Edgar Filing: ITC Holdings Corp.

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Accelerated filer o

Non-accelerated filer o

Smaller reporting company o

(Do not check if a smaller reporting company)

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 March 31, 2016



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

Commission File Number: 001-32576

ITC HOLDINGS CORP.

(Exact Name of Registrant as Specified in Its Charter)



Michigan (State or Other Jurisdiction of Incorporation or Organization)		32-0058047 (I.R.S. Employer Identification No.)

27175 Energy Way

Novi, MI 48377

(Address Of Principal Executive Offices, Including Zip Code)

(248) 946-3000

(Registrant’s Telephone Number, Including Area Code)

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

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):

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

The number of shares of the Registrant’s Common Stock, without par value, outstanding as of April 22, 2016 was 152,777,811.

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ITC Holdings Corp.

Form 10-Q for the Quarterly Period Ended March 31, 2016

INDEX



	Page
Part I. Financial Information	5
Item 1. Financial Statements	5
Condensed Consolidated Statements of Financial Position (Unaudited)	5
Condensed Consolidated Statements of Operations (Unaudited)	6
Condensed Consolidated Statements of Comprehensive Income (Unaudited)	7
Condensed Consolidated Statements of Cash Flows (Unaudited)	8
Notes to Condensed Consolidated Financial Statements (Unaudited)	9
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3. Quantitative and Qualitative Disclosures About Market Risk	36
Item 4. Controls and Procedures	37
Part II. Other Information	37
Item 1. Legal Proceedings	37
Item 1A. Risk Factors	38
Item 2. Unregistered Sale of Equity Securities and Use of Proceeds	38
Item 6. Exhibits	39
Signatures	40
Exhibit Index

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DEFINITIONS

Unless otherwise noted or the context requires, all references in this report to:

ITC Holdings Corp. and its subsidiaries


•	“ITC Great Plains” are references to ITC Great Plains, LLC, a wholly-owned subsidiary of ITC Grid Development, LLC;


•	“ITC Grid Development” are references to ITC Grid Development, LLC, a wholly-owned subsidiary of ITC Holdings;


•	“ITC Holdings” are references to ITC Holdings Corp. and not any of its subsidiaries;


•	“ITC Midwest” are references to ITC Midwest LLC, a wholly-owned subsidiary of ITC Holdings;


•	“ITCTransmission” are references to International Transmission Company, a wholly-owned subsidiary of ITC Holdings;


•	“METC” are references to Michigan Electric Transmission Company, LLC, a wholly-owned subsidiary of MTH;


•	“MISO Regulated Operating Subsidiaries” are references to ITCTransmission, METC and ITC Midwest together;


•	“MTH” are references to Michigan Transco Holdings, LLC, the sole member of METC and an indirect wholly-owned subsidiary of ITC Holdings;


•	“Regulated Operating Subsidiaries” are references to ITCTransmission, METC, ITC Midwest and ITC Great Plains together; and


•	“We,” “our” and “us” are references to ITC Holdings together with all of its subsidiaries.

Other definitions


•	“Consumers Energy” are references to Consumers Energy Company, a wholly-owned subsidiary of CMS Energy Corporation;


•	“DTE Electric” are references to DTE Electric Company, a wholly-owned subsidiary of DTE Energy Company;


•	“FERC” are references to the Federal Energy Regulatory Commission;


•	“Fortis” are references to Fortis Inc.;


•	“FortisUS” are references to FortisUS Inc., a subsidiary of Fortis;


•	“FPA” are references to the Federal Power Act;


•	“IP&L” are references to Interstate Power and Light Company, an Alliant Energy Corporation subsidiary;


•	“ITC Holdings’ annual report on Form 10-K” are references to the annual report on Form 10-K filed on February 26, 2015;


•	“kV” are references to kilovolts (one kilovolt equaling 1,000 volts);


•	“kW” are references to kilowatts (one kilowatt equaling 1,000 watts);


•	“LIBOR” are references to the London Interbank Offered Rate;


•	“Merger” are references to the proposed merger with Fortis, whereby ITC Holdings will merge with Merger Sub and subsequently become a subsidiary of FortisUS;


•	“Merger Agreement” are references to the agreement between Fortis, FortisUS, Merger Sub and ITC Holdings for the Merger;


•	“Merger Sub” are references to Element Acquisition Sub, Inc., a subsidiary of Fortis;


•	“MISO” are references to the Midcontinent Independent System Operator, Inc., a FERC-approved RTO which oversees the operation of the bulk power transmission system for a substantial portion of the Midwestern United States and Manitoba, Canada, and of which ITCTransmission, METC and ITC Midwest are members;


•	“NERC” are references to the North American Electric Reliability Corporation;


•	“RTO” are references to Regional Transmission Organizations; and

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•	“SPP” are references to Southwest Power Pool, Inc., a FERC-approved RTO which oversees the operation of the bulk power transmission system for a substantial portion of the South Central United States, and of which ITC Great Plains is a member.

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PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ITC HOLDINGS CORP. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF FINANCIAL POSITION (UNAUDITED)



	March 31,		December 31,
(in thousands, except share data)	2016		2015
ASSETS
Current assets
Cash and cash equivalents	$	8,221	$	13,859
Accounts receivable	120,533		104,262
Inventory	27,577		25,777
Regulatory assets	16,937		14,736
Income tax receivable	141,323		—
Prepaid and other current assets	10,920		10,608
Total current assets	325,511		169,242
Property, plant and equipment (net of accumulated depreciation and amortization of $1,512,637 and $1,487,713, respectively)	6,246,320		6,109,639
Other assets
Goodwill	950,163		950,163
Intangible assets (net of accumulated amortization of $29,073 and $28,242, respectively)	44,950		45,602
Regulatory assets	249,264		233,376
Deferred financing fees (net of accumulated amortization of $1,469 and $1,277, respectively)	3,343		2,498
Other	43,691		44,802
Total other assets	1,291,411		1,276,441
TOTAL ASSETS	$	7,863,242	$	7,555,322
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	117,461	$	124,331
Accrued payroll	13,985		24,123
Accrued interest	39,576		52,577
Accrued taxes	33,475		44,256
Regulatory liabilities	36,102		44,964
Refundable deposits from generators for transmission network upgrades	16,744		2,534
Debt maturing within one year	607,058		395,105
Other	28,374		31,034
Total current liabilities	892,775		718,924
Accrued pension and postretirement liabilities	65,907		61,609
Deferred income taxes	898,858		735,426
Regulatory liabilities	273,564		254,788
Refundable deposits from generators for transmission network upgrades	7,522		18,077
Other	27,848		23,075
Long-term debt	3,947,954		4,034,352
Commitments and contingent liabilities (Notes 3 and 10)
STOCKHOLDERS’ EQUITY
Common stock, without par value, 300,000,000 shares authorized, 152,766,017 and 152,699,077 shares issued and outstanding at March 31, 2016 and December 31, 2015, respectively	835,513		829,211
Retained earnings	911,198		875,595
Accumulated other comprehensive income	2,103		4,265
Total stockholders’ equity	1,748,814		1,709,071
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	7,863,242	$	7,555,322

See notes to condensed consolidated financial statements (unaudited).

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ITC HOLDINGS CORP. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)



	Three months ended
	March 31,
(in thousands, except per share data)	2016			2015
OPERATING REVENUES	$	280,133		$	272,487
OPERATING EXPENSES
Operation and maintenance	24,596			25,562
General and administrative	45,708			40,894
Depreciation and amortization	38,872			34,435
Taxes other than income taxes	23,449			22,380
Other operating (income) and expenses — net	(264		)	(236		)
Total operating expenses	132,361			123,035
OPERATING INCOME	147,772			149,452
OTHER EXPENSES (INCOME)
Interest expense — net	50,417			48,474
Allowance for equity funds used during construction	(7,519		)	(7,549		)
Other income	(268		)	(253		)
Other expense	1,162			1,188
Total other expenses (income)	43,792			41,860
INCOME BEFORE INCOME TAXES	103,980			107,592
INCOME TAX PROVISION	39,743			40,460
NET INCOME	$	64,237		$	67,132
Basic earnings per common share	$	0.42		$	0.43
Diluted earnings per common share	$	0.42		$	0.43
Dividends declared per common share	$	0.1875		$	0.1625

See notes to condensed consolidated financial statements (unaudited).

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ITC HOLDINGS CORP. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)



	Three months ended
	March 31,
(in thousands)	2016			2015
NET INCOME	$	64,237		$	67,132
OTHER COMPREHENSIVE LOSS
Derivative instruments, net of tax (Note 6)	(2,423		)	(727		)
Available-for-sale securities, net of tax (Note 6)	261			106
TOTAL OTHER COMPREHENSIVE LOSS, NET OF TAX	(2,162		)	(621		)
TOTAL COMPREHENSIVE INCOME	$	62,075		$	66,511

See notes to condensed consolidated financial statements (unaudited).

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ITC HOLDINGS CORP. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)



	Three months ended
	March 31,
(in thousands)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	64,237		$	67,132
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	38,872			34,435
Recognition, refund and collection of revenue accruals and deferrals — including accrued interest	(16,581		)	(12,484		)
Deferred income tax expense	160,881			27,823
Allowance for equity funds used during construction	(7,519		)	(7,549		)
Other	8,550			6,777
Changes in assets and liabilities, exclusive of changes shown separately:
Accounts receivable	(10,778		)	(3,826		)
Inventory	(1,788		)	(72		)
Income tax receivable	(141,323		)	—
Prepaid and other current assets	(66		)	(9,920		)
Accounts payable	6,373			(4,855		)
Accrued payroll	(6,463		)	(7,540		)
Accrued interest	(13,001		)	(13,172		)
Accrued taxes	(10,781		)	(11,140		)
Other current liabilities	(3,094		)	(1,676		)
Estimated potential refund related to return on equity complaints	18,900			7,960
Other non-current assets and liabilities, net	1,397			(4,960		)
Net cash provided by operating activities	87,816			66,933
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(203,996		)	(172,604		)
Other	8,754			(5,637		)
Net cash used in investing activities	(195,242		)	(178,241		)
CASH FLOWS FROM FINANCING ACTIVITIES
Borrowings under revolving credit agreements	244,100			349,800
Net issuance of commercial paper, net of discount	211,360			—
Repayments of revolving credit agreements	(331,200		)	(222,400		)
Dividends on common and restricted stock	(28,585		)	(25,220		)
Refundable deposits from generators for transmission network upgrades	4,820			143
Repayment of refundable deposits from generators for transmission network upgrades	—			(9,178		)
Other	1,293			(464		)
Net cash provided by financing activities	101,788			92,681
NET DECREASE IN CASH AND CASH EQUIVALENTS	(5,638		)	(18,627		)
CASH AND CASH EQUIVALENTS — Beginning of period	13,859			27,741
CASH AND CASH EQUIVALENTS — End of period	$	8,221		$	9,114

See notes to condensed consolidated financial statements (unaudited).

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1. GENERAL

These condensed consolidated financial statements should be read in conjunction with the notes to the consolidated financial statements as of and for the year ended December 31, 2015 included in ITC Holdings’ annual report on Form 10-K for such period.

