0% for the three months ended June 30, 2015. This increase was due primarily to the impact of lower overall revenues for the three months ended June 30, 2016.

Amortization of intangible assets. Amortization of intangible assets decreased $0.6 million to $8.1 million for the three months ended June 30, 2016. This decrease was primarily due to reduced amortization expense from previously acquired intangible assets as certain of these assets became fully amortized, partially offset by increased amortization of intangible assets associated with acquired companies.

Interest expense. Interest expense increased $1.9 million to $3.6 million for the three months ended June 30, 2016 due to increased borrowing activity and a higher weighted average interest rate during the second quarter of 2016.

Provision for income taxes. The provision for income taxes was $14.7 million for the three months ended June 30, 2016, with an effective tax rate of 46.8%. The provision for income taxes was $31.6 million for the three months ended June 30, 2015, with an effective tax rate of 47.1%. The effective tax rate was primarily impacted by a lower proportion of income before taxes from international jurisdictions, which are generally taxed at lower statutory rates. Additionally, losses were incurred in jurisdictions where tax benefits are not anticipated to be realized. Also impacting the tax rate was a reduction in the annual expected tax benefits from foreign restructurings. The period ended June 30, 2015 included a $5.0 million negative impact of an increase in the Alberta provincial statutory income tax rate effective as of June 1, 2015, which required a remeasurement of certain cumulative deferred tax assets and liabilities.

Other comprehensive income. Other comprehensive income, net of taxes was a gain of $3.1 million in the three months ended June 30, 2016 compared to a gain of $14.9 million in the three months ended June 30, 2015. These gains were primarily due to favorable foreign currency exchange rates related to the weakening of the U.S. dollar against the Canadian dollar at June 30, 2016 as compared to March 31, 2016 and the weakening of the U.S. dollar against the Canadian and Australian dollars at June 30, 2015 as compared to March 31, 2015.

Six months ended June 30, 2016 compared to the six months ended June 30, 2015

Revenues. Revenues decreased $227.6 million, or 6.1%, to $3.51 billion for the six months ended June 30, 2016. This decrease was primarily attributable to a decrease in revenues from electric power infrastructure services revenues resulting from reduced customer spending associated with larger electric transmission projects as customers in this industry continue to face heightened regulatory and environmental requirements from state and federal agencies and more stringent permitting processes with various regional system operators. This increased regulatory environment impacted the timing of existing projects and delayed the development of other necessary infrastructure projects, which had a corresponding negative impact on the level of demand for our services. Also contributing to the decrease in revenues were lower oil and gas infrastructure services revenues due to fluctuations in larger project timing and regulatory delays comparable to those in our Electric Power Infrastructure Services segment. To a lesser extent, oil and gas infrastructure services revenues were negatively impacted by project delays due to forest fires in Alberta, Canada and reduced demand for services due to lower oil prices and their impact on customer spending. In addition, revenues contributed by our international operations were negatively impacted by approximately $46 million due to less favorable foreign currency translation rates as compared to the prior year period, primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. Partially offsetting these decreases for the six months ended June 30, 2016 was the favorable impact of approximately $70 million in revenues generated by acquired companies, primarily in the Electric Power Infrastructure Services segment.

Gross profit. Gross profit decreased $61.9 million, or 13.3%, to $403.5 million for the six months ended June 30, 2016. Gross profit as a percentage of revenues decreased to 11.5% for the six months ended June 30, 2016 from 12.5% for the six months ended June 30, 2015. The reduction in gross profit and gross profit as a percentage of revenues was primarily due to the previously mentioned decrease in revenues from larger pipeline projects and larger electric transmission projects, which typically yield higher margins. Gross profit from oil and gas infrastructure services was also negatively impacted by increased project costs associated with challenging site conditions and project completion efforts on certain pipeline projects that were ongoing during the second quarter of 2016. In addition, margins continued to be negatively impacted as competitors more aggressively pursued volumes of work to absorb fixed costs. Gross profit and gross profit as a percentage of revenues were also impacted by project losses of $51.8 million related to a power plant construction project in Alaska during the six months ended June 30, 2016, which is discussed further in the results of operations for the Electric Power Infrastructure Services segment, compared to project losses of $41.3 million during the six months ended June 30, 2015 related to the same power plant construction project in Alaska and an electric transmission project in Canada completed in the third quarter of 2015. These decreases were partially offset by improved performance from ongoing projects due to more favorable weather and increased productivity compared to the six months ended June 30, 2015.

Selling, general and administrative expenses. Selling, general and administrative expenses increased $19.7 million, or 6.7%, to $315.1 million for the six months ended June 30, 2016. This increase was primarily attributable to $6.3 million in severance costs associated with the departure of Quanta’s former president and chief executive officer and severance and restructuring costs primarily associated with certain operations within the Oil and Gas Infrastructure Services segment during the first quarter of 2016, $5.8 million in incremental general and administrative costs associated with acquired companies, and $4.9 million in higher costs associated with ongoing technology and business development initiatives. Selling, general and administrative expenses as a percentage of revenues increased to 9.0% for the three months ended June 30, 2016 from 7.9% for the six months ended June 30, 2015. This increase was primarily due to the severance and restructuring costs and the impact of lower overall revenues for the six months ended June 30, 2016.

Amortization of intangible assets. Amortization of intangible assets decreased $1.4 million to $15.6 million for the six months ended June 30, 2016. This decrease was primarily due to reduced amortization expense from previously acquired intangible assets as certain of these assets became fully amortized, partially offset by increased amortization of intangible assets associated with acquired companies.

Interest expense. Interest expense increased $4.1 million to $7.2 million for the six months ended June 30, 2016 primarily due to increased borrowing activity during the six months ended June 30, 2016.

Provision for income taxes. The provision for income taxes was $28.1 million for the six months ended June 30, 2016, with an effective tax rate of 42.8%. The provision for income taxes was $62.2 million for the six months ended June 30, 2015, with an effective tax rate of 41.4%. The higher effective tax rate for the six months ended June 30, 2016 was primarily due to a lower proportion of income before taxes from international operations, which are taxed at lower statutory rates. Additionally, losses were incurred in jurisdictions where tax benefits are not anticipated to be realized. Also impacting the tax rate was a reduction in the annual expected tax benefits from foreign restructurings. The period ended June 30, 2015 included a $5.0 million negative impact of an increase in the Alberta provincial statutory income tax rate, effective as of June 1, 2015, which required a remeasurement of certain cumulative deferred tax assets and liabilities.

Other comprehensive income. Other comprehensive income, net of taxes was a gain of $63.7 million in the six months ended June 30, 2016 compared to a loss of $74.0 million in the six months ended June 30, 2015. This was primarily due to favorable foreign currency exchange rates related to the weakening of the U.S. dollar against the Canadian dollar at June 30, 2016 as compared to December 31, 2015, whereas there were less favorable foreign currency exchange rates related to the strengthening of the U.S. dollar against the Canadian and Australian dollars at June 30, 2015 compared to December 31, 2014.

Segment Results

The following table sets forth segment revenues and segment operating income (loss) for the periods indicated (dollars in thousands):


	Three Months Ended June 30,										Six Months Ended June 30,
	2016					2015					2016					2015
Revenues:
Electric Power Infrastructure Services	$	1,159,087		64.7	%	$	1,222,324		65.3	%	$	2,346,089		66.9	%	$	2,462,616		66.0	%
Oil and Gas Infrastructure Services		633,343		35.3			650,016		34.7			1,160,078		33.1			1,271,110		34.0

Consolidated revenues from external customers	$	1,792,430		100.0	%	$	1,872,340		100.0	%	$	3,506,167		100.0	%	$	3,733,726		100.0	%

Operating income (loss):
Electric Power Infrastructure Services	$	75,934		6.6	%	$	88,027		7.2	%	$	163,258		7.0	%	$	197,019		8.0	%
Oil and Gas Infrastructure Services		11,899		1.9			35,981		5.5			17,740		1.5			60,128		4.7
Corporate and non-allocated costs		(52,364	)	N/A			(55,157	)	N/A			(108,235	)	N/A			(104,146	)	N/A

Consolidated operating income	$	35,469		2.0	%	$	68,851		3.7	%	$	72,763		2.1	%	$	153,001		4.1	%

Three months ended June 30, 2016 compared to the three months ended June 30, 2015

Electric Power Infrastructure Services Segment Results

Revenues for this segment decreased $63.2 million, or 5.2%, to $1.16 billion for the three months ended June 30, 2016. This decrease was primarily a result of reduced customer spending associated with larger electric transmission projects as customers in this industry continue to face heightened regulatory and environmental requirements from state and federal agencies and more stringent permitting processes with various regional

system operators. This increased regulatory environment impacted the timing of existing projects and delayed the development of other necessary infrastructure projects, which had a corresponding negative impact on the level of demand for our services. As a result, revenues during the second quarter of 2016 were negatively impacted compared to the second quarter of 2015, which included higher levels of revenues from larger transmission projects that were nearing completion and which were not ongoing during the second quarter of 2016. Revenues in the second quarter of 2016 also declined as a result of less favorable foreign currency exchange rates in the three months ended June 30, 2016, which negatively impacted our international operations by $8 million and were primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. Partially offsetting these decreases was the contribution of approximately $30 million in revenues from acquired companies.

Operating income decreased $12.1 million, or 13.7%, to $75.9 million for the three months ended June 30, 2016. Operating income as a percentage of segment revenues decreased to 6.6% for the three months ended June 30, 2016 from 7.2% for the three months ended June 30, 2015. These decreases were primarily due to the negative impact of lower revenues from large electric transmission projects, which typically yield higher margins, and a corresponding increase in lower margin revenues from smaller scale transmission work. This change in revenue mix also resulted in increased inefficiencies associated with transitioning between smaller projects that are not experienced during continuous production on larger projects and underutilization of certain large transmission resources during the three months ended June 30, 2016. In addition, margins continued to be negatively impacted as competitors more aggressively pursued volumes of work to absorb fixed costs. Operating income and operating income as a percentage of revenues were also negatively impacted by project losses of $30.5 million related to a power plant construction project in Alaska during the three months ended June 30, 2016 compared to project losses of $25.1 million during the three months ended June 30, 2015 related to the same power plant construction project in Alaska and an electric transmission project in Canada completed in the third quarter of 2015.

The project losses related to the Alaska power plant construction project recognized during the three months ended June 30, 2016 were primarily due to performance issues encountered on the project and a claimed force majeure event that disrupted the commissioning phase of the project near the end of the second quarter of 2016 that resulted in the revision of our estimate of the total costs necessary to complete this project. During the second quarter and as the project was planned to transition from final construction and testing to the commissioning phase, the project was negatively impacted by further third party engineering deficiencies that caused changes to the planned scope of work and by performance failures by other contractors operating onsite to adequately perform during the second quarter of 2016. These issues resulted in higher than expected production costs associated with quality deficiencies and a related impact on production sequencing. Late in the second quarter Quanta also experienced a claimed force majeure event which disrupted the project and Quanta provided the customer and its insurance providers with a notice of force majeure in order to seek schedule relief and cost recovery from the disruptions. Quanta is also in the process of developing potential claims for damages that may have resulted from the third party engineering and other contractor performance issues; however, no revenues or cost recovery has been reflected in Quanta’s estimate of total project losses at June 30, 2016. At June 30, 2016, this project had a contract value of $201 million and was approximately 90% complete. This project is expected to be substantially completed near the end of the third quarter of 2016. As this project continues through the final construction and commissioning phases, it is possible that additional performance issues or other unforeseen circumstances could occur and result in the recognition of additional losses on this project; however, such amounts cannot currently be estimated.

Oil and Gas Infrastructure Services Segment Results

Revenues for this segment decreased $16.7 million, or 2.6%, to $633.3 million for the three months ended June 30, 2016. This decrease was primarily a result of fluctuations in the timing of certain larger diameter pipeline projects due to regulatory and permitting delays, as customers in this industry continue to face heightened regulatory and environmental requirements that caused certain project start dates to shift into the second half of the year as a result of delays associated with state and federal permitting processes. To a lesser

extent, revenues were negatively impacted by project delays due to the forest fires in Alberta, Canada. The revenues contributed from our international operations were negatively impacted by approximately $6 million as a result of less favorable foreign currency exchange rates in the three months ended June 30, 2016 as compared to the three months ended June 30, 2015, primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. These decreases were partially offset by increased activity from distribution services, as well as the contribution of approximately $10 million of revenues from acquired companies.