The accompanying condensed consolidated financial statements have been prepared using accounting principles generally accepted in the United States of America (“GAAP”) and with the instructions to Form 10-Q and Rule 10-01 of Securities and Exchange Commission (“SEC”) Regulation S-X as they apply to interim financial information. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. These accounting principles require us to use estimates and assumptions that impact the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from our estimates.

The condensed consolidated financial statements are unaudited, but in our opinion include all adjustments (consisting of normal recurring adjustments) necessary for a fair statement of the results for the interim period. The interim financial results are not necessarily indicative of results that may be expected for any other interim period or the fiscal year.

Supplementary Cash Flows Information



	Three months ended
	March 31,
(in thousands)	2016		2015
Supplementary cash flows information:
Interest paid (net of interest capitalized)	$	60,966	$	61,633
Income taxes paid — net	18,444		19,817
Supplementary non-cash investing and financing activities:
Additions to property, plant and equipment and other long-lived assets (a)	$	99,395	$	71,219
Allowance for equity funds used during construction	7,519		7,549

____________________________


(a)	Amounts consist of accrued liabilities for construction, labor, materials and other costs that have not been included in investing activities. These amounts have not been paid for as of March 31, 2016 or 2015, respectively, but have been or will be included as a cash outflow from investing activities for expenditures for property, plant and equipment when paid.

2. RECENT ACCOUNTING PRONOUNCEMENTS

Revenue Recognition

In May 2014, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance requiring entities to apply a new model for recognizing revenue from contracts with customers. The guidance will supersede the current revenue recognition guidance and require entities to evaluate their revenue recognition arrangements using a five step model to determine when a customer obtains control of a transferred good or service. The guidance is effective for annual reporting periods beginning after December 15, 2017 and may be adopted using a full or modified retrospective application. We do not expect the guidance to have a material impact on our consolidated results of operations, cash flows, or financial position.

Going Concern

In August 2014, the FASB issued authoritative guidance on (1) how to perform a going concern assessment and (2) when going concern disclosures are required under GAAP. The guidance extends the responsibility for performing a going concern assessment to company management; previously, this requirement existed only in auditing literature. The standard is expected to enhance the timeliness, clarity and consistency of going concern disclosures. The guidance is effective for the annual period ending after December 15, 2016, and for interim periods and annual periods thereafter. Early application is permitted. We do not expect the standard to have a material impact on our consolidated financial statements, including our disclosures.

Amendments to the Consolidation Analysis

In February 2015, the FASB issued authoritative guidance that amends the variable interest entity consolidation analysis under GAAP. The new standard was issued to improve targeted areas of consolidation guidance. Although the FASB’s

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deliberations were largely focused on the investment management industry, the standard is applicable for reporting entities across industries. Specifically, the guidance amends the consolidation analysis for limited partnerships, clarifies when fees paid to a decision maker should be a factor in the consolidation analysis and amends how variable interests held by related parties affect consolidation. We adopted this guidance as of January 1, 2016 and it did not change our conclusions with regard to identification of variable interest entities or consolidation of any entities.

Amendment to the Balance Sheet Presentation of Debt Issuance Costs

In April 2015, the FASB issued authoritative guidance that amends the balance sheet presentation of debt issuance costs. This new standard requires debt issuance costs to be shown as a direct deduction from the carrying amount of the related debt, consistent with debt discounts. The guidance is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. On January 1, 2016, we adopted this guidance retrospectively and have applied this change to all amounts presented in our condensed consolidated statements of financial position. The following shows the impact of this adoption on our previously reported consolidated statement of financial position as of December 31, 2015:



(In thousands)	Reported		Adjustment			Adjusted
Deferred financing fees (net of accumulated amortization)	$	29,298	$	(26,800	)	$	2,498
Debt maturing within one year	395,334		(229		)	395,105
Long-term debt	4,060,923		(26,571		)	4,034,352

We have accounted for this adoption as a change in accounting principle that is required due to a change in the authoritative accounting guidance. In connection with implementing this guidance, we adopted an accounting policy to present unamortized debt issuance costs associated with revolving credit agreements, commercial paper and other similar arrangements as an asset that is amortized over the life of the particular arrangement. In addition, we present debt issuance costs incurred prior to the associated debt funding as an asset for all other debt arrangements. This standard did not impact our consolidated statements of operations or cash flows.

Classification and Measurement of Financial Instruments

In January 2016, the FASB issued authoritative guidance amending the classification and measurement of financial instruments. The guidance requires entities to carry most investments in equity securities at fair value and recognize changes in fair value in net income, unless the investment results in consolidation or equity method accounting. For financial liabilities measured using the fair value option, the change in fair value caused by a change in instrument-specific credit will be presented separately in other comprehensive income as opposed to reflecting the entire amount of the change in fair value in earnings. Additionally, the new guidance amends certain disclosure requirements associated with the fair value of financial instruments. The guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is permitted. The guidance is required to be adopted by recording a cumulative-effect adjustment to beginning retained earnings as of the beginning of the fiscal year in which the guidance is effective (“modified retrospective adoption”), with limited exceptions. We are currently assessing the impacts this guidance will have on our consolidated financial statements, including our disclosures.

Accounting for Leases

In February 2016, the FASB issued authoritative guidance on accounting for leases, which impacts accounting by lessees as well as lessors. The new guidance creates a dual approach for lessee accounting, with lease classification determined in accordance with principles in existing lease guidance. Income statement presentation differs depending on the lease classification; however, both types of leases result in lessees recognizing a right-of-use asset and a lease liability, with limited exceptions. Under existing accounting guidance, operating leases are not recorded on the balance sheet of lessees. The new guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years and will be applied using a modified retrospective approach, with possible optional practical expedients. Early application is permitted. We are currently assessing the impacts this guidance will have on our consolidated financial statements, including our disclosures.

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Contingent Put and Call Options in Debt Instruments

In March 2016, the FASB issued authoritative guidance intended to standardize the assessment of whether embedded features within a debt host contract, including contingent put and call options, should be bifurcated and accounted for separately. This guidance clarifies that an entity does not have to separately assess whether the event that triggers the ability to exercise the contingent option is itself indexed only to interest rates or credit risk as part of the analysis of whether an embedded contingent option is clearly and closely related to the debt host. The guidance is effective for fiscal years beginning after December 15, 2016 and required to be adopted using a modified retrospective approach. We do not expect this guidance to have a material impact on our consolidated financial statements, including our disclosures.

Simplification of Employee Share-Based Payment Accounting

In March 2016, the FASB issued authoritative guidance that simplifies several aspects of the accounting for employee share-based payment transactions. The new guidance (1) requires that an entity recognize all excess tax benefits and tax deficiencies as income tax benefit or expense in the income statement, (2) allows an entity to elect as an accounting policy either to estimate forfeitures (as currently required) or account for forfeitures when they occur, (3) modifies the current exception to liability classification of an award when an employer uses a net-settlement feature to withhold shares to meet the employer’s minimum statutory tax withholding requirement to apply if the withholding amount does not exceed the maximum statutory tax rate and (4) specifies the statement of cash flow presentation for excess tax benefits and cash payments to taxing authorities when shares are withheld to meet tax withholding requirements. The new guidance is effective for annual periods beginning after December 15, 2017. Early adoption is permitted. The various amendments require different transition methods including modified-retrospective adoption through a cumulative effect adjustment to retained earnings, prospective adoption and retrospective adoption. We are currently assessing the impacts this guidance will have on our consolidated financial statements, including our disclosures.

3. REGULATORY MATTERS

MISO Funding Policy for Generator Interconnections

On June 18, 2015, FERC issued an order initiating a proceeding, pursuant to Section 206 of the Federal Power Act (“FPA”), to examine MISO’s funding policy for generator interconnections, which allows a transmission owner to unilaterally elect to fund network upgrades and recover such costs from the interconnection customer. In this order, FERC suggested the MISO funding policy be revised to require mutual agreement between the interconnection customer and transmission owner to utilize the election to fund network upgrades. On July 20, 2015, MISO and its transmission owners (“TOs”) filed a request for a rehearing of the FERC order to examine MISO’s funding policy for generator interconnections, which was subsequently denied by FERC on December 29, 2015. On January 8, 2016, MISO made a compliance filing to revise its funding policy to adopt the FERC suggestion to require mutual agreement between the customer and TO, with an effective date of June 24, 2015. On January 28, 2016, our MISO Regulated Operating Subsidiaries, together with several other utilities, filed a request with FERC for rehearing of certain aspects of the December 29, 2015 order. Additionally, on February 26, 2016, our MISO Regulated Operating Subsidiaries, along with Ameren Services Company, filed an appeal of certain aspects of the December 29, 2015 order. We do not expect the resolution of this proceeding to have a material impact on our consolidated results of operations, cash flows or financial condition.

MISO Formula Rate Template Modifications Filing

On October 30, 2015, our MISO Regulated Operating Subsidiaries requested modifications, pursuant to Section 205 of the FPA, to certain aspects of their respective formula rate templates which included, among other things, changes to ensure that various income tax items are computed correctly for purposes of determining their revenue requirements. Our MISO Regulated Operating Subsidiaries requested an effective date of January 1, 2016 for the proposed template changes. On December 30, 2015, the FERC conditionally accepted the formula rate template modifications and required a further compliance filing, which was made on February 8, 2016. On April 14, 2016, the FERC issued an order accepting the February 8, 2016 compliance filing, effective January 1, 2016. The formula rate templates, prior to any proposed modifications, include certain deferred income taxes on contributions in aid of construction in rate base that resulted in the joint applicants recovering excess amounts from customers. As of March 31, 2016 and December 31, 2015, our MISO Regulated Operating Subsidiaries had recorded an aggregate refund liability of $8.4 million and $10.4 million, respectively.

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Challenges Regarding Bonus Depreciation

On December 18, 2015, Interstate Power and Light Company (“IP&L”) filed a formal challenge (“IP&L challenge”) with the FERC against ITC Midwest on certain inputs to ITC Midwest’s formula rates. The IP&L challenge alleged that ITC Midwest has unreasonably and imprudently opted out of using bonus depreciation in the calculation of its federal income tax expense and thereby unduly increased the transmission charges for transmission service for customers. On March 11, 2016, the FERC granted the IP&L challenge in part by requiring ITC Midwest to recalculate its revenue requirements, effective January 1, 2015, to simulate the election of bonus depreciation for 2015. FERC denied IP&L’s request that ITC Midwest be required to elect bonus depreciation in any past or future years; however, stakeholders will be able to challenge any decision by ITC Midwest not to take bonus depreciation in future years. ITC Midwest has filed with the FERC for rehearing of the March 11, 2016 order. On April 15, 2016, Consumers Energy Company filed a formal challenge, or in the alternative, a complaint under Section 206 of the FPA, with the FERC against METC also relating to METC’s historical practice of opting out of using bonus depreciation.

Rate of Return on Equity Complaints

See “Rate of Return on Equity Complaints” in Note 10 for a discussion of the complaints.

Cost-Based Formula Rate Templates with True-Up Mechanism

The transmission revenue requirements at our Regulated Operating Subsidiaries are set annually, using FERC-approved formula rate templates (“formula rate templates”), and remain in effect for a one-year period. By completing their formula rate templates on an annual basis, our Regulated Operating Subsidiaries are able to make adjustments to reflect changing operational data and financial performance, including the amount of network load on their transmission systems (for our MISO Regulated Operating Subsidiaries), operating expenses and additions to property, plant and equipment when placed in service, among other items. The formula rate templates do not require further action or FERC filings each year although the template inputs remain subject to legal challenge at the FERC. Our Regulated Operating Subsidiaries will continue to use formula rate templates to calculate their respective annual revenue requirements unless the FERC determines any template to be unjust and unreasonable or another mechanism is determined by the FERC to be just and reasonable. See “Rate of Return on Equity Complaints” in Note 10 for detail on return on equity (“ROE”) matters including incentive adders approved by FERC in 2015.

Our formula rate templates include a true-up mechanism, whereby our Regulated Operating Subsidiaries compare their actual revenue requirements to their billed revenues for each year to determine any over- or under-collection of revenue requirements. Revenue is recognized for services provided during each reporting period based on actual revenue requirements calculated using the formula rate templates. Our Regulated Operating Subsidiaries accrue or defer revenues to the extent that the actual revenue requirement for the reporting period is higher or lower, respectively, than the amounts billed relating to that reporting period. The amount of accrued or deferred revenues is reflected in future revenue requirements and thus flows through to customer bills within two years under the provisions of the formula rate templates.

The net changes in regulatory assets and liabilities associated with our Regulated Operating Subsidiaries’ formula rate revenue accruals and deferrals, including accrued interest, were as follows during the three months ended March 31, 2016:



(in thousands)	Total
Net regulatory liability as of December 31, 2015	$	(2,564	)
Net refund of 2014 revenue deferrals and accruals, including accrued interest	5,594
Net revenue accrual for the three months ended March 31, 2016	11,199
Net accrued interest payable for the three months ended March 31, 2016	(212		)
Net regulatory asset as of March 31, 2016	$	14,017

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Regulatory assets and liabilities associated with our Regulated Operating Subsidiaries’ formula rate revenue accruals and deferrals, including accrued interest, are recorded in the condensed consolidated statements of financial position at March 31, 2016 as follows:



(in thousands)	Total
Current assets	$	16,937
Non-current assets	34,943
Current liabilities	(29,218		)
Non-current liabilities	(8,645		)
Net regulatory asset as of March 31, 2016	$	14,017

4. GOODWILL AND INTANGIBLE ASSETS

Goodwill

At March 31, 2016 and December 31, 2015, we had goodwill balances recorded at ITCTransmission, METC and ITC Midwest of $173.4 million, $453.8 million and $323.0 million, respectively, which resulted from the ITCTransmission acquisition, the METC acquisition and ITC Midwest’s asset acquisition, respectively.

Intangible Assets

We have recorded intangible assets as a result of the METC acquisition in 2006. The carrying value of these assets was $30.4 million and $31.2 million (net of accumulated amortization of $28.0 million and $27.2 million) as of March 31, 2016 and December 31, 2015, respectively.

We have also recorded intangible assets for payments made by and obligations of ITC Great Plains to certain TOs to acquire rights, which are required under the SPP tariff to designate ITC Great Plains to build, own and operate projects within the SPP region, including the KETA Project and the Kansas V-Plan Project. The carrying amount of these intangible assets was $14.5 million and $14.4 million (net of accumulated amortization of $1.1 million and $1.0 million) as of March 31, 2016 and December 31, 2015, respectively.

During each of the three month periods ended March 31, 2016 and 2015, we recognized $0.8 million of amortization expense of our intangible assets. For each of the next five years, we expect the annual amortization of our intangible assets that have been recorded as of March 31, 2016 to be $3.3 million per year.

5. DEBT

Derivative Instruments and Hedging Activities

We may use derivative financial instruments, including interest rate swap contracts, to manage our exposure to fluctuations in interest rates. The use of these financial instruments mitigates exposure to these risks and the variability of our operating results. We are not a party to leveraged derivatives and do not enter into derivative financial instruments for trading or speculative purposes. The interest rate swaps listed below manage interest rate risk associated with the forecasted future issuance of fixed-rate debt related to (1) the expected refinancing of the ITC Holdings 5.875% Senior Notes, due September 30, 2016 (“5.875% Senior Notes”) and (2) the expected financing required to repay the amount borrowed under ITC Holdings’ term loan credit agreement, due September 30, 2016 (“Term Loan”). As of March 31, 2016, ITC Holdings had $139.2 million and $160.9 million outstanding under the 5.875% Senior Notes and Term Loan, respectively.



Interest Rate Swaps	Notional Amount		Weighted Average Fixed Rate		Original Term	Effective Date
(Amounts in millions)
August 2014 swap	$	25.0	3.217	%	10 years	September 2016
October 2014 swap	25.0		3.075	%	10 years	September 2016
January 2015 swap	25.0		2.301	%	10 years	September 2016
February 2016 swaps	75.0		1.687	%	10 years	September 2016
March 2016 swap	50.0		1.743	%	10 years	September 2016
Total	$	200.0

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The 10-year term interest rate swaps call for ITC Holdings to receive interest quarterly at a variable rate equal to LIBOR and pay interest semi-annually at various fixed rates effective for the 10-year period beginning September 30, 2016 after the agreements have been terminated. The agreements include a mandatory early termination provision and will be terminated no later than the effective date of the interest rate swaps of September 30, 2016. The interest rate swaps have been determined to be highly effective at offsetting changes in the fair value of the forecasted interest cash flows associated with the expected debt issuance, resulting from changes in benchmark interest rates from the trade date of the interest rate swaps to the issuance date of the debt obligation.

As of March 31, 2016, there has been no material ineffectiveness recorded in the condensed consolidated statement of operations. The interest rate swaps qualify for hedge accounting treatment, whereby any gain or loss recognized from the trade date to the effective date for the effective portion of the hedge is recorded net of tax in accumulated other comprehensive income (“AOCI”). This amount will be accumulated and amortized as a component of interest expense over the life of the related forecasted debt issuance. As of March 31, 2016, the fair value of the derivative instruments was an asset of $0.4 million recorded to other current assets and a liability of $8.2 million recorded to other current liabilities. None of the interest rate swaps contain credit-risk-related contingent features. Refer to Note 9 for additional fair value information.

METC

On April 26, 2016, METC issued $200.0 million of 3.90% Senior Secured Notes, due April 26, 2046. The proceeds will be used to repay the $200.0 million borrowed under METC’s term loan credit agreement. The METC Senior Secured Notes were issued under its first mortgage indenture and secured by a first mortgage lien on substantially all of its real property and tangible personal property.

ITC Holdings

ITC Holdings has an ongoing commercial paper program for the issuance and sale of unsecured commercial paper in an aggregate amount not to exceed $400.0 million outstanding at any one time. As of March 31, 2016, ITC Holdings had approximately $307.0 million of commercial paper issued and outstanding under the program, with a weighted-average interest rate of 0.8% and weighted average remaining days to maturity of 19 days. The proceeds from the issuances under the program were used for general corporate purposes, including the repayment of borrowings under ITC Holdings’ revolving credit agreement. The amount outstanding as of March 31, 2016 was classified as debt maturing within one year in the condensed consolidated statements of financial position.

Revolving Credit Agreements

At March 31, 2016, ITC Holdings and its Regulated Operating Subsidiaries had the following unsecured revolving credit facilities available:



(amounts in millions)	Total Available Capacity		Outstanding Balance (a)		Unused Capacity			Weighted Average Interest Rate on Outstanding Balance		Commitment Fee Rate (b)
ITC Holdings	$	400.0	$	7.0	$	393.0	(c)	1.6%	(d)	0.175	%
ITCTransmission	100.0		61.1		38.9			1.4%	(e)	0.10	%
METC	100.0		12.4		87.6			1.4%	(e)	0.10	%
ITC Midwest	250.0		90.8		159.2			1.4%	(e)	0.10	%
ITC Great Plains	150.0		61.5		88.5			1.4%	(e)	0.10	%
Total	$	1,000.0	$	232.8	$	767.2

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(a)	Included within long-term debt.


(b)	Calculation based on the average daily unused commitments, subject to adjustment based on the borrower’s credit rating.

(c)

ITC Holdings’ revolving credit agreement may be used for general corporate purposes, including to repay commercial paper issued pursuant to the commercial paper program described above, if necessary. While outstanding commercial paper does not reduce available capacity under ITC Holdings’ revolving credit agreement, the unused capacity under this agreement adjusted for the commercial paper outstanding was $86.0 million as of March 31, 2016.

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(d)	Loan bears interest at a rate equal to LIBOR plus an applicable margin of 1.25% or at a base rate, which is defined as the higher of the prime rate, 0.50% above the federal funds rate or 1.00% above the one month LIBOR, plus an applicable margin of 0.25%, subject to adjustments based on ITC Holdings’ credit rating.


(e)	Loans bear interest at a rate equal to LIBOR plus an applicable margin of 1.00% or at a base rate, which is defined as the higher of the prime rate, 0.50% above the federal funds rate or 1.00% above the one month LIBOR, subject to adjustments based on the borrower’s credit rating.

On April 7, 2016, each of ITC Holdings and its Regulated Operating Subsidiaries amended its respective unsecured revolving credit agreement to allow for the consummation of the Merger (defined below in Note 11).

Covenants

Our debt instruments contain numerous financial and operating covenants that place significant restrictions on certain transactions, such as incurring additional indebtedness, engaging in sale and lease-back transactions, creating liens or other encumbrances, entering into mergers, consolidations, liquidations or dissolutions, creating or acquiring subsidiaries, selling or otherwise disposing of all or substantially all of our assets and paying dividends. In addition, the covenants require us to meet certain financial ratios, such as maintaining certain debt to capitalization ratios and maintaining certain interest coverage ratios. As of March 31, 2016, we were not in violation of any debt covenant.