Operating income decreased $24.1 million, or 66.9%, to $11.9 million for the three months ended June 30, 2016. Operating income as a percentage of segment revenues decreased to 1.9% for the three months ended June 30, 2016 from 5.5% for the three months ended June 30, 2015. These decreases were primarily due to the decrease in revenues from larger pipeline projects discussed above, which typically yield higher margins, and certain larger pipeline projects that were scheduled to begin in the second quarter of 2016 experienced delayed start dates into the second half of 2016 related to final permitting processes, which negatively impacted resource utilization. Also negatively impacting operating income and operating income as a percentage of revenues were higher costs associated with challenging site conditions on an ongoing transmission project in Canada and customer requests for additional project completion efforts on a U.S. transmission project that was substantially completed in 2015. While we intend to pursue potential claims for additional compensation that may be due from our customer for certain site challenges encountered during the second quarter of 2016, recovery on any such claims is not included in our estimate of total contract value at June 30, 2016.

Corporate and Non-allocated Costs

Certain selling, general and administrative expenses and amortization of intangible assets are not allocated to segments. Corporate and non-allocated costs for the quarter ended June 30, 2016 decreased $2.8 million to $52.4 million as compared to the quarter ended June 30, 2015 primarily due to a decrease in acquisition and integration costs associated with current lower levels of activity.

Six months ended June 30, 2016 compared to the six months ended June 30, 2015

Electric Power Infrastructure Services Segment Results

Revenues for this segment decreased $116.5 million, or 4.7%, to $2.35 billion for the six months ended June 30, 2016. This decrease was primarily a result of reduced customer spending associated with larger electric transmission projects as customers in this industry continue to face heightened regulatory and environmental requirements from state and federal agencies and more stringent permitting processes with various regional system operators. This increased regulatory environment impacted the timing of existing projects and delayed the development of other necessary infrastructure projects, which had a corresponding negative impact on the level of demand for our services. Revenues also declined as a result of less favorable foreign currency exchange rates in the six months ended June 30, 2016, which negatively impacted our international operations by approximately $26 million and were primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. Partially offsetting these decreases were the contributions of approximately $55 million in revenues from acquired companies and $10.2 million in higher emergency restoration services revenues.

Operating income decreased $33.8 million, or 17.1%, to $163.3 million for the six months ended June 30, 2016. Operating income as a percentage of segment revenues decreased to 7.0% for the six months ended June 30, 2016 from 8.0% for the six months ended June 30, 2015. These decreases were primarily due to the negative impact of lower revenues from large electric transmission projects, which typically yield higher margins, and a corresponding increase in lower margin revenues from smaller scale transmission work. This change in revenue mix also resulted in increased inefficiencies associated with transitioning between smaller projects that are not experienced during continuous production on larger projects and underutilization of certain large transmission resources during the six months ended June 30, 2016. In addition, margins continue to be negatively impacted as competitors more aggressively pursued volumes of work to absorb fixed costs. These

decreases were partially offset by improved performance from ongoing projects, as we experienced more favorable weather and increased productivity compared to the six months ended June 30, 2015. Operating income and operating income as a percentage of revenues were also negatively impacted by project losses of $51.8 million related to the power plant construction project in Alaska during the six months ended June 30, 2016 compared to project losses of $41.3 million during the six months ended June 30, 2015 related to the same power plant construction project in Alaska and an electric transmission project in Canada completed in the third quarter of 2015.

The project losses related to the Alaska power plant construction project recognized during the three months ended June 30, 2016 were primarily due to performance issues encountered on the project and a claimed force majeure event that disrupted the commissioning phase of the project near the end of the second quarter of 2016 that resulted in the revision of our estimate of the total costs necessary to complete this project. During the first six months of 2016 and as the project was planned to transition from final construction and testing to the commissioning phase, our productivity was negatively impacted by further third party engineering deficiencies that caused changes to the planned scope of work and by performance failures by other contractors operating onsite. These issues resulted in higher than expected production costs and a related impact on production sequencing. Late in the second quarter of 2016 Quanta also experienced a claimed force majeure event which disrupted the project and Quanta provided the customer and its insurance providers with a notice of force majeure in order to seek schedule relief and cost recovery from the disruptions. Quanta is also in the process of developing potential claims for damages that may have resulted from the third party engineering and other contractor performance issues; however, no revenues or cost recovery have been reflected in Quanta’s estimate of total project losses at June 30, 2016. At June 30, 2016, this project had a contract value of $201 million and was approximately 90% complete. This project is expected to be substantially completed near the end of the third quarter of 2016. As this project continues through the final construction and commissioning phases, it is possible that additional performance issues or other unforeseen circumstances could occur and result in the recognition of additional losses on this project; however, such amounts cannot currently be estimated.

Oil and Gas Infrastructure Services Segment Results

Revenues for this segment decreased $111.0 million, or 8.7%, to $1.16 billion for the six months ended June 30, 2016. This decrease was primarily a result of fluctuations in the timing of certain larger diameter pipeline projects due to regulatory and permitting delays, as customers in this industry continue to face heightened regulatory and environmental requirements that have caused certain project start dates to shift into the second half of the year as a result of delays associated with state and federal permitting processes. To a lesser extent, revenues were negatively impacted by project delays due to forest fires in Alberta, Canada and reduced demand for services due to lower oil prices and their impact on customer spending. The revenues contributed from our international operations were negatively impacted by approximately $20.0 million as a result of less favorable foreign currency exchange rates in the six months ended June 30, 2016 as compared to the six months ended June 30, 2015, primarily attributable to the strengthening of the U.S. dollar against the Canadian dollar. These decreases were partially offset by the increased activity from distribution services, as well as the contribution of approximately $15 million in revenues from acquired companies.

Operating income decreased $42.4 million, or 70.5%, to $17.7 million for the six months ended June 30, 2016. Operating income as a percentage of segment revenues decreased to 1.5% for the six months ended June 30, 2016 from 4.7% for the six months ended June 30, 2015. These decreases were primarily due to the previously mentioned decrease in revenues from larger pipeline projects discussed above, as these projects typically yield higher margins, and certain larger pipeline projects that were scheduled to begin in the second quarter of 2016 experienced delayed start dates into the second half of 2016 related to final permitting processes, which negatively impacted resource utilization. Operating income and operating income as a percentage of revenues were also negatively impacted by challenging site conditions associated with an ongoing transmission project in Canada and customer requests for additional project completion efforts on a transmission project in the U.S. that was substantially completed in 2015. While we intend to pursue potential claims for additional

compensation from our customer for certain site challenges encountered during the second quarter of 2016, recovery on any such claims is not included in our estimate of total contract value at June 30, 2016. Also contributing to the decrease in operating income and operating income as a percentage of revenues was the negative impact of approximately $2 million in severance and restructuring costs recognized during the three months ended March 31, 2016.

Corporate and Non-allocated Costs

Certain selling, general and administrative expenses and amortization of intangible assets are not allocated to segments. Corporate and non-allocated costs for the six months ended June 30, 2016 increased $4.1 million to $108.2 million as compared to the six months ended June 30, 2015. This increase was primarily due to $4.0 million in costs associated with the departure of Quanta’s former president and chief executive officer recognized during the three months ended March 31, 2016.

Liquidity and Capital Resources

Cash Requirements

Our cash and cash equivalents totaled $162.3 million and $128.8 million as of June 30, 2016 and December 31, 2015. As of June 30, 2016 and December 31, 2015, cash and cash equivalents held in domestic bank accounts were approximately $13.4 million and $16.1 million, and cash and cash equivalents held in foreign bank accounts were approximately $148.9 million and $112.7 million. As of June 30, 2016 and December 31, 2015, cash and cash equivalents held by our investments in joint ventures, which are either consolidated or proportionately consolidated, were approximately $17.8 million and $24.9 million, of which $13.4 million and $11.9 million related to domestic joint ventures. Cash and cash equivalents held by the joint ventures are available to support the operations of the related joint ventures, and we do not have access to that cash for our other operations. Under the terms of the partnership agreements, we generally have no right to the joint ventures’ cash other than participating in distributions and in the event of dissolution.

We were in compliance with the covenants under our credit agreement at June 30, 2016. We anticipate that our cash and cash equivalents on hand, existing borrowing capacity under our credit facility, and our future cash flows from operations will provide sufficient funds to enable us to meet our future operating needs and our planned capital expenditures, as well as facilitate our ability to grow in the foreseeable future.

Our industry is capital intensive, and we expect the need for substantial capital expenditures to continue into the foreseeable future to meet the anticipated demand for our services. Capital expenditures related to continuing operations are expected to total $200 million to $220 million for 2016, of which we have spent approximately $108.6 million through June 30, 2016.

We also evaluate opportunities for strategic acquisitions from time to time that may require cash, as well as opportunities to make investments in customer-sponsored projects where we anticipate performing services such as project management, engineering, procurement or construction services. These investment opportunities exist in the markets and industries we serve and may require the use of cash in the form of debt or equity investments.

Management continues to monitor the financial markets and general national and global economic conditions for factors that may affect our liquidity and capital resources. We consider our cash investment policies to be conservative in that we maintain a diverse portfolio of what we believe to be high-quality cash investments with short-term maturities. Accordingly, we do not anticipate that any weakness in the capital markets will have a material impact on the principal amounts of our cash investments or our ability to rely upon our credit facility for funds. To date, we have experienced no loss of or lack of access to our cash or cash equivalents or funds under our credit facility; however, we can provide no assurances that access to our invested cash and cash equivalents or availability under our credit facility will not be impacted in the future by adverse conditions in the financial markets.

If we were to repatriate cash that is indefinitely reinvested outside the United States, we could be subject to additional U.S. income and foreign withholding taxes. Because of the number and variability of assumptions required, it is not practicable to determine the amount of any additional U.S. tax liability that may result if we decide to no longer indefinitely reinvest foreign earnings outside the United States. If our intentions or U.S. tax laws change in the future, there may be a significant negative impact on the provision for income taxes and cash flows as a result of recording an incremental tax liability in the period such change occurs.

Sources and Uses of Cash

As of June 30, 2016, we had cash and cash equivalents of $162.3 million and working capital of $1.04 billion. We also had $317.3 million of outstanding letters of credit and bank guarantees, $217.6 million of which was denominated in U.S. dollars and $99.7 million of which was denominated in Australian or Canadian dollars. We also had $398.0 million of outstanding revolving loans under our credit facility, $300.0 million of which was denominated in U.S. dollars and $98.0 million of which was denominated in Canadian dollars. As of June 30, 2016, our $1.810 billion senior secured revolving credit facility, which matures on December 18, 2020, had $1.09 billion available for revolving loans or issuing new letters of credit or bank guarantees.

Operating Activities

Cash flow from operations is primarily influenced by demand for our services and operating margins but can also be influenced by working capital needs associated with the various types of services that we provide. In particular, working capital needs may increase when we commence large volumes of work under circumstances where project costs, primarily associated with labor, equipment and subcontractors, are required to be paid before the receivables resulting from the work performed are billed and collected. Accordingly, changes within working capital in accounts receivable, costs and estimated earnings in excess of billings on uncompleted contracts, and billings in excess of costs and estimated earnings on uncompleted contracts are normally related and are typically affected on a collective basis by changes in revenue due to both changes in timing and volume of work performed and variability in the timing of customer billings and payments. Additionally, working capital needs are generally higher during the summer and fall months due to increased demand for our services when favorable weather conditions exist in many of the regions in which we operate. Conversely, working capital assets are typically converted to cash during the winter months. These seasonal trends can be offset by changes in the timing of projects which can be impacted by project delays or accelerations and other economic factors that may affect customer spending.

Operating activities of continuing operations provided net cash of $66.5 million during the three months ended June 30, 2016 as compared to $106.1 million provided during the three months ended June 30, 2015. The decrease in cash flows from operating activities of continuing operations for the three months ended June 30, 2016 as compared to the three months ended June 30, 2015 was primarily due to less favorable operating results.

Operating activities of continuing operations provided net cash of $266.3 million during the six months ended June 30, 2016 as compared to $285.8 million provided during the six months ended June 30, 2015. The decrease in cash flows from operating activities of continuing operations for the six months ended June 30, 2016 as compared to the six months ended June 30, 2015 was primarily due to lower operating results in the current year period and the receipt of a cash payment in the amount of $65 million in the six months ended June 30, 2015 from settlement of an arbitration proceeding involving certain contract price adjustments. Also impacting cash flow from operations of continuing operations in the six months ended June 30, 2015 was a reduction in income tax payments as a result of the $102.5 million charge to selling, general and administrative expense in 2014 related to certain receivables and its impact on estimated tax payments.

Days sales outstanding (DSO) as of June 30, 2016 was 74 days, as compared to 85 days at June 30, 2015. This decrease was primarily due to favorable billing terms for certain large projects ongoing in 2016 as compared to projects ongoing in 2015. DSO is calculated by using the sum of current accounts receivable, net of allowance

(which includes retainage and unbilled balances), plus costs and estimated earnings in excess of billings on uncompleted contracts less billings in excess of costs and estimated earnings on uncompleted contracts, divided by average revenues per day during the quarter.