6. STOCKHOLDERS’ EQUITY

The changes in stockholders’ equity for the three months ended March 31, 2016 were as follows:



									Accumulated
									Other			Total
	Common Stock					Retained			Comprehensive			Stockholders’
(in thousands, except share and per share data)	Shares		Amount			Earnings			Income (Loss)			Equity
BALANCE, DECEMBER 31, 2015	152,699,077		$	829,211		$	875,595		$	4,265		$	1,709,071
Net income	—		—			64,237			—			64,237
Repurchase and retirement of common stock	(28,875	)	(1,176		)	—			—			(1,176		)
Dividends declared ($0.1875 per share)	—		—			(28,634		)	—			(28,634		)
Stock option exercises	84,006		1,847			—			—			1,847
Shares issued under the Employee Stock Purchase Plan	23,276		647			—			—			647
Issuance of restricted stock	3,896		—			—			—			—
Forfeiture of restricted stock	(11,737	)	—			—			—			—
Forfeiture of performance shares	(3,626	)	—			—			—			—
Share-based compensation, net of forfeitures	—		4,933			—			—			4,933
Other comprehensive loss, net of tax	—		—			—			(2,162		)	(2,162		)
Other	—		51			—			—			51
BALANCE, MARCH 31, 2016	152,766,017		$	835,513		$	911,198		$	2,103		$	1,748,814

The changes in stockholders’ equity for the three months ended March 31, 2015 were as follows:



									Accumulated
									Other			Total
	Common Stock					Retained			Comprehensive			Stockholders’
(in thousands, except share and per share data)	Shares		Amount			Earnings			Income (Loss)			Equity
BALANCE, DECEMBER 31, 2014	155,140,967		$	923,191		$	741,550		$	4,816		$	1,669,557
Net income	—		—			67,132			—			67,132
Repurchase and retirement of common stock	(11,917	)	(476		)	—			—			(476		)
Dividends declared on common stock ($0.1625 per share)	—		—			(25,220		)	—			(25,220		)
Stock option exercises	37,495		665			—			—			665
Shares issued under the Employee Stock Purchase Plan	17,267		581			—			—			581
Issuance of restricted stock	27,776		—			—			—			—
Forfeiture of restricted stock	(13,772	)	—			—			—			—
Share-based compensation, net of forfeitures	—		3,853			—			—			3,853
Other comprehensive loss, net of tax	—		—			—			(621		)	(621		)
BALANCE, MARCH 31, 2015	155,197,816		$	927,814		$	783,462		$	4,195		$	1,715,471

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Accumulated Other Comprehensive Income

The following table provides the components of changes in AOCI for the three months ended March 31, 2016 and 2015:



	Three months ended
	March 31,
(in thousands)	2016			2015
Balance at the beginning of period	$	4,265		$	4,816
Derivative instruments
Reclassification of net loss relating to interest rate cash flow hedges from AOCI to interest expense — net (net of tax of $92 and $75 for the three months ended March 31, 2016 and 2015, respectively)	119			136
Loss on interest rate swaps relating to interest rate cash flow hedges (net of tax of $1,823 and $614 for the three months ended March 31, 2016 and 2015, respectively)	(2,542		)	(863		)
Derivative instruments, net of tax	(2,423		)	(727		)
Available-for-sale securities
Unrealized net gain on available-for-sale securities (net of tax of $187 and $76 for the three months ended March 31, 2016 and 2015, respectively)	261			106
Available-for-sale securities, net of tax	261			106
Total other comprehensive loss, net of tax	(2,162		)	(621		)
Balance at the end of period	$	2,103		$	4,195

The amount of net loss relating to interest rate cash flow hedges to be reclassified from AOCI to interest expense for the 12-month period ending March 31, 2017 is not expected to be material.

7. EARNINGS PER SHARE

We report both basic and diluted EPS. Our restricted stock contain rights to receive nonforfeitable dividends and thus, are participating securities requiring the two-class method of computing EPS. A reconciliation of both calculations for the three months ended March 31, 2016 and 2015 is presented in the following table:



	Three months ended
	March 31,
(in thousands, except share, per share data and percentages)	2016			2015
Numerator:
Net income	$	64,237		$	67,132
Less: dividends declared and paid — common and restricted shares	(28,585		)	(25,220		)
Undistributed earnings	35,652			41,912
Percentage allocated to common shares (a)	99.4		%	99.2		%
Undistributed earnings — common shares	35,438			41,577
Add: dividends declared and paid — common shares	28,403			25,024
Numerator for basic and diluted earnings per common share	$	63,841		$	66,601
Denominator:
Basic earnings per common share — weighted average common shares outstanding	151,460,490			153,970,515
Incremental shares for stock options, employee stock purchase plan shares and performance shares — weighted average assumed conversion	1,012,299			1,444,202
Diluted earnings per common share — adjusted weighted average shares and assumed conversion	152,472,789			155,414,717
Per common share net income:
Basic	$	0.42		$	0.43
Diluted	$	0.42		$	0.43

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(a)	Weighted average common shares outstanding	151,460,490		153,970,515
	Weighted average restricted shares (participating securities)	982,640		1,209,468
	Total	152,443,130		155,179,983
	Percentage allocated to common shares	99.4	%	99.2	%

The incremental shares for stock options and employee stock purchase plan (“ESPP”) shares are included in the diluted EPS calculation using the treasury stock method, unless the effect of including them would be anti-dilutive. Additionally, performance shares are included in the diluted EPS calculation using the treasury stock method when the performance metric is substantively measurable as of the end of the reporting period and has been met under the assumption the end of the reporting period was the end of the performance period. The outstanding stock options, ESPP shares and performance shares and the anti-dilutive stock options and ESPP shares excluded from the diluted EPS calculations were as follows:



	2016	2015
Outstanding stock options, ESPP shares and performance shares (as of March 31)	4,004,003	4,553,938
Anti-dilutive stock options and ESPP shares (for the three months ended March 31)	524,834	542,312

8. RETIREMENT BENEFITS AND ASSETS HELD IN TRUST

Pension Plan Benefits

We have a qualified defined benefit pension plan (“retirement plan”) for eligible employees, comprised of a traditional final average pay plan and a cash balance plan. The traditional final average pay plan is noncontributory, covers select employees, and provides retirement benefits based on years of benefit service, average final compensation and age at retirement. The cash balance plan is also noncontributory, covers substantially all employees and provides retirement benefits based on eligible compensation and interest credits. Our funding practice for the retirement plan is to contribute amounts necessary to meet the minimum funding requirements of the Employee Retirement Income Security Act of 1974, plus additional amounts as we determine appropriate. We expect to contribute $2.8 million to the retirement plan in 2016.

We also have two supplemental nonqualified, noncontributory, defined benefit pension plans for selected management employees (the “supplemental benefit plans” and collectively with the retirement plan, the “pension plans”). The supplemental benefit plans provide for benefits that supplement those provided by the retirement plan. We expect to contribute $5.2 million to the supplemental benefit plans in 2016.

Net periodic benefit cost for the pension plans, by component, was as follows for the three months ended March 31, 2016 and 2015:



	Three months ended
	March 31,
(in thousands)	2016			2015
Service cost	$	1,604		$	1,624
Interest cost	872			924
Expected return on plan assets	(932		)	(960		)
Amortization of prior service credit	(4		)	(10		)
Amortization of unrecognized loss	876			1,061
Net pension cost	$	2,416		$	2,639

Other Postretirement Benefits

We provide certain postretirement health care, dental and life insurance benefits for eligible employees. We expect to contribute $7.4 million to the plan in 2016.

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Net postretirement benefit plan cost, by component, was as follows for the three months ended March 31, 2016 and 2015:



	Three months ended
	March 31,
(in thousands)	2016			2015
Service cost	$	1,855		$	2,122
Interest cost	630			619
Expected return on plan assets	(530		)	(463		)
Amortization of unrecognized loss	—			125
Net postretirement cost	$	1,955		$	2,403

Defined Contribution Plan

We also sponsor a defined contribution retirement savings plan. Participation in this plan is available to substantially all employees. We match employee contributions up to certain predefined limits based upon eligible compensation and the employee’s contribution rate. The cost of this plan was $1.6 million and $1.5 million for the three months ended March 31, 2016 and 2015, respectively.

9. FAIR VALUE MEASUREMENTS

The measurement of fair value is based on a three-tier hierarchy, which prioritizes the inputs used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. Changes in economic conditions or model-based valuation techniques may require the transfer of financial instruments from one fair value level to another. In such instances, the transfer is reported at the beginning of the reporting period. For the three months ended March 31, 2016 and the year ended December 31, 2015, there were no transfers between levels.

Our assets and liabilities measured at fair value subject to the three-tier hierarchy at March 31, 2016, were as follows:



	Fair Value Measurements at Reporting Date Using
	Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs			Significant Unobservable Inputs
(in thousands)	(Level 1)		(Level 2)			(Level 3)
Financial assets measured on a recurring basis:
Cash and cash equivalents — cash equivalents	$	15	$	—		$	—
Mutual funds — fixed income securities	36,357		—			—
Mutual funds — equity securities	1,069		—			—
Interest rate swap derivatives	—		359			—
Financial liabilities measured on a recurring basis:
Interest rate swap derivatives	—		(8,160		)	—
Total	$	37,441	$	(7,801	)	$	—

Our assets and liabilities measured at fair value subject to the three-tier hierarchy at December 31, 2015, were as follows:



	Fair Value Measurements at Reporting Date Using
	Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs			Significant Unobservable Inputs
(in thousands)	(Level 1)		(Level 2)			(Level 3)
Financial assets measured on a recurring basis:
Cash and cash equivalents — cash equivalents	$	49	$	—		$	—
Mutual funds — fixed income securities	35,813		—			—
Mutual funds — equity securities	976		—			—
Interest rate swap derivative	—		112			—
Financial liabilities measured on a recurring basis:
Interest rate swap derivatives	—		(3,548		)	—
Total	$	36,838	$	(3,436	)	$	—

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As of March 31, 2016 and December 31, 2015, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis. The assets included in the table consist of investments recorded within cash and cash equivalents and other long-term assets, including investments held in a trust associated with our supplemental nonqualified, noncontributory, retirement benefit plans for selected management employees. Our cash and cash equivalents consist of money market funds that are recorded at cost plus accrued interest to approximate fair value. Our mutual funds consist of publicly traded mutual funds and are recorded at fair value based on observable trades for identical securities in an active market. Changes in the observed trading prices and liquidity of money market funds are monitored as additional support for determining fair value. Gain and losses are recorded in earnings for investments classified as trading securities and other comprehensive income for investments classified as available-for-sale.

The asset and liability related to derivatives consist of interest rate swaps as discussed in Note 5. The fair value of our interest rate swap derivatives is determined based on a discounted cash flow (“DCF”) method using LIBOR swap rates, which are observable at commonly quoted intervals.

We also held non-financial assets that are required to be measured at fair value on a non-recurring basis. These consist of goodwill and intangible assets. We did not record any impairment charges on long-lived assets and no other significant events occurred requiring non-financial assets and liabilities to be measured at fair value (subsequent to initial recognition) during the three months ended March 31, 2016. For additional information on our goodwill and intangible assets, please refer to the notes to the consolidated financial statements as of and for the year ended December 31, 2015 included in our Form 10-K for such period and to Note 4 of this Form 10-Q.

Fair Value of Financial Assets and Liabilities

Fixed Rate Debt

Based on the borrowing rates obtained from third party lending institutions currently available for bank loans with similar terms and average maturities from active markets, the fair value of our consolidated long-term debt and debt maturing within one year, excluding revolving and term loan credit agreements and commercial paper, was $3,951.5 million and $3,879.7 million at March 31, 2016 and December 31, 2015, respectively. These fair values represent Level 2 measurements under the three-tier hierarchy described above. The total book value of our consolidated long-term debt and debt maturing within one year, net of discount and deferred financing fees and excluding revolving and term loan credit agreements and commercial paper, was $3,654.4 million and $3,653.6 million at March 31, 2016 and December 31, 2015, respectively.

Revolving and Term Loan Credit Agreements

At March 31, 2016 and December 31, 2015, we had a consolidated total of $593.8 million and $680.9 million, respectively, outstanding under our revolving and term loan credit agreements, which are variable rate loans. The fair value of these loans approximates book value based on the borrowing rates currently available for variable rate loans obtained from third party lending institutions. These fair values represent Level 2 under the three-tier hierarchy described above.

Other Financial Instruments

The carrying value of other financial instruments included in current assets and current liabilities, including cash and cash equivalents, special deposits and commercial paper, approximates their fair value due to the short-term nature of these instruments.

10. COMMITMENTS AND CONTINGENT LIABILITIES

Environmental Matters

We are subject to federal, state and local environmental laws and regulations, which impose limitations on the discharge of pollutants into the environment, establish standards for the management, treatment, storage, transportation and disposal of solid and hazardous wastes and hazardous materials, and impose obligations to investigate and remediate contamination in certain circumstances. Liabilities relating to investigation and remediation of contamination, as well as other liabilities concerning hazardous materials or contamination, such as claims for personal injury or property damage, may arise at many locations, including formerly owned or operated properties and sites where wastes have been treated or disposed of, as well as properties currently owned or operated by us. Such liabilities may arise even where the contamination does not result from noncompliance with applicable environmental laws. Under some environmental laws, such liabilities may also be joint and several, meaning that a party can be held responsible for more than its share of the liability involved, or even the entire share.

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Although environmental requirements generally have become more stringent and compliance with those requirements more expensive, we are not aware of any specific developments that would increase our costs for such compliance in a manner that would be expected to have a material adverse effect on our results of operations, financial position or liquidity.

Our assets and operations also involve the use of materials classified as hazardous, toxic or otherwise dangerous. Many of the properties that we own or operate have been used for many years, and include older facilities and equipment that may be more likely than newer ones to contain or be made from such materials. Some of these properties include aboveground or underground storage tanks and associated piping. Some of them also include large electrical equipment filled with mineral oil, which may contain or previously have contained PCBs. Our facilities and equipment are often situated on or near property owned by others so that, if they are the source of contamination, others’ property may be affected. For example, aboveground and underground transmission lines sometimes traverse properties that we do not own and transmission assets that we own or operate are sometimes commingled at our transmission stations with distribution assets owned or operated by our transmission customers.

Some properties in which we have an ownership interest or at which we operate are, or are suspected of being, affected by environmental contamination. We are not aware of any pending or threatened claims against us with respect to environmental contamination relating to these properties, or of any investigation or remediation of contamination at these properties, that entail costs likely to materially affect us. Some facilities and properties are located near environmentally sensitive areas such as wetlands.

Claims have been made or threatened against electric utilities for bodily injury, disease or other damages allegedly related to exposure to electromagnetic fields associated with electric transmission and distribution lines. While we do not believe that a causal link between electromagnetic field exposure and injury has been generally established and accepted in the scientific community, the liabilities and costs imposed on our business could be significant if such a relationship is established or accepted. We are not aware of any pending or threatened claims against us for bodily injury, disease or other damages allegedly related to exposure to electromagnetic fields and electric transmission and distribution lines that entail costs likely to have a material adverse effect on our results of operations, financial position or liquidity.

Litigation

We are involved in certain legal proceedings before various courts, governmental agencies and mediation panels concerning matters arising in the ordinary course of business. These proceedings include certain contract disputes, eminent domain and vegetation management activities, regulatory matters and pending judicial matters. We cannot predict the final disposition of such proceedings. We regularly review legal matters and record provisions for claims that are considered probable of loss.

Michigan Sales and Use Tax Audit

The Michigan Department of Treasury has conducted sales and use tax audits of ITCTransmission for the audit periods April 1, 2005 through June 30, 2008 and October 1, 2009 through September 30, 2013. The Michigan Department of Treasury has denied ITCTransmission’s claims of the industrial processing exemption from use tax that it has taken beginning January 1, 2007. The exemption claim denials resulted in use tax assessments against ITCTransmission. ITCTransmission filed administrative appeals to contest these use tax assessments.

In a separate, but related case involving a Michigan-based public utility that made similar industrial processing exemption claims, the Michigan Supreme Court ruled in July 2015 that the electric system, which involves altering voltage, constitutes an exempt, industrial processing activity. However, the ruling further held the electric system is also used for other functions that would not be exempt, and remanded the case to the Michigan Court of Claims to determine how the exemption applies to assets that are used in electric distribution activities. ITCTransmission is assessing the recent ruling in light of its specific facts, but cannot estimate the timing of any potential tax assessments or refunds.

The amount of use tax associated with the exemptions taken by ITCTransmission through March 31, 2016 is estimated to be approximately $18.6 million including interest. This amount includes approximately $10.4 million, including interest, assessed for the audit periods noted above. ITCTransmission believes it is probable that portions of the use tax assessments could be sustained upon resolution of this matter. ITCTransmission has recorded $8.8 million and $5.9 million for this contingent liability, including interest, as of March 31, 2016 and December 31, 2015, respectively, primarily as an increase to property, plant and equipment, which is a component of revenue requirement in our cost-based formula rate.

METC has also taken the industrial processing exemption, estimated to be approximately $10.4 million for periods still subject to audit. METC has not been assessed any use tax liability and has not recorded any contingent liability as of March 31,

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2016 associated with this matter. In the event it becomes appropriate to record additional use tax liability relating to this matter, ITCTransmission and METC would record the additional use tax primarily as an increase to the cost of property, plant and equipment, as the majority of purchases for which the exemption was taken relate to equipment purchases associated with capital projects.

Rate of Return on Equity Complaints

On November 12, 2013, the Association of Businesses Advocating Tariff Equity, Coalition of MISO Transmission Customers, Illinois Industrial Energy Consumers, Indiana Industrial Energy Consumers, Inc., Minnesota Large Industrial Group and Wisconsin Industrial Energy Group (collectively, the “complainants”) filed a complaint with the FERC under Section 206 of the FPA (the “Initial Complaint”), requesting that the FERC find the current 12.38% MISO regional base ROE rate (the “base ROE”) for all MISO TOs, including ITCTransmission, METC and ITC Midwest, to no longer be just and reasonable. The complainants sought a FERC order reducing the base ROE used in our MISO Regulated Operating Subsidiaries’ formula transmission rates to 9.15%. The Initial Complaint also alleged that the rates of any MISO TO using a capital structure with greater than 50% for the equity component are likewise not just and reasonable (our MISO Regulated Operating Subsidiaries use their actual capital structures, which target 60% equity, as FERC had previously authorized). The Initial Complaint also alleged the ROE adders currently approved for certain ITC Holdings operating companies, including an adder currently charged by ITCTransmission for being a member of an RTO and adders charged by ITCTransmission and METC for being independent TOs, are no longer just and reasonable, and sought to have them eliminated.

On June 19, 2014, in a separate Section 206 complaint against the regional base ROE rate for ISO New England TOs, FERC adopted a new methodology for establishing base ROE rates for electric transmission utilities. The new methodology is based on a two-step DCF analysis that uses both short-term and long-term growth projections in calculating ROE rates for a proxy group of electric utilities. The previous methodology used only short-term growth projections. FERC also reiterated that it can apply discretion in determining how ROE rates are established within a zone of reasonableness and reiterated its policy for limiting the overall ROE rate for any company, including the base and all applicable adders, at the high end of the zone of reasonableness set by the two-step DCF methodology. The new method presented in the ISO New England ROE case will be used in resolving the MISO ROE case.

On October 16, 2014, FERC granted the complainants’ request in part by setting the base ROE for hearing and settlement procedures, while denying all other aspects of the Initial Complaint. FERC found that the complainants failed to show that the use of actual or FERC-approved capital structures that include more than 50% equity is unjust and unreasonable. FERC also denied the request to terminate ITCTransmission’s and METC’s ROE incentives. The order reiterated that any TO’s total ROE rate is limited by the top end of a zone of reasonableness and the TO’s ability to implement the full amount of previously granted ROE adders may be affected by the outcome of the hearing. FERC set the refund effective date as November 12, 2013.

During the fourth quarter of 2014, the MISO TOs engaged in the ordered FERC settlement procedures with the complainants, but were not able to reach resolution. On January 5, 2015, the Chief Judge of FERC issued an order which terminated settlement procedures and initiated the hearing process, with an initial decision due within 47 weeks of the order. On April 6, 2015, the MISO TOs filed expert witness testimony in the Initial Complaint proceeding supporting the existing base ROE as just and reasonable. However, in the event that FERC elects to change the base ROE, the testimony included a recommendation of 11.39% base ROE for the period of November 12, 2013 through February 11, 2015 (the “Initial Refund Period”). On December 22, 2015, the presiding administrative law judge issued an initial decision on the Initial Complaint, which recommended a base ROE of 10.32% for the Initial Refund Period, with a maximum ROE of 11.35%. The initial decision is a non-binding recommendation to FERC on the Initial Complaint, and exceptions to the initial decision have been filed by the MISO TOs and the complainants. In resolving the Initial Complaint, we expect FERC to establish a new base ROE and zone of reasonable returns that will be used to determine any potential refund liability for the Initial Refund Period. The new base ROE as well as any ROE adders, subject to the limitations of the top end of any zone of reasonableness that is established, are expected to be used to calculate the refund liability for the Initial Refund Period. We anticipate a FERC order on the Initial Complaint by the end of 2016.

On February 12, 2015, an additional complaint was filed with the FERC under Section 206 of the FPA (the “Second Complaint”) by Arkansas Electric Cooperative Corporation, Mississippi Delta Energy Agency, Clarksdale Public Utilities Commission, Public Service Commission of Yazoo City and Hoosier Energy Rural Electric Cooperative, Inc., seeking a FERC order to reduce the base ROE used in our MISO Regulated Operating Subsidiaries’ formula transmission rates to 8.67%, with an effective date of February 12, 2015. On March 11, 2015, the MISO TOs filed an answer to the Second Complaint with the FERC supporting the current base ROE as just and reasonable. On June 18, 2015, FERC accepted the Second Complaint and

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set it for hearing and settlement procedures. FERC also set the refund effective date for the Second Complaint as February 12, 2015.

On October 20, 2015, the MISO TOs filed expert witness testimony in the Second Complaint proceeding supporting the existing base ROE as just and reasonable. However, in the event that FERC elects to change the base ROE, the testimony included a recommendation of 10.75% base ROE for the period of February 12, 2015 through May 11, 2016 (the “Second Refund Period”). Updated data to be considered in establishing any new base ROE was filed by the parties to the Second Complaint in January 2016, including a recommendation in the updated MISO TO expert witness testimony to use a 10.96% base ROE. In resolving the Second Complaint, we expect FERC to establish a new base ROE and zone of reasonable returns that will be used, along with any adders, to calculate the refund liability for the Second Refund Period. The initial decision on the Second Complaint is expected by June 30, 2016, with the related FERC order anticipated in 2017.