Investing Activities

During the three months ended June 30, 2016, investing activities of continuing operations used net cash of $58.3 million as compared to $91.8 million used in the three months ended June 30, 2015. Investing activities of continuing operations in the second quarter of 2016 included $60.9 million used for capital expenditures, partially offset by $5.2 million of proceeds from the sale of property and equipment. Investing activities of continuing operations in the second quarter of 2015 included $62.5 million used for capital expenditures and $37.9 million used in connection with acquisitions, partially offset by $7.7 million of proceeds from the sale of property and equipment.

During the six months ended June 30, 2016, investing activities of continuing operations used net cash of $142.3 million as compared to $184.0 million used in the six months ended June 30, 2015. Investing activities of continuing operations in the six months ended June 30, 2016 included $108.6 million used for capital expenditures and $39.7 million used in connection with acquisitions, partially offset by $10.3 million of proceeds from the sale of property and equipment. Investing activities of continuing operations in the six months ended June 30, 2015 included $121.0 million used for capital expenditures and $72.7 million used in connection with acquisitions, partially offset by $9.0 million of proceeds from the sale of property and equipment.

Our industry is capital intensive, and we expect the need for substantial capital expenditures to continue into the foreseeable future to meet the anticipated demand for our services. In addition, we expect to continue to pursue strategic acquisitions and investments, although we cannot predict the timing or magnitude of the potential cash outlays for these initiatives.

Financing Activities

During the three months ended June 30, 2016, net cash used in financing activities of continuing operations was $0.5 million as compared to net cash used of $83.2 million in the three months ended June 30, 2015. Financing activities of continuing operations in the three months ended June 30, 2015 included $172.3 million of common stock repurchases under our stock repurchase program, partially offset by $96.5 million of net borrowings under our credit facility.

During the six months ended June 30, 2016, net cash used in financing activities of continuing operations was $85.2 million as compared to net cash used of $225.4 million in the six months ended June 30, 2015. Financing activities of continuing operations in the six months ended June 30, 2016 included $75.3 million of net repayments under our credit facility. Financing activities of continuing operations in the six months ended June 30, 2015 included $354.3 million of common stock repurchases under our stock repurchase program, partially offset by $140.1 million of net borrowings under our credit facility.

Stock Repurchases

During the fourth quarter of 2013, our board of directors approved a stock repurchase program authorizing us to purchase from time to time through December 31, 2016, up to $500.0 million of our outstanding common stock (the 2013 Repurchase Program). During the nine months ended September 30, 2015, we repurchased 14.3 million shares of our common stock at a cost of $406.5 million in the open market under the 2013 Repurchase Program and completed the 2013 Repurchase Program.

During the third quarter of 2015, our board of directors approved a new stock repurchase program authorizing us to purchase, from time to time through February 28, 2017, up to $1.25 billion of our outstanding

common stock (the 2015 Repurchase Program). Repurchases under the 2015 Repurchase Program can be made in open market or privately negotiated transactions, including pursuant to an accelerated share repurchase arrangement, an issuer repurchase plan or otherwise, at our discretion, based on market and business conditions, applicable contractual and legal requirements and other factors. The 2015 Repurchase Program does not obligate us to acquire any specific amount of common stock and may be modified or terminated by our board of directors at any time at its sole discretion and without notice. During the third and fourth quarters of 2015, we repurchased 19.2 million shares of our common stock at a cost of $449.9 million in the open market under the 2015 Repurchase Program.

Also during the third quarter of 2015, we entered into an accelerated share repurchase arrangement (the ASR) to repurchase $750.0 million of our common stock under the 2015 Repurchase Program. Under the terms of the ASR, we paid $750.0 million to JPMorgan Chase Bank, National Association, London Branch (JPMorgan) and initially received 25.7 million shares of our common stock. The fair market value of these 25.7 million shares at the time of delivery was approximately $600.0 million, and the repurchased shares and the related cost to acquire them were accounted for as an adjustment to the balance of treasury stock during the quarter ended September 30, 2015, reducing the weighted-average number of basic and diluted common shares used to calculate our earnings per share. The $150.0 million remaining under the ASR was recorded as an adjustment to additional paid-in capital (APIC) during the quarter ended September 30, 2015 and was reclassified from APIC to treasury stock on April 12, 2016 as a result of the final settlement of the ASR. On April 12, 2016, upon final settlement of the ASR and based on the final volume-weighted average share price during the term of the ASR, minus a discount and subject to other adjustments pursuant to the terms and conditions of the ASR, we received 9.4 million additional shares of our common stock from JPMorgan.

As of June 30, 2016, we had repurchased 54.3 million shares of our common stock at a cost of $1.20 billion under the 2015 Repurchase Program, and approximately $50.1 million remained available under the 2015 Repurchase Program.

Debt Instruments

Credit Facility

On December 18, 2015, we entered into an amended and restated credit agreement with various lenders that provides for a $1.810 billion senior secured revolving credit facility maturing on December 18, 2020. The entire amount available under the facility may be used by us for revolving loans and letters of credit in U.S. dollars and certain alternative currencies. Up to $600.0 million of the facility may be used by certain of our subsidiaries for revolving loans and letters of credit in certain alternative currencies. Up to $100.0 million of the facility may be used for swing line loans in U.S. dollars, up to $50.0 million of the facility may be used for swing line loans in Canadian dollars and up to $30.0 million of the facility may be used for swing line loans in Australian dollars. In addition, subject to the conditions specified in the credit agreement, we have the option to increase the revolving commitments by up to $400.0 million from time to time upon receipt of additional commitments from new or existing lenders. Borrowings under the credit agreement are to be used to refinance existing indebtedness and for working capital, capital expenditures and other general corporate purposes.

As of June 30, 2016, we had approximately $317.3 million of outstanding letters of credit and bank guarantees, $217.6 million of which were denominated in U.S. dollars and $99.7 million of which were denominated in Australian and Canadian dollars. We also had $398.0 million of outstanding revolving loans under the credit facility, $300.0 million of which were denominated in U.S. dollars and $98.0 million of which were denominated in Canadian dollars. The remaining $1.09 billion was available for revolving loans or issuing new letters of credit or bank guarantees.

Under our current credit agreement, amounts borrowed in U.S. dollars bear interest, at our option, at a rate equal to either (i) the Eurocurrency Rate (as defined in the credit agreement) plus 1.125% to 2.125%, as

determined based on our Consolidated Leverage Ratio (as described below), or (ii) the Base Rate (as described below) plus 0.125% to 1.125%, as determined based on our Consolidated Leverage Ratio. Amounts borrowed as revolving loans under the credit agreement in any currency other than U.S. dollars bear interest at a rate equal to the Eurocurrency Rate plus 1.125% to 2.125%, as determined based on our Consolidated Leverage Ratio. Standby letters of credit issued under the credit agreement are subject to a letter of credit fee of 1.125% to 2.125%, based on our Consolidated Leverage Ratio, and Performance Letters of Credit (as defined in the credit agreement) issued under the credit agreement in support of certain contractual obligations are subject to a letter of credit fee of 0.675% to 1.275%, based on our Consolidated Leverage Ratio. We are also subject to a commitment fee of 0.20% to 0.40%, based on our Consolidated Leverage Ratio, on any unused availability under the credit agreement.

The Consolidated Leverage Ratio is the ratio of our Consolidated Funded Indebtedness to Consolidated EBITDA (as those terms are defined in the credit agreement). For purposes of calculating our Consolidated Leverage Ratio, Consolidated Funded Indebtedness is reduced by available cash and Cash Equivalents (as defined in the credit agreement) in excess of $25.0 million. The Base Rate equals the highest of (i) the Federal Funds Rate (as defined in the credit agreement) plus 0.5%, (ii) the prime rate publicly announced by Bank of America, N.A. and (iii) the Eurocurrency Rate plus 1.00%.

Subject to certain exceptions, the credit agreement is secured by substantially all of our assets and the assets of our wholly owned U.S. subsidiaries and by a pledge of all of the capital stock of our wholly owned U.S. subsidiaries and 65% of the capital stock of direct foreign subsidiaries of our wholly owned U.S. subsidiaries. Our wholly owned U.S. subsidiaries also guarantee the repayment of all amounts due under the credit agreement. Subject to certain conditions, all collateral will automatically be released from the liens at any time we maintain an Investment Grade Rating (defined in the credit agreement as two of the following three conditions being met: (i) a corporate credit rating that is BBB- or higher by Standard & Poor’s Rating Services, (ii) a corporate family rating that is Baa3 or higher by Moody’s Investors Services, Inc. or (iii) a corporate credit rating that is BBB- or higher by Fitch Ratings, Inc.).

The credit agreement contains certain covenants, including a maximum Consolidated Leverage Ratio and a minimum Consolidated Interest Coverage Ratio (as defined in the credit agreement). The credit agreement also limits certain acquisitions, mergers and consolidations, indebtedness, asset sales and prepayments of indebtedness and, subject to certain exceptions, prohibits liens on our assets. The credit agreement allows cash payments for dividends and stock repurchases subject to compliance with the following requirements (after giving effect to the dividend or stock repurchase): (i) no default or event of default under the credit agreement; (ii) continued compliance with the financial covenants in the credit agreement; and (iii) at least $100.0 million of availability under the credit agreement and/or cash and cash equivalents on hand. As of June 30, 2016, we were in compliance with all of the covenants in the credit agreement.

The credit agreement provides for customary events of default and contains cross-default provisions with our underwriting, continuing indemnity and security agreement with our sureties and all of our other debt instruments exceeding $100.0 million in borrowings or availability. If an Event of Default (as defined in the credit agreement) occurs and is continuing, on the terms and subject to the conditions set forth in the credit agreement, the lenders may declare all amounts outstanding and accrued and unpaid interest immediately due and payable, require that we provide cash collateral for all outstanding letter of credit obligations, terminate the commitments under the credit agreement, and foreclose on the collateral.

Off-Balance Sheet Transactions

As is common in our industry, we have entered into certain off-balance sheet arrangements in the ordinary course of business that result in risks not directly reflected in our balance sheets. Our significant off-balance sheet transactions include liabilities associated with non-cancelable operating leases, letter of credit obligations, commitments to purchase equipment, surety guarantees related to performance bonds, certain multiemployer

pension plan liabilities and obligations relating to our investments and joint venture arrangements. Certain joint venture structures involve risks not directly reflected in our balance sheets. For certain joint ventures, we have guaranteed all of the obligations of the joint venture under a contract with the customer. Additionally, other joint venture arrangements qualify as a general partnership, for which we are jointly and severally liable for all of the obligations of the joint venture. In our joint venture arrangements, typically each joint venturer indemnifies the other party for any liabilities incurred in excess of the liabilities such other party is obligated to bear under the respective joint venture agreement. Other than as discussed in this report, we have not engaged in any material off-balance sheet financing arrangements through special purpose entities, and we have no material guarantees of the work or obligations of third parties.

Leases

We enter into non-cancelable operating leases for many of our facility, vehicle and equipment needs. These leases allow us to conserve cash by paying a monthly lease rental fee for use of facilities, vehicles and equipment rather than purchasing them. We may decide to cancel or terminate a lease before the end of its term, in which case we are typically liable to the lessor for the remaining lease payments under the term of the lease.

We have guaranteed the residual value of the underlying assets under certain of our equipment operating leases at the date of termination of such leases. We have agreed to pay any difference between this residual value and the fair market value of each underlying asset as of the lease termination date. As of June 30, 2016, the maximum guaranteed residual value was approximately $538.7 million. We believe that no significant payments will be made as a result of the difference between the fair market value of the leased equipment and the guaranteed residual value. However, there can be no assurance that future significant payments will not be required.

Letters of Credit

Certain of our vendors require letters of credit to ensure reimbursement for amounts they are disbursing on our behalf, such as to beneficiaries under our self-funded insurance programs. In addition, from time to time, certain customers require us to post letters of credit to ensure payment to our subcontractors and vendors under those contracts and to guarantee performance under our contracts. Such letters of credit are generally issued by a bank or similar financial institution, typically pursuant to our credit agreement. Each letter of credit commits the issuer to pay specified amounts to the holder of the letter of credit if the holder claims that we have failed to perform specified actions. If this were to occur, we would be required to reimburse the issuer of the letter of credit. Depending on the circumstances of such a reimbursement, we may also be required to record a charge to earnings for the reimbursement. We do not believe that it is likely that any material claims will be made under a letter of credit in the foreseeable future.

As of June 30, 2016, we had $317.3 million in outstanding letters of credit and bank guarantees to secure our casualty insurance program and various contractual commitments. These are irrevocable stand-by letters of credit with maturities generally expiring at various times throughout 2016 and 2017. Upon maturity, it is expected that the majority of the letters of credit related to the casualty insurance program will be renewed for subsequent one-year periods.