We believe it is probable that refunds will be required for these matters and as of March 31, 2016, the estimated range of refunds on a pre-tax basis is expected to be from $186.9 million to $242.3 million for the period from November 12, 2013 through March 31, 2016. As of March 31, 2016 and December 31, 2015, our MISO Regulated Operating Subsidiaries had recorded an aggregate estimated regulatory liability of $186.9 million and $168.0 million, respectively, representing the low end of the range of potential refunds as of those dates, as there is no best estimate within the range of refunds. The recognition of this estimated liability resulted in a reduction in revenues of $17.5 million and $7.5 million and an increase in interest expense of $1.4 million and $0.4 million for the three months ended March 31, 2016 and 2015, respectively. This resulted in an estimated after-tax reduction to net income of $11.5 million and $4.8 million for the three months ended March 31, 2016 and 2015, respectively.

Based on the estimated range of refunds identified above, we believe that it is reasonably possible that these matters could result in an additional estimated pre-tax refund of up to $55.4 million (or a $34.0 million estimated after-tax reduction of net income) in excess of the amount recorded as of March 31, 2016. It is also possible the outcome of these matters could differ from the estimated range of losses and materially affect our consolidated results of operations due to the uncertainty of the calculation of an authorized base ROE along with the zone of reasonableness under the newly adopted two-step DCF methodology, which is subject to significant discretion by the FERC. As of March 31, 2016, our MISO Regulated Operating Subsidiaries had a total of approximately $3.0 billion of equity in their collective capital structures for ratemaking purposes. Based on this level of aggregate equity, we estimate that each 10 basis point reduction in the authorized ROE would reduce annual consolidated net income by approximately $3.0 million.

In a separate but related matter, in November 2014, METC, ITC Midwest and other MISO TOs filed a request with FERC, under FPA Section 205, for authority to include a 50 basis point incentive adder for RTO participation in each of the TOs’ formula rates. On January 5, 2015, FERC approved the use of this incentive adder, effective January 6, 2015. Additionally, ITC Midwest filed a request with FERC, under FPA Section 205, in January 2015 for authority to include a 100 basis point incentive adder for independent transmission ownership, which is currently authorized for ITCTransmission and METC. On March 31, 2015, FERC approved the use of a 50 basis point incentive adder for independence, effective April 1, 2015. On April 30, 2015, ITC Midwest filed a request with FERC for rehearing on the approved incentive adder for independence and this request was subsequently denied by FERC on January 6, 2016. An appeal of FERC’s decision has been filed. The RTO participation incentive adder will be applied to METC’s and ITC Midwest’s base ROEs and the independence incentive adder will be applied to ITC Midwest’s base ROE in establishing their total authorized ROE rates, subject to the limitations of the top end of any zone of reasonableness that is established. Collection of these recently approved incentive adders is being deferred, pending the outcome of the ROE complaints.

Challenges Regarding Bonus Depreciation

See “Challenges Regarding Bonus Depreciation” in Note 3 for discussion of these challenges.

Legal Matters Associated with Proposed Merger

Following the announcement of the Merger (defined below in Note 11), four putative state class action lawsuits have been filed by purported shareholders of ITC Holdings on behalf of a purported class of ITC Holdings shareholders. Initially, the four actions (Paolo Guerra v. Albert Ernst, et al., Harvey Siegelman v. Joseph L. Welch, et al., Alan Poland v. Fortis Inc., et al., Sanjiv Mehrotra v. Joseph L. Welch, et al.) were filed in the Oakland County Circuit Court of the State of Michigan. The complaints name as defendants a combination of ITC Holdings and the individual members of the ITC Holdings board of directors, Fortis Inc. (“Fortis”), FortisUS Inc. (“FortisUS”) and Element Acquisition Sub Inc. (“Merger Sub”). The complaints generally allege, among other things, that (1) ITC Holdings’ directors breached their fiduciary duties in connection with the Merger Agreement (defined below in Note 11), (including, but not limited to, various alleged breaches of duties of good faith,

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loyalty, care and independence), (2) ITC Holdings’ directors failed to take appropriate steps to maximize shareholder value and claims that the Merger Agreement contains several deal protection provisions that are unnecessarily preclusive and (3) a combination of ITC Holdings, Fortis, FortisUS and Merger Sub aided and abetted the purported breaches of fiduciary duties. The complaints seek class action certification and a variety of relief including, among other things, enjoining defendants from completing the proposed Merger, unspecified rescissory and compensatory damages, and costs, including attorneys’ fees and expenses. The Siegelman case was voluntarily dismissed by the plaintiff on March 22, 2016. On March 23, 2016, the state court entered an order directing that the related cases be consolidated under the caption In re ITC Holdings Corporation Shareholder Litigation. On April 8, 2016, Poland filed an amended complaint to add derivative claims on behalf of ITC Holdings.

On March 14, 2016, the Guerra state court action was dismissed by the plaintiff and refiled in the United States District Court, Eastern District of Michigan, as Paolo Guerra v. Albert Ernst, et al. The federal complaint names the same defendants (plus FortisUS), asserts the same general allegations and seeks the same types of relief as in the state court cases. On March 25, 2016, Guerra amended his federal complaint. The amended complaint dropped Fortis US, Fortis and Merger Sub as defendants and added claims alleging that the defendants violated Sections 14(a) and 20(a) of the Exchange Act because the preliminary proxy statement/prospectus, filed with the SEC in connection with the special meeting of shareholders to approve the Merger Agreement, is allegedly materially misleading and allegedly omits material facts that are necessary to render it non-misleading.

Another lawsuit was filed on April 8, 2016 in the United States District Court, Eastern District of Michigan captioned Harold Severance v. Joseph L. Welch et al. against the individual members of the ITC Holdings board of directors, Fortis, FortisUS and Merger Sub, asserting the same general allegations and seeking the same type of relief as Guerra.

On April 22, 2016, the Mehrotra state court action was dismissed by the plaintiff and refiled in the United States District Court, Eastern District of Michigan, as Sanjiv Mehrotra v. Joseph L. Welch, et al. With the exception of Fortis, the federal complaint names the same defendants and asserts the same general allegations as the other federal complaints.

We believe the lawsuits are without merit and intend to vigorously defend against them. Additional lawsuits arising out of or relating to the Merger Agreement or the Merger may be filed in the future. See Note 11 for additional discussion on the proposed Merger.

11. PROPOSED MERGER

On February 9, 2016, Fortis, FortisUS, Merger Sub and ITC Holdings entered into an agreement and plan of merger (the “Merger Agreement”), pursuant to which Merger Sub will merge with and into ITC Holdings, as a result of which ITC Holdings will become a subsidiary of FortisUS (the “Merger”). In the Merger, our shareholders will receive $22.57 in cash and 0.7520 Fortis common shares for each share of common stock of ITC Holdings. Upon completion of the Merger, ITC Holdings shareholders will hold approximately 27% of the common shares of Fortis. Fortis will apply to list its common shares on the New York Stock Exchange and will continue to have its shares listed on the Toronto Stock Exchange.

On April 20, 2016, FortisUS assigned its rights, interest, duties and obligations under the Merger Agreement to ITC Investment Holdings Inc. (“Investment Holdings”), a subsidiary of FortisUS formed to complete the Merger. On the same date, Fortis reached a definitive agreement with GIC Private Limited to acquire an indirect 19.9% equity interest in ITC Holdings and debt securities to be issued by Investment Holdings for aggregate consideration of $1.228 billion in cash upon completion of the Merger.

The closing of the Merger, expected to occur in late 2016, is subject to approval by ITC Holdings’ shareholders and the shareholders of Fortis, the satisfaction of other customary closing conditions and certain regulatory, state and federal approvals including, among others, those of the FERC, the Committee on Foreign Investment in the U.S., the U.S. Federal Trade Commission, the U.S. Department of Justice and various state utilities regulators. Many of these conditions are outside our control, and we cannot provide any assurance as to whether or when the Merger will be consummated or whether our shareholders will realize the anticipated benefits of completing the Merger. Also, if the Merger does not receive timely regulatory approval or if an event occurs that delays or prevents the Merger, such delay or failure to complete the Merger may cause uncertainty and other negative consequences that may materially and adversely affect our business, financial position and results of operations.

The Merger Agreement contains certain termination rights, including the right of ITC Holdings to terminate the Merger Agreement to accept a superior proposal (subject to compliance with certain notice and other requirements). In addition, subject to certain exceptions and limitations, ITC Holdings or Fortis may terminate the Merger Agreement if the Merger is not consummated by February 9, 2017 (as such date may be extended pursuant to the terms of the Merger Agreement). The

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Merger Agreement provides that, in connection with termination of the Merger Agreement by ITC Holdings or Fortis upon specified conditions, a termination fee of $245 million may be required to be paid by ITC Holdings or Fortis. If the Merger Agreement is terminated as a result of the failure to obtain certain regulatory approvals or due to a legal prohibition related to regulatory matters, a termination fee of $280 million will be payable by Fortis to ITC Holdings, subject to certain limitations.

For the three months ended March 31, 2016, we expensed external legal, advisory and financial services fees related to the Merger of $9.9 million and certain internal labor and associated costs related to the Merger of approximately $3.1 million. The external and internal costs related to the Merger will not be included as components of revenue requirement at our Regulated Operating Subsidiaries as they were incurred at ITC Holdings.

Per the Merger Agreement, prior to completion of the Merger, there are certain restrictions on our ability to pay dividends other than those paid in the ordinary course of business with record dates and payment dates consistent with our past practice. Management does not expect the restrictions to have an impact on our ability to pay dividends at the current level for the foreseeable future.

See Note 10 for legal matters associated with the proposed Merger with Fortis.

12. SEGMENT INFORMATION

We identify reportable segments based on the criteria set forth by the FASB regarding disclosures about segments of an enterprise, including the regulatory environment of our subsidiaries and the business activities performed to earn revenues and incur expenses. The following tables show our financial information by reportable segment:



	Three months ended
OPERATING REVENUES:	March 31,
(in thousands)	2016			2015
Regulated Operating Subsidiaries	$	280,016		$	272,450
ITC Holdings and other	307			177
Intercompany eliminations	(190		)	(140		)
Total Operating Revenues	$	280,133		$	272,487



	Three months ended
INCOME BEFORE INCOME TAXES:	March 31,
(in thousands)	2016			2015
Regulated Operating Subsidiaries	$	152,787		$	148,818
ITC Holdings and other	(48,807		)	(41,226		)
Total Income Before Income Taxes	$	103,980		$	107,592



	Three months ended
NET INCOME:	March 31,
(in thousands)	2016			2015
Regulated Operating Subsidiaries	$	94,185		$	91,439
ITC Holdings and other	64,237			67,132
Intercompany eliminations	(94,185		)	(91,439		)
Total Net Income	$	64,237		$	67,132



TOTAL ASSETS:	March 31,			December 31,
(in thousands)	2016			2015
Regulated Operating Subsidiaries	$	7,752,752		$	7,463,557
ITC Holdings and other	4,253,768			4,147,915
Reconciliations / Intercompany eliminations (a)	(4,143,278		)	(4,056,150		)
Total Assets	$	7,863,242		$	7,555,322

____________________________


(a)	Reconciliation of total assets results primarily from differences in the netting of deferred tax assets and liabilities at our Regulated Operating Subsidiaries as compared to the classification in our condensed consolidated statements of financial position.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

Our reports, filings and other public announcements contain certain statements that describe our management’s beliefs concerning future business conditions, plans and prospects, growth opportunities, the outlook for our business and the electric transmission industry, expectations with respect to various legal and regulatory proceedings and the proposed Merger with Fortis based upon information currently available. Such statements are “forward-looking” statements within the meaning of the Private Securities Litigation Reform Act of 1995. Wherever possible, we have identified these forward-looking statements by words such as “will,” “may,” “anticipates,” “believes,” “intends,” “estimates,” “expects,” “projects,” “likely” and similar phrases. These forward-looking statements are based upon assumptions our management believes are reasonable. Such forward-looking statements are based on estimates and assumptions and subject to significant risks and uncertainties which could cause our actual results, performance and achievements to differ materially from those expressed in, or implied by, these statements, including, among others, the risks and uncertainties listed in Item 1A Risk Factors of our Form 10-K for the fiscal year ended December 31, 2015, and the following:


•	Certain elements of our Regulated Operating Subsidiaries’ formula rates can be and have been challenged, which could result in lowered rates and/or refunds of amounts previously collected and thus have an adverse effect on our business, financial condition, results of operations and cash flows.

•

Our actual capital investment may be lower than planned, which would cause a lower than anticipated rate base and would therefore result in lower revenues and earnings compared to our current expectations. In addition, we expect to invest in strategic development opportunities to improve the efficiency and reliability of the transmission grid, but we cannot provide assurance that we will be able to initiate or complete any of these investments. In addition, we expect to incur expenses related to the pursuit of development opportunities, which may be higher than forecasted.


•	The regulations to which we are subject may limit our ability to raise capital and/or pursue acquisitions, development opportunities or other transactions or may subject us to liabilities.


•	Changes in energy laws, regulations or policies could impact our business, financial condition, results of operations and cash flows.


•	If amounts billed for transmission service for our Regulated Operating Subsidiaries’ transmission systems are lower than expected, or our actual revenue requirements are higher than expected, the timing of collection of our revenues would be delayed.


•	Each of our MISO Regulated Operating Subsidiaries depends on its primary customer for a substantial portion of its revenues, and any material failure by those primary customers to make payments for transmission services could have a material adverse effect on our business, financial condition, results of operations and cash flows.


•	A significant amount of the land on which our assets are located is subject to easements, mineral rights and other similar encumbrances. As a result, we must comply with the provisions of various easements, mineral rights and other similar encumbrances, which may adversely impact their ability to complete construction projects in a timely manner.


•	We contract with third parties to provide services for certain aspects of our business. If any of these agreements are terminated, we may face a shortage of labor or replacement contractors to provide the services formerly provided by these third parties.


•	Hazards associated with high-voltage electricity transmission may result in suspension of our operations or the imposition of civil or criminal penalties.


•	We are subject to environmental regulations and to laws that can give rise to substantial liabilities from environmental contamination.

•

We are subject to various regulatory requirements, including reliability standards; contract filing requirements; reporting, recordkeeping and accounting requirements; and transaction approval requirements. Violations of these requirements, whether intentional or unintentional, may result in penalties that, under some circumstances, could have a material adverse effect on our business, financial condition, results of operations and cash flows.


•	Acts of war, terrorist attacks, cyber attacks, natural disasters, severe weather and other catastrophic events may have a material adverse effect on our business, financial condition, results of operations and cash flows.

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•	ITC Holdings is a holding company with no operations, and unless we receive dividends or other payments from our subsidiaries, we may be unable to pay dividends and fulfill our other cash obligations.


•	We have a considerable amount of debt and our reliance on debt financing may limit our ability to fulfill our debt obligations and/or to obtain additional financing.


•	Certain provisions in our debt instruments limit our financial and operating flexibility.


•	Adverse changes in our credit ratings may negatively affect us.


•	Provisions in our Articles of Incorporation and bylaws, Michigan corporate law and our debt agreements may impede efforts by our shareholders to change the direction or management of our company.


•	Provisions in our Articles of Incorporation restrict market participants from voting or owning 5% or more of the outstanding shares of our capital stock.


•	Completion of the Merger is subject to various conditions which, if not satisfied, may cause the Merger not to be completed in a timely manner or at all.


•	We will continue to incur substantial transaction-related costs in connection with the Merger.


•	The announcement and pendency of the Merger could adversely affect our business, results of operations and financial condition.


•	While the Merger Agreement is in effect, we are subject to restrictions on our business activities.


•	Because the market value of Fortis common stock that our shareholders will receive in the Merger may fluctuate, our shareholders cannot be sure of the market value of the stock portion of the consideration that they will receive in the Merger.


•	If the Merger is completed, the combined company may not be able to successfully integrate our business with Fortis and therefore may not be able to realize the anticipated benefits of the Merger.


•	After the completion of the Merger, sales of Fortis common stock may negatively affect its market price.


•	We may be the target of securities class action and derivative lawsuits which could result in substantial costs and may delay or prevent the Merger from being completed.

Forward-looking statements speak only as of the date made and can be affected by assumptions we might make or by known or unknown risks and uncertainties. Many factors mentioned in our discussion in this report will be important in determining future results. Consequently, we cannot assure you that our expectations or forecasts expressed in such forward-looking statements will be achieved. Except as required by law, we undertake no obligation to publicly update any of our forward-looking or other statements, whether as a result of new information, future events or otherwise.

OVERVIEW

Through our Regulated Operating Subsidiaries, we operate high-voltage systems in Michigan’s Lower Peninsula and portions of Iowa, Minnesota, Illinois, Missouri, Kansas and Oklahoma that transmit electricity from generating stations to local distribution facilities connected to our systems. Our business strategy is to operate, maintain and invest in transmission infrastructure in order to enhance system integrity and reliability, reduce transmission constraints and upgrade the transmission networks to support new generating resources interconnecting to our transmission systems. We also are pursuing development projects not within our existing systems, which are likewise intended to improve overall grid reliability, reduce transmission constraints and facilitate interconnections of new generating resources, as well as enhance competitive wholesale electricity markets.

As electric transmission utilities with rates regulated by the FERC, our Regulated Operating Subsidiaries earn revenues through tariff rates charged for the use of their electric transmission systems by our customers, which include investor-owned utilities, municipalities, cooperatives, power marketers and alternative energy suppliers. As independent transmission companies, our Regulated Operating Subsidiaries are subject to rate regulation only by the FERC. The rates charged by our Regulated Operating Subsidiaries are established using cost-based formula rate templates, as discussed in Note 3 to the condensed consolidated financial statements under “— Cost-Based Formula Rates with True-Up Mechanism.”

Our Regulated Operating Subsidiaries’ primary operating responsibilities include maintaining, improving and expanding their transmission systems to meet their customers’ ongoing needs, scheduling outages on system elements to allow for

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maintenance and construction, maintaining appropriate system voltages and monitoring flows over transmission lines and other facilities to ensure physical limits are not exceeded.

We derive nearly all of our revenues from providing electric transmission service over our Regulated Operating Subsidiaries’ transmission systems to investor-owned utilities, such as DTE Electric, Consumers Energy and IP&L, and other entities, such as alternative electricity suppliers, power marketers and other wholesale customers that provide electricity to end-use consumers as well as from transaction-based capacity reservations on our transmission systems.

Significant recent matters that influenced our financial position and results of operations and cash flows for the three months ended March 31, 2016 or that may affect future results include:


•	Our capital investment of $176.6 million at our Regulated Operating Subsidiaries during the three months ended March 31, 2016, resulting primarily from our focus on improving system reliability, increasing system capacity and upgrading the transmission network to support new generating resources;


•	Debt issuance as described in Note 5 to the condensed consolidated financial statements and borrowings under our revolving credit agreements in 2016 and 2015 to fund capital investment at our Regulated Operating Subsidiaries and for general corporate purposes;


•	Debt maturing within one year of $607.1 million as of March 31, 2016 and the potentially higher interest rates associated with the additional financing required to repay this debt;

•

Recognition of the refund liability for the potential refund relating to the rate of return on equity (“ROE”) complaints, as described in Note 10 to the condensed consolidated financial statements, which resulted in a total estimated pre-tax reduction of revenue and additional interest of $18.9 million and an estimated after-tax reduction to net income of $11.5 million for the three months ended March 31, 2016;

•

Election of bonus depreciation for tax years 2015 and 2016 for our Regulated Operating Subsidiaries as well as the simulation of ITC Midwest’s 2015 revenue requirement with the election of bonus depreciation. The total impact from these matters was lower revenues and net income of approximately $5.4 million and $3.2 million, respectively, for the three months ended March 31, 2016. These matters also resulted in additional deferred income tax liabilities of approximately $138.7 million and a corresponding income tax receivable as of March 31, 2016; and

•

The proposed Merger with Fortis, pursuant to which ITC Holdings will become a subsidiary of Fortis upon completion of the Merger as described below under “— Capital Project Updates and Other Recent Developments — Proposed Merger.” For the three months ended March 31, 2016, we expensed external legal, advisory and financial services fees related to the Merger of $9.9 million and certain internal labor and associated costs related to the Merger of approximately $3.1 million. Certain amounts of the external costs are not expected to be deductible for income tax purposes. The external and internal costs related to the Merger are not included as components of revenue requirement as they were incurred at ITC Holdings. We expect the total fees and costs related to the Merger will be material to our results of operations in 2016. The Merger is expected to be consummated in late 2016.

These items are discussed in more detail throughout Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Capital Project Updates and Other Recent Developments

Proposed Merger

On February 9, 2016, ITC Holdings entered into an agreement and plan of merger (the “Merger Agreement”) with Fortis, FortisUS and Merger Sub, pursuant to which Merger Sub will merge with and into ITC Holdings, as a result of which ITC Holdings will become a subsidiary of FortisUS (the “Merger”). In the Merger, our shareholders will receive $22.57 in cash and 0.7520 Fortis common shares for each share of common stock of ITC Holdings. On April 20, 2016, Fortis reached a definitive agreement with GIC Private Limited to acquire an indirect 19.9% equity interest in ITC Holdings. Refer to Note 11 to the condensed consolidated financial statements for further explanation of the Merger.

Development Bonuses

We recognized general and administrative expenses of $0.9 million and $9.5 million during the three months ended March 31, 2016 and 2015, respectively, for bonuses for certain development projects, including the successful completion of certain milestones relating to projects at ITC Great Plains.

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Multi-Value Projects

2011 MISO Multi-Value Projects

In December 2011, MISO approved a portfolio of Multi-Value Projects (“MVPs”) which includes portions of four MVPs that we will construct, own and operate. The four MVPs are located in south central Minnesota, northern and southeast Iowa, southwest Wisconsin, and northeast Missouri and are in various stages of construction and included in ITC Midwest’s capital investment amounts. We currently estimate ITC Midwest will invest approximately $500 million in the four MVPs from 2016 through 2018.

Thumb Loop Project

The Thumb Loop Project, constructed by ITCTransmission, consists of a 140-mile, double-circuit 345 kV transmission line and related substations that now serves as the backbone of the transmission system needed to accommodate future wind development projects in the Michigan counties of Tuscola, Huron, Sanilac and St. Clair. The final phase of the Thumb Loop Project was placed in-service in May 2015. Through March 31, 2016, ITCTransmission has invested $502.8 million in the Thumb Loop Project and any further investment to complete this project is not expected to be material.