Performance Bonds and Parent Guarantees

Many customers, particularly in connection with new construction, require us to post performance and payment bonds issued by a financial institution known as a surety. These bonds provide a guarantee to the customer that we will perform under the terms of a contract and that we will pay subcontractors and vendors. If we fail to perform under a contract or to pay subcontractors and vendors, the customer may demand that the surety make payments or provide services under the bond. We must reimburse the surety for any expenses or outlays it incurs. Under our underwriting, continuing indemnity and security agreement with our sureties and with the consent of the

lenders that are party to our credit agreement, we have granted security interests in certain of our assets to collateralize our obligations to the sureties. Subject to certain conditions and consistent with terms of our credit agreement, these security interests will be automatically released if we maintain a credit rating that meets two of the following three conditions: (i) a corporate credit rating that is BBB- or higher by Standard & Poor’s Rating Services, (ii) a corporate family rating that is Baa3 or higher by Moody’s Investors Services, Inc. or (iii) a corporate credit rating that is BBB- or higher by Fitch Ratings, Inc. We may be required to post letters of credit or other collateral in favor of the sureties or our customers in the future. Posting letters of credit in favor of the sureties or our customers would reduce the borrowing availability under our credit facility. To date, we have not been required to make any reimbursements to our sureties for bond-related costs. We believe that it is unlikely that we will have to fund significant claims under our surety arrangements in the foreseeable future. As of June 30, 2016, the total amount of outstanding performance bonds was estimated to be approximately $2.7 billion. Our estimated maximum exposure as it relates to the value of performance bonds outstanding is lowered on each bonded project as the cost to complete is reduced, and each of our commitments under the performance bonds generally extinguishes concurrently with the expiration of our related contractual obligation. The estimated cost to complete these bonded projects was approximately $667 million as of June 30, 2016.

Additionally, from time to time, we guarantee the obligations of our wholly owned subsidiaries, including obligations under certain contracts with customers, certain lease obligations, certain joint venture arrangements and, in some states, obligations in connection with obtaining contractors’ licenses. We are not aware of any material obligations for performance or payment asserted against us under any of these guarantees.

Contractual Obligations

As of June 30, 2016, our future contractual obligations were as follows (in thousands):


	Total		Remainder of 2016		2017		2018		2019		2020		Thereafter
Long-term debt - principal ⁽¹⁾	$	401,945	$	205	$	3,712	$	—	$	—	$	398,028	$	—
Long-term debt - cash interest ⁽²⁾		56		42		14		—		—		—		—
Operating lease obligations		270,793		55,908		78,221		56,538		34,412		19,433		26,281
Capital lease and related interest obligations ⁽³⁾		4,777		878		1,727		1,470		702		—		—
Equipment purchase commitments		3,595		3,595		—		—		—		—		—
Capital commitment related to investments in unconsolidated affiliates ⁽⁴⁾		65,438		7,728		33,199		—		24,511		—		—

Total	$	746,604	$	68,356	$	116,873	$	58,008	$	59,625	$	417,461	$	26,281

⁽¹⁾

Amounts were recorded in our June 30, 2016 condensed consolidated balance sheet and included $398.0 million of outstanding revolving loans under our credit facility, which bear interest at variable market rates. Assuming the principal amount outstanding at June 30, 2016 remained outstanding and the interest rate in effect at June 30, 2016 remained the same, the annual cash interest expense with respect to the credit facility would be approximately $8.0 million, payable for the remainder of the term of the facility, which matures in December 2020.

⁽²⁾	Amounts relate to cash interest expense on our fixed-rate long-term debt, which excludes the credit facility.

⁽³⁾	Principal amounts of lease obligations were recorded in our June 30, 2016 condensed consolidated balance sheet.

⁽⁴⁾

A return of capital from unconsolidated affiliates of approximately $43.8 million is anticipated in August 2017 and is not included in these amounts. As of June 30, 2016, we had made aggregate contributions to this unconsolidated affiliate of $8.4 million and had received $2.3 million as a return of capital.

Equipment Purchase Commitments

We have committed capital for the expansion of our vehicle fleet in order to accommodate manufacturer lead times on certain types of vehicles. As of June 30, 2016, production orders for approximately $3.6 million had been issued with delivery dates scheduled to occur throughout the remainder of 2016. Although we have committed to the purchase of these vehicles at the time of their delivery, we intend that these orders will be assigned to third party leasing companies and made available to us under certain of our master equipment lease agreements, which will release us from our capital commitment.

Unrecognized Tax Benefits

We are currently under examination by the Internal Revenue Service for tax years 2010, 2011 and 2012. Additionally, certain of our subsidiaries are under examination by various U.S. state, Canadian and other foreign tax authorities for multiple periods, and the amount of unrecognized tax benefits could therefore increase or decrease as a result of the expiration of certain statute of limitations periods or settlements of these examinations. We believe it is reasonably possible that within the next 12 months unrecognized tax benefits may decrease by up to $25.9 million due to the expiration of certain statute of limitations periods or settlements of the examinations.

Multiemployer Pension Plans

The previously presented table of estimated contractual obligations does not reflect the obligations under the multiemployer pension plans in which our union employees participate. Some of our operating units are parties to various collective bargaining agreements that require us to provide to the employees subject to these agreements specified wages and benefits, as well as to make contributions to multiemployer pension plans. Our multiemployer pension plan contribution rates generally are specified in the collective bargaining agreements (usually on an annual basis), and contributions are made to the plans on a “pay-as-you-go” basis based on our union employee payrolls. The location and number of union employees that we employ at any given time and the plans in which they may participate vary depending on the projects we have ongoing at any time and the need for union resources in connection with those projects. Therefore, we are unable to accurately predict our union employee payroll and the amount of the resulting multiemployer pension plan contribution obligations for future periods.

We may also be required to make additional contributions to our multiemployer pension plans if they become underfunded, and these additional contributions will be determined based on our union employee payrolls. The Pension Protection Act of 2006 added special funding and operational rules generally applicable to plan years beginning after 2007 for multiemployer plans that are classified as “endangered,” “seriously endangered” or “critical” status. Plans in these classifications must adopt measures to improve their funded status through a funding improvement or rehabilitation plan, as applicable, which may require additional contributions from employers (which may take the form of a surcharge on benefit contributions) and/or modifications to retiree benefits. A number of multiemployer plans to which our operating units contribute or may contribute in the future are in “endangered,” “seriously endangered” or “critical” status. The amount of additional funds, if any, that we may be obligated to contribute to these plans in the future cannot be reasonably estimated and are not included in the above table due to uncertainty of the future levels of work that require the specific use of the union employees covered by these plans, as well as the future contribution levels and possible surcharges on contributions applicable to these plans.

We may also have additional liabilities imposed by law as a result of our participation in multiemployer defined benefit pension plans. The Employee Retirement Income Security Act of 1974, as amended by the Multiemployer Pension Plan Amendments Act of 1980, imposes certain liabilities upon employers who are contributors to a multiemployer plan if the employer withdraws from the plan or the plan is terminated or experiences a mass withdrawal. These liabilities include an allocable share of the unfunded vested benefits in the plan for all plan participants, not merely the benefits payable to a contributing employer’s own retirees. Other

than as noted below, we are not aware of any material amounts of withdrawal liability that have been or are expected to be incurred as a result of a withdrawal by any of our operating units from any multiemployer defined benefit pension plans.

2011 Central States Plan Withdrawal Liability. In the fourth quarter of 2011, certain of our subsidiaries withdrew from the Central States, Southeast and Southwest Areas Pension Plan (Central States Plan). This withdrawal event was the result of an amendment to a collective bargaining agreement with the International Brotherhood of Teamsters (Teamsters) that eliminated certain employers’ obligations to contribute to the Central States Plan, which was then in critical status and significantly underfunded as to its vested benefit obligations. The amendment was negotiated by the Pipe Line Contractors Association (PLCA) on behalf of its members, which include certain of our subsidiaries. Because certain of our other subsidiaries continued participation in the Central States Plan into 2012, the subsidiaries’ withdrawals in 2011 effected only a partial withdrawal on our behalf in 2011. We believed that the partial withdrawal was advantageous because it limited exposure to increased liability resulting from a future withdrawal event, at which point the Central States Plan could have been further underfunded. We and other PLCA members now contribute to a different multiemployer pension plan on behalf of the affected Teamsters employees. While certain of our subsidiaries continued participation in the Central States Plan into 2012, we believe that such subsidiaries withdrew from the Central States Plan in 2012, thereby effecting a complete withdrawal as of December 30, 2012 for all Quanta subsidiaries.

In connection with the partial withdrawal in 2011, we recorded a withdrawal liability of approximately $32.6 million in the fourth quarter of 2011 based on estimates received from the Central States Plan. The Central States Plan subsequently asserted that the withdrawal of the PLCA members, and thus our partial withdrawal, was not effective in 2011. The PLCA and Quanta believed at that time that a legally effective withdrawal had occurred during the fourth quarter of 2011, and this issue was litigated in the federal district court for the Northern District of Illinois, Eastern Division. In September 2013, the district court ruled in favor of the Central States Plan, and that decision was appealed by the PLCA. In July 2014, the Central States Plan provided us with a Notice and Demand claiming partial withdrawal liability in the amount of $39.6 million and requiring Quanta to make payments on this assessment while the dispute is ongoing. In September 2015, the United States Court of Appeals for the Seventh Circuit ruled in favor of the PLCA and reversed the district court’s previous ruling, which had been in favor of the Central States Plan. Based on the outcome of the appeal, in January 2016, the Central States Plan issued a revised Notice and Demand claiming partial withdrawal liability in the amount of $32.9 million.

Separately, in December 2013, the Central States Plan filed lawsuits against two of our subsidiaries in connection with their withdrawal in 2012. In the first lawsuit, the Central States Plan alleged that the subsidiary elected to participate in the Central States Plan pursuant to the collective bargaining agreement under which it participated. We argued that no such election was made and that any payments made to the Central States Plan were made in error. In July 2014, the parties reached an agreement to settle the lawsuit, and the court dismissed the case with prejudice. In the second lawsuit, the Central States Plan alleged that contributions made by our subsidiary to a new industry fund created after we withdrew from the Central States Plan should have been made to the Central States Plan. This arguably would have extended our withdrawal date for this subsidiary to at least the end of 2013. We disputed these allegations on the basis that we properly paid contributions to the new industry fund based on the terms of the collective bargaining agreement under which we participated and asserted that we terminated our obligation to contribute to the Central States Plan by the end of 2012. The parties both moved for summary judgment, and in March 2015, the court entered judgment in our favor. The Central States Plan filed a notice of appeal in April 2015, and in December 2015, the Central States Plan agreed to dismiss the appeal with prejudice.

The ultimate liability associated with the complete withdrawal of our subsidiaries from the Central States Plan will depend on various factors, including interpretations of the terms of the collective bargaining agreements under which the subsidiaries participated and whether exemptions from withdrawal liability applicable to construction industry employers will be available. In March 2014, the Central States Plan provided revised estimates indicating that the total withdrawal liability based on certain withdrawal scenarios from 2011 through

2014 could range between $40.1 million and $55.4 million, which we believe to be the range of reasonably possible loss for this matter. Additionally, based on those estimates and allowing for the exclusion of amounts believed by management to have been improperly included in such estimates, we recorded an adjustment to cost of services during the three months ended March 31, 2014 to increase the recognized withdrawal liability to an amount within the range communicated to us by the Central States Plan. Given the unknown nature of some of the factors mentioned above, the final withdrawal liability cannot yet be determined with certainty. Accordingly, it is reasonably possible that the amount owed upon final resolution of these matters could be materially higher than the expense we recognized through June 30, 2016. Although we dispute the total liability owed to the Central States Plan, we continue to make monthly payments according to the terms of the January 2016 Notice and Demand while the parties determine the final withdrawal liability. As of June 30, 2016, we had made payments totaling $13.7 million toward the withdrawal liability assessment.

2013 Central States Plan Withdrawal Liability. On October 9, 2013, we acquired a company that experienced a complete withdrawal from the Central States Plan prior to the date of acquisition. Prior to the acquisition, the Central States Plan issued a Notice and Demand to the acquired company claiming a withdrawal liability in the total amount of $6.9 million and requiring payments to be made on this assessment while the dispute is ongoing. In connection with the acquisition, we recorded an initial liability of $4.8 million related to this withdrawal liability, and approximately $2.1 million of the purchase price for the acquired company was deposited into an escrow account to fund any withdrawal obligation in excess of the initial liability recorded. In January 2016, the Central States Plan issued a revised Notice and Demand claiming withdrawal liability in the amount of $4.8 million. Although we continue to dispute the total liability owed to the Central States Plan, we continue to make monthly payments according to the terms of this revised Notice and Demand while the parties determine the final withdrawal liability. As of June 30, 2016, payments totaling $3.1 million had been made toward the withdrawal liability assessment.

The final amount of withdrawal liability payable in connection with this matter remains the subject of a pending arbitration proceeding and will ultimately depend on various factors, including the outcome of the PLCA litigation described above. However, the acquired company’s withdrawal from the Central States Plan is not expected to have a material impact on our financial condition, results of operations or cash flows.

Letters of Credit Fees and Commitment Fees

Also excluded from the Contractual Obligations table is interest associated with letters of credit fees and commitment fees under our credit facility because the outstanding letters of credit, availability and applicable interest rates and fees are variable. For additional information regarding the interest rates and fees associated with borrowings under our credit facility, see Liquidity and Capital Resources — Debt Instruments — Credit Facility above.

Joint Venture Capital Commitments

We have also excluded from the Contractual Obligations table additional capital commitments associated with investments in unconsolidated affiliates related to planned oil and gas infrastructure projects of approximately $4.1 million because we are unable to determine the exact timing of these capital commitments but anticipate them to be paid by June 30, 2017. As specific amounts of capital commitments and their timing are determined, we will reflect such amounts in the Contractual Obligations table.

Self-Insurance

We are insured for employer’s liability, general liability, auto liability and workers’ compensation claims. Under these programs, the deductibles for general liability and auto liability are $10.0 million per occurrence, the deductible for workers’ compensation is $5.0 million per occurrence, and the deductible for employer’s liability is $1.0 million per occurrence. We are generally self-insured for all claims that do not exceed the amount of the

applicable deductible. In connection with our casualty insurance programs, we are required to issue letters of credit to secure our self-insured obligations. We also have employee health care benefit plans for most employees not subject to collective bargaining agreements, of which the primary plan is subject to a deductible of $400,000 per claimant per year.

Losses under all of these insurance programs are accrued based upon our estimate of the ultimate liability for claims reported and an estimate of claims incurred but not reported, with assistance from third-party actuaries. These insurance liabilities are difficult to assess and estimate due to unknown factors, including the severity of an injury, the extent of damage, the determination of our liability in proportion to other parties and the number of incidents not reported. The accruals are based upon known facts and historical trends, and management believes such accruals are adequate. As of June 30, 2016 and December 31, 2015, the gross amount accrued for insurance claims totaled $212.9 million and $209.0 million with $158.2 million and $153.5 million considered to be long-term and included in other non-current liabilities. Related insurance recoveries/receivables as of June 30, 2016 and December 31, 2015 were $9.2 million and $8.6 million of which $0.6 million and $0.6 million were included in prepaid expenses and other current assets and $8.6 million and $8.0 million were included in other assets, net.

We renew our insurance policies on an annual basis, and therefore deductibles and levels of insurance coverage may change in future periods. In addition, insurers may cancel our coverage or determine to exclude certain items from coverage, or we may elect not to obtain certain types or incremental levels of insurance if we believe that the cost to obtain such coverage exceeds the additional benefits obtained. In any such event, our overall risk exposure would increase, which could negatively affect our results of operations, financial condition and cash flows. The Contractual Obligations table excludes commitments associated with our insurance liabilities, as we are unable to determine the timing of payments related to these obligations.

Concentrations of Credit Risk

We are subject to concentrations of credit risk related primarily to our cash and cash equivalents and our accounts receivable, including amounts related to unbilled accounts receivable and costs and estimated earnings in excess of billings on uncompleted contracts. Substantially all of our cash investments are managed by what we believe to be high credit quality financial institutions. In accordance with our investment policies, these institutions are authorized to invest this cash in a diversified portfolio of what we believe to be high quality investments, which primarily include interest-bearing demand deposits, money market investments, money market mutual funds and investment grade commercial paper with original maturities of three months or less. Although we do not currently believe the principal amount of these investments is subject to any material risk of loss, changes in economic conditions could impact the interest income we receive from these investments. In addition, we grant credit under normal payment terms, generally without collateral, to our customers, which include electric power and oil and gas companies, governmental entities, general contractors, and builders, owners and managers of commercial and industrial properties located primarily in the United States, Canada and Australia. Consequently, we are subject to potential credit risk related to changes in business and economic factors throughout the United States, Canada and Australia, which may be heightened as a result of uncertain economic and financial market conditions that have existed in recent years. However, we generally have certain statutory lien rights with respect to services provided. Historically, some of our customers have experienced significant financial difficulties, and others may experience financial difficulties in the future. These difficulties expose us to increased risk related to collectability of billed and unbilled receivables and costs and estimated earnings in excess of billings on uncompleted contracts for services we have performed.

At June 30, 2016 and December 31, 2015, one customer accounted for approximately 18% and 12% of our consolidated net position. The services provided to this customer related primarily to our Electric Power Infrastructure Services segment. No customers represented 10% or more of our revenues for the three and six months ended June 30, 2016 and 2015, and no other customers represented 10% or more of our consolidated net position as of June 30, 2016 or December 31, 2015.

Legal Proceedings

We are from time to time party to various lawsuits, claims and other legal proceedings that arise in the ordinary course of business. These actions typically seek, among other things, compensation for alleged personal injury, breach of contract and/or property damages, employment-related damages, punitive damages, civil penalties or other losses, or injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, we record a reserve when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. In addition, we disclose matters for which management believes a material loss is at least reasonably possible. See Legal Proceedings and Collective Bargaining Agreements in Note 11 of the Notes to Condensed Consolidated Financial Statements in Item 1. Financial Statements of Part I of this Quarterly Report for additional information regarding litigation, claims and other legal proceedings.

Related Party Transactions

In the normal course of business, we enter into transactions from time to time with related parties. Our significant related party transactions typically take the form of facility leases with prior owners of certain acquired companies.

New Accounting Pronouncements

Adoption of New Accounting Pronouncements

In February 2015, the FASB issued an update which amends existing consolidation guidance, including amending the guidance related to determining whether an entity is a variable interest entity. The guidance may be applied using a modified retrospective approach whereby the entity records a cumulative effect of adoption at the beginning of the fiscal year of initial application. A reporting entity may also apply the amendments on a full retrospective basis. We adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on our consolidated financial statements or related disclosures.

In April 2015, the FASB issued an update that requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with the presentation of debt discounts and premiums. The update is required to be adopted retroactively for all periods presented. In August 2015, the FASB issued another update that states that the Securities Exchange Commission (SEC) staff would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. We adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on our consolidated financial statements or related disclosures.

In April 2015, the FASB issued an update that provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, then the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. An entity can elect to adopt the amendments either prospectively to all arrangements entered into or materially modified after the effective date or retrospectively. We adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on our consolidated financial statements or related disclosures.

disclose in the notes the amount recorded in current-period earnings that would have been recorded in previous reporting periods if the adjustment had been recognized as of the acquisition date. The update is required to be adopted prospectively to adjustments that occur after the effective date with earlier application permitted for financial statements that have not yet been issued. We adopted this guidance effective January 1, 2016, and the adoption of the update did not have a significant impact on our consolidated financial statements or related disclosures.

Accounting Standards Not Yet Adopted

In May 2014, the FASB issued an update that supersedes most current revenue recognition guidance as well as some cost recognition guidance. The update requires that an entity recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This update also requires new qualitative and quantitative disclosures about the nature, amount, timing and uncertainty of revenues and cash flows arising from customer contracts, including significant judgments and changes in judgments, information about contract balances and performance obligations, and assets recognized from costs incurred to obtain or fulfill a contract. In July 2015, the FASB affirmed its proposal to defer the effective date until fiscal years beginning on or after December 15, 2017. The guidance can be applied on a full retrospective or modified retrospective basis whereby the entity records a cumulative effect of initially applying this update at the date of initial application. We are currently evaluating the potential impact of this authoritative guidance on our consolidated financial statements and will adopt this guidance effective January 1, 2018.

In August 2014, the FASB issued guidance to address the diversity in practice in determining when there is substantial doubt about an entity’s ability to continue as a going concern and when and how an entity must disclose certain relevant conditions and events. This update requires an entity to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern for a period of one year after the date that the financial statements are issued (or available to be issued). If such conditions or events exist, an entity should disclose that there is substantial doubt about the entity’s ability to continue as a going concern for a period of one year after the date that the financial statements are issued (or available to be issued), along with the principal conditions or events that raise substantial doubt, management’s evaluation of the significance of those conditions or events in relation to the entity’s ability to meet its obligations and management’s plans that are intended to mitigate those conditions or events. The guidance is effective for annual and interim periods ending after December 15, 2016. This guidance will impact the disclosure and presentation of any substantial doubt about our ability to continue as a going concern, if such substantial doubt were to exist. We will adopt this guidance by December 31, 2016.

In July 2015, the FASB issued an update that requires inventory to be measured at the lower of either cost or net realizable value. When evidence exists that the net realizable value of inventory is lower than its cost, the difference will be recognized as a loss in earnings in the period in which it occurs. The update is required to be adopted prospectively and is effective for interim and annual reporting periods beginning after December 15, 2016, although early adoption is permitted. We are currently evaluating the potential impact of this authoritative guidance on our consolidated financial statements and will adopt this guidance by January 1, 2017.

In January 2016, the FASB issued an update that addresses certain aspects of recognition, measurement, presentation, and disclosure of financial instruments. The new standard is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for financial statements of fiscal years or interim periods that have not been previously issued. We are evaluating the impact of the new standard on our consolidated financial statements and will adopt the new standard by January 1, 2018.

financial statements of fiscal years or interim periods that have not been previously issued. We are evaluating the impact of the new standard on our consolidated financial statements and will adopt the new standard by January 1, 2019.

In March 2016, the FASB issued an update that requires companies with share-based payments to record all of the tax effects related to such share-based payments at settlement (or expiration) through the income statement rather than through equity. It is anticipated that companies will experience increased volatility of income tax expense upon adoption of this update. This change is required to be applied prospectively to all excess tax benefits and tax deficiencies resulting from settlements after the date of the adoption of the update and is effective for interim and annual reporting periods beginning after December 15, 2016, although early adoption is permitted. We are currently evaluating the potential impact of this authoritative guidance on our consolidated financial statements and will adopt this guidance by January 1, 2017.

In June 2016, the FASB issued an update that will change the way companies measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The update will require companies to use an “expected loss” model for instruments measured at amortized cost and to record allowances for available-for-sale (AFS) debt securities rather than reduce the carrying amounts. The update will also require disclosure of information regarding how a company developed its allowance, including changes in the factors that influenced management’s estimate of expected credit losses and the reasons for those changes. Companies will apply this standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The new standard is effective for interim and annual reporting periods beginning after December 15, 2019, although early adoption is permitted for annual reporting periods beginning after December 15, 2018. We are currently evaluating the potential impact of this authoritative guidance on our consolidated financial statements and will adopt this guidance by January 1, 2020.

Outlook

We believe there are growth opportunities across all the industries we serve. However, we and our customers continue to operate in a fluid business environment, with gradual improvement in the United States economy yet continuing uncertainty in the marketplace overall. Significant decreases in oil and natural gas prices since mid-2014 have adversely impacted certain of our end markets. The decline in oil prices has negatively impacted the Canadian economy in particular due to the influence of the energy industry on the country’s economy, which in turn has adversely impacted both our electric power and oil and gas infrastructure services operations in Canada. However, we believe our Canadian operations have stabilized and there are signs of recovery. Our customers also face stringent regulatory and environmental requirements as they develop projects to enhance and expand their infrastructure. In addition, regulatory delays have impacted our business, particularly for larger electric transmission and pipeline projects. These economic, regulatory and other factors have negatively affected our financial condition, results of operations and cash flows in the past and may continue to do so in the future. We believe that our financial and operational strengths will enable us to manage these challenges and uncertainties, and we remain optimistic about our near-term and long-term opportunities.

Electric Power Infrastructure Services Segment

The North American electric grid is aging and requires significant upgrades, maintenance and expansion to meet current and future demands for reliable power delivery. Over the past several years, many utilities across North America have begun to implement plans to improve their transmission systems in order to improve reliability and reduce congestion. Among other things, these activities include new construction, structure change-outs, line upgrades and maintenance projects on many transmission systems. In addition, state renewable portfolio standards, which set required or voluntary standards for how much power is to be generated from renewable energy sources, can result in the need for additional transmission lines and substations to transport the power from these facilities, which are often in remote locations, to demand centers. Other factors, such as the

reliability standards issued by the North American Electric Reliability Corporation and other regulatory actions, are also driving transmission system upgrades and expansions. We believe these factors create significant opportunities for our transmission infrastructure services.

Demand for electricity in North America is expected to grow over the long term. North America’s electric power grid was not designed or constructed to serve today’s power needs and is not adequate to efficiently serve the power needs of the future. The electric power grid is aging, continues to deteriorate and lacks redundancy. The increasing demand for electricity, coupled with the aging infrastructure, has affected and will continue to affect reliability, requiring utilities to upgrade and expand their existing transmission and distribution systems. Current federal legislation also requires the power industry to meet federal reliability standards for its transmission and distribution systems. We expect these system upgrades will result in increased spending and increased demand for our services over the long term.

As demand for power grows, the need for new power generation facilities is expected to grow as well. The development of new traditional power generation facilities, as well as renewable energy sources such as solar, wind and certain types of natural gas generation facilities, requires new or expanded transmission infrastructure to transport power to demand centers. Renewable energy in particular often requires significant transmission infrastructure due to the remote location of renewable sources of energy. As a result, we anticipate that future development of new power generation will lead to increased demand over the long term for our electric transmission design and construction services as well as our substation engineering and installation services.

The significant improvement in access to natural gas resources from unconventional shale formations in the United States and Canada, driven by technological advancements, has dramatically increased the near- and long-term supply of natural gas in North America. This increase in supply has also resulted in low natural gas prices for the past several years and the anticipation that natural gas prices will remain at lower levels going forward. As a result, it is anticipated that the amount of electricity generated by natural gas powered plants will increase and the majority of new fossil fuel generation facilities built in North America for the foreseeable future will be fueled by natural gas. Further, the Environmental Protection Agency has implemented certain emissions regulations that are resulting in the development of natural gas generation facilities to replace coal generation plants that are being retired in order to comply with the new regulations. These dynamics are anticipated to result in the need for new transmission and substation infrastructure to be built in North America to interconnect new natural gas fired generation facilities. It is also anticipated that modifications to and reengineering of existing transmission and substation infrastructure will be required when existing coal generation facilities are retired or shut down.

We consider renewable energy, including solar, wind and certain types of natural gas generation facilities, to be an ongoing opportunity for our engineering, project management and installation services. Concerns about greenhouse gas emissions, as well as the goal of reducing reliance on power generation from fossil fuels, are creating the need for more renewable energy sources. Renewable portfolio standards, which mandate that renewable energy constitute a specified percentage of a utility’s power generation by a specified date, exist in many states. We believe that our comprehensive services, industry knowledge and experience in the design, installation and maintenance of renewable energy facilities will enable us to support our customers’ renewable energy efforts. Further, we have the financial strength to selectively provide financing solutions to customers in a modest but strategic way to help facilitate the development of renewable energy and other projects and also potentially create construction backlog for us.

The economic feasibility of renewable energy projects, and therefore the attractiveness of investment in such projects, may depend on the availability of tax incentive programs or the ability of the project developer to take advantage of such incentives. There is no assurance that the government will extend existing tax incentives or create new incentive or funding programs. Although we see development of renewable energy projects, primarily utility-scale solar facilities, which could create increased demand for our engineering, procurement and construction services, we believe there is some uncertainty whether these projects will advance to award and construction.

The Federal Energy Regulatory Commission (FERC) issued FERC Order No. 1000 to promote more efficient and cost-effective development of new transmission facilities. The order establishes transmission planning and cost allocation requirements intended to facilitate multi-state electric transmission lines and to encourage competition by removing, under certain conditions, federal rights of first refusal from FERC-approved tariffs and agreements. FERC Order No. 1000 was affirmed by FERC in May 2012 with the issuance of FERC Order No. 1000-A. In the short-term, we believe FERC Order No. 1000 implementation and compliance has created some confusion and uncertainty amongst utilities and regulators that has adversely impacted the timing of some potential transmission projects and spending. However, as these challenges are worked through, we believe FERC Order No. 1000 has the potential to favorably impact electric transmission line development over time, particularly for large, high-voltage electric transmission projects.

Several existing, pending or proposed legislative or regulatory actions may also positively affect demand for the services provided by this segment in the long term, particularly in connection with electric power infrastructure and renewable energy spending. For example, legislative or regulatory action that alleviates some of the siting and right-of-way challenges that impact transmission projects would potentially accelerate future transmission line construction. We also anticipate increased infrastructure spending by our customers as a result of regulation requiring the power industry to meet federal reliability standards for its transmission and distribution systems and providing incentives to the industry to invest in and improve maintenance on its systems.

We believe that utilities remain committed to the expansion and strengthening of their transmission infrastructure with planning, engineering and funding for many of their projects in place. The regulatory and environmental permitting processes remain a hurdle for some proposed transmission and renewable energy projects, and these factors continue to create uncertainty as to timing of this spending. In the near-term, our electric power infrastructure services operations have been impacted by regulatory delays, particularly for large transmission projects. However, we expect many of these projects to move forward over a multi-year period. The timing and scope of projects can also be affected by other factors such as siting, right-of-way and unfavorable economic and market conditions. We anticipate many of these issues to be overcome and spending on transmission projects to be active over the next few years. We currently have a number of these projects underway, and we expect this segment’s backlog to remain strong for the remainder of 2016.

In the near-term, margins in our Electric Power Infrastructure Services segment have experienced pressure due to increased industry transmission resource availability, as construction of several large, high-voltage transmission projects has been delayed due to the challenging regulatory approval and permitting environment. We believe these large transmission projects have been delayed and not canceled and that demand for our transmission services will remain strong over the next several years. As a result, over the past several quarters, we have reallocated many of our large transmission resources to the small and medium size transmission market. However, we have largely maintained our transmission resource capacity overall in order to remain strategically positioned to pursue transmission projects in the future. We believe there have been excess transmission contractor resources in the small and medium size transmission marketplace due to the delay of large transmission projects, which has resulted in increased competition and pricing pressure for those services in some areas. Over the past few quarters, we believe these competitive pressures are beginning to stabilize. We will remain focused on maintaining our pricing discipline and believe competitive pressures could recede further as large, high-voltage transmission projects move forward over the coming quarters and the small and medium size transmission market continues to grow and/or contractors adjust further to the current environment.

We benefited from increases in distribution spending throughout the last several years, despite continued economic and political uncertainties. We believe there is an ongoing need for utilities to sustain investment in their distribution systems in order to properly maintain their systems. In addition, a number of utilities are implementing system upgrades or “hardening” programs in response to severe weather events that have occurred over the past few years, which is also increasing distribution investment in some regions of the United States. We also anticipate that utilities will continue to integrate “smart grid” technologies into their distribution systems over time to improve grid management and create efficiencies.

The need to ensure available specialized labor resources for projects also drives strategic relationships with customers. In addition, several industry and market trends are prompting customers in the electric power industry to seek outsourcing partners. These trends include an aging utility workforce and labor availability issues, increasing pressure to reduce cost and improve reliability, and increasing duration and complexity of customer capital programs. Due to these and other factors, we believe customer demand for labor resources will continue to increase, possibly outpacing the supply of industry resources. As a result, we believe the number of opportunities for strategic partnerships is growing.

Certain international regions present significant opportunities for growth over time across many of our operations. We are evaluating ways in which we can strategically apply our expertise to strengthen infrastructure in various foreign countries where infrastructure enhancements are increasingly important. For example, we are actively pursuing opportunities in growth markets where we can leverage our technology or proprietary work methods, such as our energized services, to establish a presence in these markets. In Canada, we are leveraging our electric power infrastructure services resources, relationships and reputation to expand and grow our telecom infrastructure services operations in the country. In addition, over the last several years we have successfully developed our telecom infrastructure services operations in several Latin American countries that offer attractive growth opportunities. We believe the success of these efforts could enable us to expand our infrastructure services offering in Latin America to include electric power and other infrastructure services.

Oil and Gas Infrastructure Services Segment

We continue to believe there are growth opportunities in our Oil and Gas Infrastructure Services segment, primarily in the installation and maintenance of larger pipeline and related facilities, as well as pipeline integrity, natural gas distribution systems and specialty services such as horizontal directional drilling. We also continue to believe the existing pipeline system infrastructure in North America is insufficient to support future development of unconventional shale formations and Canadian oil sands. We believe that the development of such resources, though declining in the near term, may continue over the long term and that building this infrastructure would take a number of years, which we believe should increase demand for our services over the long term.

We also believe the abundant natural gas supply, combined with attractive natural gas prices, will increase demand for natural gas in the future. For example, the U.S. Energy Information Administration has stated that the number of natural gas-fired power plants built will increase significantly over the next two decades. Power generation from renewable energy sources also continues to increase and become a larger percentage of the overall power generation mix. We also believe natural gas will be the fuel of choice to provide backup power generation during times when renewable energy sources are not available. We believe these factors will result in increased development of natural gas power generation and demand for natural gas production over the long term, which should create a need for additional pipeline infrastructure to connect natural gas supplies to demand centers.

A challenging regulatory and permitting environment has also caused delays of some larger pipeline projects during the past several years. These dynamics resulted in below average larger pipeline construction opportunities for us and the industry during that period. However, the market for larger pipeline projects, in our view, began to improve in the later part of 2013, though regulatory delays for some projects have moderated the pace of recovery. The lack of larger pipeline opportunities has negatively impacted our Oil and Gas Infrastructure Services segment margins, in part as a result of our inability to adequately cover certain fixed costs. Margins for larger pipeline projects are also subject to significant performance risk, which can arise from adverse weather conditions, challenging geography, customer decisions and crew productivity. Our specific opportunities in the larger pipeline business are sometimes difficult to predict because of the seasonality of the bidding and construction cycles within the industry.

A number of larger pipeline projects from the Canadian oil sands and North American shale formations to refineries and other demand centers are in various stages of development. Although many of these projects are

still developing, certain projects have been awarded to us and other pipeline contractors and are moving towards construction. Given the costs and time required to bring a larger pipeline project from conception to construction, we believe many of our customers view such projects as important, strategic pieces of infrastructure, have a long-term perspective regarding their needs, and are not primarily influenced by short term commodity fluctuations. Additionally, certain of the proposed larger oil pipeline projects that are under development have already secured oil production customers under contractual arrangements, making these projects economically viable despite the decline in oil prices. There are also a number of larger natural gas pipeline projects that have been approved and are moving towards construction and others that are in development or going through the regulatory approval process. If oil and natural gas prices further decline or remain at lower levels for a prolonged period, these views may change and demand for our oil and natural gas infrastructure services could be materially impacted.

While there is risk that these projects will not move forward or could be delayed, we are encouraged by the proposed larger pipeline development plans and the successful progression of certain larger pipeline projects, which is indicative of an improved and favorable large pipeline market over the next several years in North America. To that end, we have secured contracts for significant larger pipeline projects that we anticipate will be executed in 2016 and expect our pipeline construction activity to increase meaningfully through the year. These project progressions have had a favorable impact on our backlog, and we expect additional demand for our larger pipeline services going forward.

The abundance, low price and long-term supply of North American natural gas has also resulted in efforts to develop liquefied natural gas (LNG) export facilities in the United States, Canada and Australia, which could provide pipeline and related facilities development opportunities for us. Natural gas prices in various international markets are significantly higher than North American natural gas prices, making the economics of exporting North American natural gas to international markets attractive. A number of LNG export facilities are in various stages of planning, permitting and development in the United States and Canada. Although we cannot be certain how many, if any, of these projects will move forward, as they could be affected by changing pricing and economic conditions, we believe our comprehensive service offerings and broad geographic presence enable us to competitively pursue opportunities that become available.

Over the past several years, we have expanded our service offerings into Canada and Australia, which have different market drivers and seasonality as compared to the United States. In addition, our previous acquisitions of companies that provide pipeline logistics services to the natural gas and oil industry in the United States and specialty services to the offshore oil and gas industry further enhance the segment’s service offerings, customer base and end markets.

We also believe there are growth opportunities for some of our other pipeline services, including pipeline integrity, rehabilitation and replacement services over the long-term. The U.S. Department of Transportation has implemented regulatory legislation through the Pipeline and Hazardous Materials Safety Administration (PHMSA) relating to pipeline integrity requirements. PHMSA continues to develop, propose and implement additional safety and pipeline integrity regulation. For example, in October 2015, PHMSA proposed regulations to make critical safety improvements for hazardous liquid pipelines. The proposed regulations would strengthen requirements for operation, inspection and maintenance of hazardous liquid pipelines. In March 2016, PHMSA proposed regulations to update critical safety requirements for natural gas transmission pipelines. The proposed rule would broaden the scope of safety coverage both by adding new assessment and repair criteria for gas transmission pipelines, and by expanding these protocols to include pipelines located in areas of medium population density where an incident would pose risk to human life. The proposed rule provides pipeline operators with regulatory certainty and responds to both congressional mandates and outside safety recommendations.

We expect that these types of regulations will increase the demand for our pipeline integrity, rehabilitation and replacement services over the long-term. As pipeline integrity testing requirements increase in stringency and frequency, we believe more information will be gathered about the condition of the nation’s pipeline

infrastructure, which could result in an increase in spending by our customers on pipeline integrity initiatives. We also operate an engineering, research and development business that develops and owns pipeline inspection tools. We believe our ability to offer a complete pipeline integrity turnkey solution to pipeline companies and gas utilities positions us to take advantage of available opportunities.

We are also experiencing an increase in demand for our natural gas distribution services as a result of improved economic conditions, lower natural gas prices and a significant need to upgrade and replace aging infrastructure. A number of states, particularly states in the northeast United States that have cities and areas with aging natural gas distribution infrastructure, have approved and are implementing regulations and multi-year programs to replace cast iron, wrought iron and bare steel natural gas infrastructure, which is prone to failure with age, with modern and safer pipe material. We expect this to take an extended period of time, which should provide attractive growth opportunities for this part of our business.

The oil and gas industry is highly cyclical and subject to volatility as a result of fluctuations in natural gas, natural gas liquids and oil prices. In the past, sustained periods of low prices for these products negatively impacted the development of related natural resources and infrastructure. The current low price environment has adversely impacted demand for some of our services, primarily infrastructure services in Australia, Canada and the Gulf of Mexico. Exploration and production companies, as well as midstream companies, have significantly reduced capital spending, and are expected to continue to operate with reduced budgets for the foreseeable future. Continued low prices may further reduce spending on exploration and production. Reduced capital spending on larger pipeline, gas gathering and compressor systems and other related infrastructure would result in less demand for our services. In particular, the demand for infrastructure services in areas where the price of oil is influential, such as Australia, the Canadian Oil Sands, certain oil driven shale formations in the United States and offshore oil resources in the Gulf of Mexico, has been materially and adversely impacted by low oil prices. These markets could remain challenged for as long as oil prices remain at lower levels.

Overall, we remain cautiously optimistic about this segment’s operations going forward. We believe that, over the long term, the market will correct the current oversupply, and as a result, oil prices could recover. The timing of any recovery, however, is uncertain. From a near- and medium-term perspective, we continue to believe that larger pipeline opportunities can provide strong profitability, although these projects and the profits they generate are often subject to more cyclicality and execution risk than our other service offerings. We have also taken steps to diversify our operations in this segment through other services, such as pipeline integrity, pipeline logistics, and offshore specialty services. We believe these measures, together with the potential for larger pipeline opportunities, will position us for profitable growth in this segment over the long-term.

Conclusion

Despite lower oil and natural gas prices, continuing challenges from uncertain economic conditions and restrictive regulatory and permitting requirements, including recent regulatory delays that impacted our business in 2015 and have carried forward into 2016, particularly for large electric transmission and mainline pipe projects, we continue to see potential growth opportunities in the industries we serve.

We are benefiting from utilities’ increased spending on projects to upgrade and expand their electric power transmission infrastructure to improve system reliability and to deliver renewable electricity from new generation sources to demand centers. Favorable industry legislation and regulations are also creating incentives and a positive environment for utilities to invest in their electrical infrastructure, particularly for transmission infrastructure. Additional environmental regulations concerning fossil fuel power generation emissions create opportunities for transmission lines to be updated, rebuilt or replaced due to “coal to gas” facility replacements. We also expect utilities to outsource more of their work to companies like us, due in part to the challenges associated with their aging workforce. We believe that we remain the partner of choice for many utilities in need of broad infrastructure expertise, specialty equipment and workforce resources, particularly as capital budgets and infrastructure projects have become larger and more complex.

The current low price environment for oil and natural gas creates uncertainty and has adversely impacted demand for some of the services in our Oil and Gas Infrastructure Services segment. This dynamic could continue should natural gas and oil prices further decline or remain at lower levels. However, we believe long-term dynamics create growth opportunities going forward. We believe that our overall size and breadth of service offerings provide competitive advantages that allow us to leverage opportunities that arise in connection with development and production of resources from North American unconventional shale formations, the Canadian oil sands and coal seam gas and unconventional shale formations in Australia. We have experienced backlog growth in 2016 driven by new larger pipeline project awards and believe there could be additional larger pipeline project activity over the next several years. We also believe that our strategy to pursue midstream gathering system opportunities in certain unconventional shale formations in the United States, as well as the anticipated increase in demand for our pipeline integrity, rehabilitation and replacement services from pipeline integrity initiatives, and other services in adjacent markets, will create attractive growth potential for us and also further diversify our service offerings in both the near and long term.

Demand for our electric and natural gas distribution services has increased over the past several years as the economy has stabilized and spending on maintenance to improve reliability has returned. We are optimistic that continued implementation of electric distribution reliability programs and the potential for improvement in the housing market will facilitate continued growth in demand for our electric distribution services. Gas distribution spending has been driven primarily by improving economic conditions and the lower cost of natural gas, and more recently by efforts to replace cast iron, wrought iron and bare steel distribution pipeline systems.

Competitive pricing environments, project delays and effects from restrictive regulatory requirements have negatively impacted our margins in the past and could affect our margins in the future. Additionally, margins may be negatively impacted on a quarterly basis due to adverse weather conditions, as well as timing of project starts or completions and other factors as previously described in Understanding Margins. We continue to focus on the elements of the business we can control, including costs, the margins we accept on projects, collecting receivables, ensuring quality service, rightsizing initiatives as needed to match the markets we serve, and safely executing on the projects we are awarded.

Capital expenditures for 2016 related to continuing operations are expected to be between $200 million to $220 million. We expect 2016 capital expenditures to be funded substantially from cash on hand, internal cash flows and borrowings under our credit facility.

We also continue to evaluate potential strategic acquisitions and similar investments to broaden our customer base, expand our geographic area of operation, grow our portfolio of services and increase opportunities across our operations. We believe that additional attractive acquisition candidates exist primarily as a result of the highly fragmented nature of the industry, the inability of many companies to expand and modernize due to capital constraints, and the desire of owners for liquidity. We also believe that our financial strength, entrepreneurial operating model and experienced management team are attractive to acquisition candidates.

We believe that we are well-positioned to capitalize upon opportunities and trends in the industries we serve because of our full-service operations with broad geographic reach, our financial strength and our technical expertise. Additionally, we believe the industry opportunities and trends discussed herein will increase the demand for our services over the long-term, although the actual timing, magnitude and impact of these opportunities and trends on our results of operations, financial position and cash flows are difficult to predict.

Uncertainty of Forward-Looking Statements and Information

This Quarterly Report on Form 10-Q includes “forward-looking statements” reflecting assumptions, expectations, projections, intentions or beliefs about future events that are intended to qualify for the “safe harbor” from liability established by the Private Securities Litigation Reform Act of 1995. You can identify these

statements by the fact that they do not relate strictly to historical or current facts. They use words such as “anticipate,” “estimate,” “project,” “forecast,” “may,” “will,” “should,” “could,” “expect,” “believe,” “plan,” “intend” and other words of similar meaning. In particular, these include, but are not limited to, statements relating to the following:

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Projected revenues, net income, earnings per share, margins, weighted average shares outstanding, capital expenditures, and other projections of operating or financial results;

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Expectations regarding our business outlook, growth or opportunities in particular markets;

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The expected value of contracts or intended contracts with customers;

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Future capital allocation initiatives, including the amount, timing, availability and strategy with respect to any future stock repurchases;

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The scope, services, term and results of any projects awarded or expected to be awarded for services to be provided by us;

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The development of larger electric transmission and oil and natural gas pipeline projects and their impact on our business or demand for our services;

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The level of oil, natural gas and natural gas liquids prices and their impact on our business or demand for our services;

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The impact of renewable energy initiatives, including mandated state renewable portfolio standards, the economic stimulus package and other existing or potential energy legislation;

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Potential opportunities that may be indicated by bidding activity or similar discussions with customers;

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The potential benefits from acquisitions;

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The expected outcome of pending or threatened litigation;

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The business plans or financial condition of our customers;

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Our plans and strategies;

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Possible recovery on pending or contemplated change orders or other claims against customers or third parties;

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The current economic and regulatory conditions and trends in the industries we serve; and

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The effects or results of the sale of our fiber optic licensing operations;

These forward-looking statements are not guarantees of future performance and involve or rely on a number of risks, uncertainties, and assumptions that are difficult to predict or beyond our control. These forward-looking statements reflect our beliefs and assumptions based on information available to our management at the time the statements are made. We caution you that actual outcomes and results may differ materially from what is expressed, implied or forecasted by our forward-looking statements and that any or all of our forward-looking statements may turn out to be wrong. Those statements can be affected by inaccurate assumptions and by known or unknown risks and uncertainties, including the following:

•

Market conditions;

•

The effects of industry, economic or political conditions outside our control;

•

Quarterly variations in our operating results;

•

Adverse economic and financial conditions, including weakness in the capital markets;

•

Trends and growth opportunities in relevant markets;

•

Delays, reductions in scope or cancellations of anticipated, pending or existing projects, including as a result of weather, regulatory or environmental processes, project performance issues, or our customers’ capital constraints;

•

The successful negotiation, execution, performance and completion of anticipated, pending and existing contracts, including the ability to obtain awards of projects on which we bid or are otherwise discussing with customers;

•

Our dependence on suppliers, subcontractors and equipment manufacturers;

•

Our ability to attract skilled labor and retain key personnel and qualified employees;

•

The potential shortage of skilled employees;

•

Our dependence on fixed price contracts and the potential to incur losses with respect to these contracts;

•

Estimates relating to our use of percentage-of-completion accounting;

•

Adverse impacts from weather;

•

Our ability to generate internal growth;

•

Competition in our business, including our ability to effectively compete for new projects and market share;

•

The effect of natural gas, natural gas liquids and oil prices on our operations and growth opportunities and on our customers’ capital programs and the resulting impact on demand for our services;

•

The future development of natural resources in shale formations;

•

Potential failure of renewable energy initiatives, the economic stimulus package or other existing or potential legislative actions to result in increased demand for our services;

•

Liabilities associated with multiemployer pension plans, including underfunding of liabilities and termination or withdrawal liabilities;

•

The possibility of further increases in the liability associated with our withdrawal from a multiemployer pension plan;

•

Liabilities for claims that are self-insured or not insured;

•

Unexpected costs or liabilities that may arise from lawsuits or indemnity claims asserted against us;

•

The outcome of pending or threatened litigation;

•

Risks relating to the potential unavailability or cancellation of third party insurance, the exclusion of coverage for certain losses, and potential increases in premiums for coverage deemed beneficial to us;

•

Cancellation provisions within our contracts and the risk that contracts expire and are not renewed or are replaced on less favorable terms;

•

Loss of customers with whom we have long-standing or significant relationships;

•

The potential that participation in joint ventures exposes us to liability and/or harm to our reputation for acts or omissions by our partners;

•

Our inability or failure to comply with the terms of our contracts, which may result in unexcused delays, warranty claims, failure to meet performance guarantees, damages or contract terminations;

•

The inability of our customers to pay for services;

•

The failure to recover on payment claims against project owners or to obtain adequate compensation for customer-requested change orders;

•

The failure of our customers to comply with regulatory requirements applicable to their projects, including those related to awards of stimulus funds, which may result in project delays and cancellations;

•

Budgetary or other constraints that may reduce or eliminate tax incentives for or government funding of projects, including stimulus projects, which may result in project delays or cancellations;

•

Estimates and assumptions in determining our financial results and backlog;

•

Our ability to realize our backlog;

•

Risks associated with operating in international markets, including instability of foreign governments, currency fluctuations, tax and investment strategies and compliance with the laws of foreign jurisdictions, as well as the U.S. Foreign Corrupt Practices Act and other applicable anti-bribery and anti-corruption laws;

•

Our ability to successfully identify, complete, integrate and realize synergies from acquisitions;

•

The potential adverse impact resulting from uncertainty surrounding acquisitions, including the ability to retain key personnel from the acquired businesses and the potential increase in risks already existing in our operations;

•

The adverse impact of impairments of goodwill, receivables and other intangible assets or investments;

•

Our growth outpacing our decentralized management and infrastructure;

•

Requirements relating to governmental regulation and changes thereto;

•

Inability to enforce our intellectual property rights or the obsolescence of such rights;

•

Risks related to the implementation of an information technology solution;

•

The impact of our unionized workforce on our operations, including labor stoppages or interruptions due to strikes or lockouts;

•

Potential liabilities relating to occupational health and safety matters;

•

Beliefs and assumptions about the collectability of receivables;

•

The cost of borrowing, availability of cash and credit, fluctuations in the price and volume of our common stock, debt covenant compliance, interest rate fluctuations and other factors affecting our financing and investing activities;

•

The ability to access sufficient funding to finance desired growth and operations;

•

Our ability to obtain performance bonds;

•

Potential exposure to environmental liabilities;

•

Our ability to continue to meet the requirements of the Sarbanes-Oxley Act of 2002;

•

Rapid technological and structural changes that could reduce the demand for our services;

•

The impact of increased healthcare costs arising from healthcare reform legislation;

•

The impact of regulatory changes on labor costs;

•

The impact of significant fluctuations in foreign currency exchange rates;

•

The business, accounting and other effects from the sale of our fiber optic licensing operations;

•

The potential for claims or damages associated with the sale of our fiber optic licensing operations, including as a result of indemnity claims;

•

The terms of any transaction we enter into to facilitate the repurchase of shares under our stock repurchase program; and

•

The other risks and uncertainties as are described elsewhere herein and in Item 1A. Risk Factors of Part I of our Annual Report on Form 10-K for the year ended December 31, 2015 and as may be detailed from time to time in our other public filings with the SEC.

All of our forward-looking statements, whether written or oral, are expressly qualified by these cautionary statements and any other cautionary statements that may accompany such forward-looking statements or that are otherwise included in this report. In addition, we do not undertake and expressly disclaim any obligation to update or revise any forward-looking statements to reflect events or circumstances after the date of this report or otherwise.

Item 3.

Quantitative and Qualitative Disclosures about Market Risk.

The information in this section should be read in connection with the information on financial market risk related to changes in interest rates and currency exchange rates in Item 7A. Quantitative and Qualitative Disclosures About Market Risk of Part II of our Annual Report on Form 10-K for the year ended December 31, 2015. Our primary exposure to market risk relates to unfavorable changes in concentration of credit risk, interest rates and currency exchange rates.

Credit Risk. We are subject to concentrations of credit risk related to our cash and cash equivalents and our accounts receivable, including amounts related to unbilled accounts receivable and costs and estimated earnings in excess of billings on uncompleted contracts. Substantially all of our cash investments are managed by what we believe to be high credit quality financial institutions. In accordance with our investment policies, these institutions are authorized to invest this cash in a diversified portfolio of what we believe to be high-quality investments, which primarily include interest-bearing demand deposits, money market investments and money market mutual funds with original maturities of three months or less. Although we do not currently believe the principal amounts of these investments are subject to any material risk of loss, changes in economic conditions could impact the interest income we receive from these investments. In addition, as we grant credit under normal payment terms, generally without collateral, we are subject to potential credit risk related to our customers’ ability to pay for services provided. This risk may be heightened as a result of the depressed economic and financial market conditions that have existed in recent years. However, we believe the concentration of credit risk related to trade accounts receivable and costs and estimated earnings in excess of billings on uncompleted contracts is limited because of the diversity of our customers. We perform ongoing credit risk assessments of our customers and financial institutions and in some cases we obtain collateral or other security from our customers.

Interest Rate Risk. As of June 30, 2016, we had no derivative financial instruments to manage interest rate risk. As such, we were exposed to earnings and fair value risk due to changes in interest rates with respect to our long-term obligations. As of June 30, 2016, the fair value of our variable rate debt of $400.0 million approximated book value. Our weighted average interest rate for the three months ended June 30, 2016 was 2.18%. The annual effect on our pretax earnings of a hypothetical 50 basis point increase or decrease in variable interest rates would be approximately $2.0 million based on our June 30, 2016 balance of variable rate debt.

Foreign Currency Risk. The U.S. dollar is the functional currency for the majority of our operations, which are primarily located within the United States. The functional currency for our foreign operations, which are primarily located in Canada and Australia, is typically the currency of the country in which the foreign operating unit is located. Accordingly, our financial performance is subject to fluctuation due to changes in foreign currency exchange rates relative to the U.S. dollar. During the three and six months ended June 30, 2016, revenues from our foreign operations accounted for 18.7% and 19.6% of our consolidated revenues. Fluctuations in foreign exchange rates during the three months ended June 30, 2016 caused an approximate decrease of $14 million in foreign revenues compared to the three months ended June 30, 2015. Fluctuations in foreign exchange rates during the six months ended June 30, 2016 caused an approximate decrease of $46 million in foreign revenues compared to the six months ended June 30, 2015.

We are also subject to foreign currency risk with respect to sales, purchases and borrowings that are denominated in a currency other than the respective functional currencies of our operating units. To minimize the risk from changes in foreign currency exchange rates, we may enter into foreign currency derivative contracts to hedge our foreign currency risk on a cash flow basis. There were no outstanding foreign currency derivative contracts at June 30, 2016.

We also have foreign exchange risk related to cash and cash equivalents in foreign banks. Based on the balance of cash and cash equivalents in foreign banks of $148.9 million as of June 30, 2016, an assumed 5% adverse change to foreign exchange rates would result in a fair value decline of $7.4 million. Fluctuations in fair value are recorded in “Accumulated other comprehensive income (loss),” a separate component of stockholders’ equity.

Item 4. Controls and Procedures.

Attached as exhibits to this Quarterly Report are certifications of Quanta’s Chief Executive Officer and Chief Financial Officer that are required in accordance with Rule 13a-14 of the Securities Exchange Act of 1934, as amended (the Exchange Act). This Controls and Procedures section includes information concerning the controls and controls evaluation referred to in the certifications, and it should be read in conjunction with the certifications for a more complete understanding of the topics presented.

Evaluation of Disclosure Controls and Procedures

Our management has established and maintains a system of disclosure controls and procedures that are designed to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act, such as this Quarterly Report, is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms. The disclosure controls and procedures are also designed to provide reasonable assurance that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

As of the end of the period covered by this Quarterly Report, we evaluated the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) of the Exchange Act. This evaluation was carried out under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer. Based on this evaluation, these officers have concluded that, as of June 30, 2016, our disclosure controls and procedures were effective to provide reasonable assurance of achieving their objectives.

Internal Control over Financial Reporting

There has been no change in our internal control over financial reporting that occurred during the quarter ended June 30, 2016 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Design and Operation of Control Systems

Our management, including the Chief Executive Officer and Chief Financial Officer, does not expect that our disclosure controls and procedures or our internal control over financial reporting will prevent or detect all errors and all fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be met. The design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Further, because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that misstatements due to error or fraud will not occur or that all control issues and instances

of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty and breakdowns can occur because of simple errors or mistakes. Controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the controls. The design of any system of controls is based in part on certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Over time, controls may become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or procedures.

PART II — OTHER INFORMATION

Item 1.

Legal Proceedings.

We are from time to time party to various lawsuits, claims and other legal proceedings that arise in the ordinary course of business. These actions typically seek, among other things, compensation for alleged personal injury, breach of contract and/or property damages, employment-related damages, punitive damages, civil penalties or other losses, or injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, we record a reserve when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. In addition, we disclose matters for which management believes a material loss is at least reasonably possible. See Legal Proceedings and Collective Bargaining Agreements in Note 11 of the Notes to Condensed Consolidated Financial Statements in Item 1. Financial Statements of Part I of this Quarterly Report, which are incorporated by reference in this Item 1. Legal Proceedings of Part II of this Quarterly Report, for additional information regarding litigation, claims and other legal proceedings.

Item 1A.

Risk Factors.

As of the date of this filing, there have been no material changes from the risk factors previously disclosed in Item 1A. Risk Factors of Part I of our Annual Report on Form 10-K for the year ended December 31, 2015 (2015 Annual Report). An investment in our common stock or other equity securities involves various risks. When considering an investment in our company, you should carefully consider all of the risk factors described herein and in our 2015 Annual Report. The matters specifically identified are not the only risks and uncertainties we face, and there may be additional matters that are not known to us or that we currently consider immaterial. All of these risks and uncertainties could adversely affect our business, financial condition or future results, and thus the value of an investment in our company.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds.

Unregistered Sales of Equity Securities

None.

Issuer Purchases of Equity Securities During the Second Quarter of 2016

The following table contains information about our purchases of equity securities during the three months ended June 30, 2016.


Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares that may yet be Purchased Under the Plans or Programs⁽¹⁾
April 1-30, 2016
ASR⁽¹⁾		9,413,640	$	15.93		9,413,640
Tax Withholdings⁽²⁾		—	$	—
May 1-31, 2016
Tax Withholdings⁽²⁾		6,096	$	23.48
June 1-30, 2016
Tax Withholdings⁽²⁾		—	$	—

Total		9,419,736				9,413,640	$	50,120,407

⁽¹⁾

On August 5, 2015, we issued a press release announcing that our board of directors approved a stock repurchase program authorizing us to purchase, from time to time through February 28, 2017, up to $1.25 billion of our outstanding common stock. Repurchases under the program can be made in open market or privately negotiated transactions, including pursuant to an accelerated share repurchase arrangement, issuer repurchase plan or otherwise, at our discretion, based on market and business conditions, applicable contractual and legal requirements and other factors. This program does not obligate us to acquire any specific amount of common stock and may be modified or terminated by our board of directors at any time at its sole discretion and without notice. In August 2015, we entered into an accelerated share repurchase arrangement (the ASR) to repurchase $750.0 million of our common stock. Under the terms of the ASR, we paid $750.0 million to JPMorgan Chase Bank, National Association, London Branch (JPMorgan) and initially received 25.7 million shares of our common stock with a fair market value of approximately $600.0 million. On April 12, 2016, upon final settlement of the ASR, we received 9.4 million additional shares of our common stock for the remaining $150.0 million we paid in August of 2015 under the ASR. As of June 30, 2016, approximately $50.1 million remained available under the program.

⁽²⁾	Includes shares purchased from employees to satisfy tax withholding obligations in connection with the vesting of restricted stock and restricted stock unit awards.

Item 3.

Defaults Upon Senior Securities.

None.

Item 4.

Mine Safety Disclosures.

None.

Item 5.

Other Information.

None.

Item 6.

Exhibits.


Exhibit No.		Description

3.1		Restated Certificate of Incorporation of Quanta Services, Inc. (previously filed as Exhibit 3.3 to the Company’s Form 8-K filed May 25, 2011 and incorporated herein by reference)

3.2		Certificate of Designation of Series G Preferred Stock (previously filed as Exhibit 3.1 to the Company’s Form 8-K filed January 17, 2014 and incorporated herein by reference)

3.3		Bylaws of Quanta Services, Inc., as amended and restated March 27, 2014 (previously filed as Exhibit 3.1 to the Company’s Form 8-K filed March 31, 2014 and incorporated herein by reference)

10.1 *		Amendment No. 2 to the Quanta Services, Inc. 2011 Omnibus Equity Incentive Plan

10.2 *		First Amendment to Fourth Amended and Restated Credit Agreement dated as of June 27, 2016, among Quanta Services, Inc. and certain subsidiaries of Quanta Services, Inc., as Borrowers, certain subsidiaries of Quanta Services, Inc. identified therein as Guarantors, Bank of America, N.A., as Administrative Agent, Domestic Swing Line Lender and an L/C Issuer, and the other Lenders party thereto

31.1 *		Certification by Chief Executive Officer pursuant to Rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)


Exhibit No.		Description

31.2 *		Certification by Chief Financial Officer pursuant to Rule 13a -14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)

32.1 *		Certification by Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith)

101		XBRL Instance Document
INS *

101		XBRL Taxonomy Extension Schema Document
SCH *

101		XBRL Taxonomy Extension Calculation Linkbase Document
CAL *

101		XBRL Taxonomy Extension Label Linkbase Document
LAB *

101		XBRL Taxonomy Extension Presentation Linkbase Document
PRE *

101		XBRL Taxonomy Extension Definition Linkbase Document
DEF *

*	Filed or furnished herewith

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant, Quanta Services, Inc., has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


QUANTA SERVICES, INC.

By:		/s/ DERRICK A. JENSEN
		Derrick A. Jensen Chief Financial Officer
		(Principal Financial Officer and
		Principal Accounting Officer)

Dated: August 8, 2016

INDEX TO EXHIBITS


Exhibit No.		Description

3.1		Restated Certificate of Incorporation of Quanta Services, Inc. (previously filed as Exhibit 3.3 to the Company’s Form 8-K filed May 25, 2011 and incorporated herein by reference)

3.2		Certificate of Designation of Series G Preferred Stock (previously filed as Exhibit 3.1 to the Company’s Form 8-K filed January 17, 2014 and incorporated herein by reference)

3.3		Bylaws of Quanta Services, Inc., as amended and restated March 27, 2014 (previously filed as Exhibit 3.1 to the Company’s Form 8-K filed March 31, 2014 and incorporated herein by reference)

10.1 *		Amendment No. 2 to the Quanta Services, Inc. 2011 Omnibus Equity Incentive Plan

10.2 *		First Amendment to Fourth Amended and Restated Credit Agreement dated as of June 27, 2016, among Quanta Services, Inc. and certain subsidiaries of Quanta Services, Inc., as Borrowers, certain subsidiaries of Quanta Services, Inc. identified therein as Guarantors, Bank of America, N.A., as Administrative Agent, Domestic Swing Line Lender and an L/C Issuer, and the other Lenders party thereto

31.1 *		Certification by Chief Executive Officer pursuant to Rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)

31.2 *		Certification by Chief Financial Officer pursuant to Rule 13a -14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)

32.1 *		Certification by Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith)

101		XBRL Instance Document
INS *

101		XBRL Taxonomy Extension Schema Document
SCH *

101		XBRL Taxonomy Extension Calculation Linkbase Document
CAL *

101		XBRL Taxonomy Extension Label Linkbase Document
LAB *

101		XBRL Taxonomy Extension Presentation Linkbase Document
PRE *

101		XBRL Taxonomy Extension Definition Linkbase Document
DEF *

*	Filed or furnished herewith