Rate of Return on Equity Complaints

On November 12, 2013, certain parties filed a joint complaint with the FERC under Section 206 of the FPA (the “Initial Complaint”), requesting that the FERC find the current 12.38% MISO regional base ROE rate (the “base ROE”) for all MISO TOs, including ITCTransmission, METC and ITC Midwest, to no longer be just and reasonable. The complainants sought a FERC order reducing the base ROE used in the formula transmission rates for our MISO Regulated Operating Subsidiaries to 9.15%, reducing the equity component of our capital structure from the FERC approved 60% to 50% and terminating the ROE adders currently approved for certain ITC Holdings operating companies, including adders currently utilized by ITCTransmission and METC.

We believe that the current ROE encourages transmission investment and offsets the burdens associated with maintaining the independent transmission business model and RTO membership. ITCTransmission, METC and ITC Midwest filed responses during the first quarter of 2014, separately and together with other MISO TOs, that sought dismissal of the Initial Complaint for its failure to satisfy the requirements of FPA Section 206 and the FERC’s accompanying Rules, or denial of the Initial Complaint on the merits, with prejudice.

On February 12, 2015, an additional complaint was filed with the FERC under Section 206 of the FPA (the “Second Complaint”) by separate complainants, seeking a FERC order to reduce the base ROE used in our MISO Regulated Operating

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Subsidiaries’ formula transmission rates to 8.67%, with an effective date of February 12, 2015. On March 11, 2015, the MISO TOs filed an answer to the Second Complaint with the FERC supporting the current base ROE as just and reasonable. On June 18, 2015, FERC accepted the Second Complaint and set it for hearing and settlement procedures. FERC also set the refund effective date for the Second Complaint as February 12, 2015.

MISO Formula Rate Template Modifications Filing

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Challenges Regarding Bonus Depreciation

On December 18, 2015, IP&L filed a formal challenge (“IP&L challenge”) with the FERC against ITC Midwest on certain inputs to ITC Midwest’s formula rates. The IP&L challenge alleged that ITC Midwest has unreasonably and imprudently opted out of using bonus depreciation in the calculation of its federal income tax expense and thereby unduly increased the transmission charges for transmission service for customers. On March 11, 2016, the FERC granted the IP&L challenge in part by requiring ITC Midwest to recalculate its revenue requirements, effective January 1, 2015, to simulate the election of bonus depreciation for 2015. FERC denied IP&L’s request that ITC Midwest be required to elect bonus depreciation in any past or future years; however, stakeholders will be able to challenge any decision by ITC Midwest not to take bonus depreciation in future years. ITC Midwest has filed with the FERC for rehearing of the March 11, 2016 order. On April 15, 2016, Consumers Energy Company filed a formal challenge, or in the alternative, a complaint under Section 206 of the FPA, with the FERC against METC also relating to METC’s historical practice of opting out of using bonus depreciation.

These condensed consolidated financial statements reflect the election of bonus depreciation for tax years 2015 and 2016 for our Regulated Operating Subsidiaries. Additionally, as required by the March 11, 2016 FERC order, we have simulated the election of bonus depreciation for ITC Midwest’s 2015 revenue requirement and included the impact of the corresponding refund obligation in these condensed consolidated financial statements. The total impact from reflecting the election of bonus depreciation as described above was lower revenues and net income of approximately $5.4 million and $3.2 million, respectively, for the three months ended March 31, 2016, as compared to the same period if bonus depreciation was not reflected. These matters also resulted in additional deferred income tax liabilities of approximately $138.7 million and a corresponding income tax receivable as of March 31, 2016. We are unable to predict the outcome of this matter; however, the election of bonus depreciation will result in higher cash flows in the year of the election and reduce our rate base and therefore our revenues and net income over the tax lives of the eligible assets. Bonus depreciation is currently enacted through 2019, with certain provisions that allow for an additional year of eligibility for certain property with long construction periods. If bonus depreciation is elected for a given year, we estimate that, based on an amount of tax additions that may be eligible for bonus depreciation representative of our investment plans in the near term, the higher deferred tax liabilities and the corresponding reduced rate base could reduce revenues recognized by us for the relevant year by $15 million to $20 million initially, with a corresponding reduction to annual net income of $9 million to $12 million (disregarding any favorable effects from the use of the potential cash tax savings), with the negative effect on annual revenues and net income relating to each year’s election decreasing each year over the tax lives of the assets.

Cost-Based Formula Rate Templates with True-Up Mechanism

Our Regulated Operating Subsidiaries calculate their revenue requirements using cost-based formula rate templates and are effective without the need to file rate cases with the FERC, although the rates are subject to legal challenge at the FERC. Under their cost-based formula rate templates, each of our Regulated Operating Subsidiaries separately calculates a revenue requirement based on financial information specific to each company. The calculation of projected revenue requirement for a future period is used to establish the transmission rate used for billing purposes. The calculation of actual revenue requirements for a historic period is used to calculate the amount of revenues recognized in that period and determine the over- or under-collection for that period.

Under these formula rate templates, our Regulated Operating Subsidiaries recover expenses and earn a return on and recover investments in property, plant and equipment on a current basis, rather than lagging. The formula rate templates for a given year initially utilize forecasted expenses, property, plant and equipment, point-to-point revenues, network load at our MISO Regulated Operating Subsidiaries and other items for the upcoming calendar year to establish projected revenue requirements for each of our Regulated Operating Subsidiaries that are used as the basis for billing for service on their systems from January 1 to December 31 of that year. Our cost-based formula rate templates include a true-up mechanism, whereby our Regulated Operating Subsidiaries compare their actual revenue requirements to their billed revenues for each year to determine any over- or under-collection of revenue. The over- or under-collection typically results from differences between the projected revenue requirement used as the basis for billing and actual revenue requirement at each of our Regulated Operating Subsidiaries, or from differences between actual and projected monthly peak loads at our MISO Regulated Operating Subsidiaries. In the event billed revenues in a given year are more or less than actual revenue requirements, which are calculated primarily using information from that year’s FERC Form No. 1, our Regulated Operating Subsidiaries will refund or collect additional revenues, with interest, within a two-year period such that customers pay only the amounts that correspond to actual revenue requirements for that given period. This annual true-up ensures that our Regulated Operating Subsidiaries recover their allowed costs and earn their allowed returns.

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Revenue Accruals and Deferrals — Effects of Monthly Peak Loads

For our MISO Regulated Operating Subsidiaries, monthly peak loads are used for billing network revenues, which currently is the largest component of our operating revenues. One of the primary factors that impacts the revenue accruals and deferrals at our MISO Regulated Operating Subsidiaries is actual monthly peak loads experienced as compared to those forecasted in establishing the annual network transmission rate. Under their cost-based formula rates that contain a true-up mechanism, our Regulated Operating Subsidiaries accrue or defer revenues to the extent that their actual revenue requirement for the reporting period is higher or lower, respectively, than the amounts billed relating to that reporting period. Although monthly peak loads do not impact operating revenues recognized, network load affects the timing of our cash flows from transmission service. The monthly peak load of our MISO Regulated Operating Subsidiaries is generally impacted by weather and economic conditions and seasonally shaped with higher load in the summer months when cooling demand is higher.

ITC Great Plains does not receive revenue based on a peak load or a dollar amount per kW each month and, therefore, peak load does not have a seasonal effect on operating cash flows. The SPP tariff applicable to ITC Great Plains is billed ratably each month based on its annual projected revenue requirement posted annually by SPP.

Capital Investment and Operating Results Trends

We expect a long-term upward trend in revenues and earnings, subject to the impact of any rate changes and required refunds resulting from the resolution of the ROE complaints as described in Note 10 to the condensed consolidated financial statements. The primary factor that is expected to continue to increase our revenues and earnings in future years is increased rate base that would result from our anticipated capital investment, in excess of depreciation, from our Regulated Operating Subsidiaries’ long-term capital investment programs to improve reliability, increase system capacity and upgrade the transmission network to support new generating resources. In addition, our capital investment efforts relating to development initiatives are based on establishing an ongoing pipeline of projects that would position us for long-term growth. Investments in property, plant and equipment, when placed in-service upon completion of a capital project, are added to the rate base of our Regulated Operating Subsidiaries.

Our Regulated Operating Subsidiaries strive for high reliability of their systems and improvement in system accessibility for all generation resources. The FERC requires compliance with certain reliability standards and may take enforcement actions against violators, including the imposition of substantial fines. NERC is responsible for developing and enforcing these mandatory reliability standards. We continually assess our transmission systems against standards established by NERC, as well as the standards of applicable regional entities under NERC that have been delegated certain authority for the purpose of proposing and enforcing reliability standards. We believe that we meet the applicable standards in all material respects, although further investment in our transmission systems and an increase in maintenance activities will likely be needed to maintain compliance, improve reliability and address any new standards that may be promulgated.

We also assess our transmission systems against our own planning criteria that are filed annually with the FERC. Based on our planning studies, we see needs to make capital investments to (1) rebuild existing property, plant and equipment; (2) upgrade the system to address demographic changes that have impacted transmission load and the changing role that transmission plays in meeting the needs of the wholesale market, including accommodating the siting of new generation or increasing import capacity to meet changes in peak electrical demand; (3) relieve congestion in the transmission systems; and (4) achieve state and federal policy goals, such as renewable generation portfolio standards. During the three months ended March 31, 2016, we made capital investments of $176.6 million at our Regulated Operating Subsidiaries (in amounts of $41.1 million, $47.0 million, $74.8 million and $13.7 million at ITCTransmission, METC, ITC Midwest and ITC Great Plains, respectively). The following table shows our actual and expected capital investments at our Regulated Operating Subsidiaries:



	Forecasted		Actual Capital
	Capital		Investment for the
(in millions)	Investment		three months ended
Source of Investment	2016 — 2018		March 31, 2016 (a)
Current Transmission Systems	$	1,523	$	136.5
Regional Infrastructure	530		40.1
Total	$	2,053	$	176.6

____________________________

(a)

Capital investment amounts differ from cash expenditures for property, plant and equipment included in our condensed consolidated statements of cash flows due in part to differences in construction costs incurred compared to cash paid during that period, as well as payments for major equipment inventory that are included in cash expenditures, but not included in capital investment until transferred to construction work in progress, among other factors.

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Refer to “Item 1 Business — Development of Business — Development Projects” in our Form 10-K for the year ended December 31, 2015 for a discussion of our development projects. We are pursuing projects that could result in a significant amount of capital investment, but are not able to estimate the amounts we ultimately expect to achieve or the timing of such investments.

Investments in property, plant and equipment could vary due to, among other things, the impact of actual loads, forecasted loads, regional economic conditions, weather conditions, union strikes, labor shortages, material and equipment prices and availability, our ability to obtain any necessary financing for such expenditures, limitations on the amount of construction that can be undertaken on our systems at any one time, regulatory approvals for reasons relating to rate construct, environmental, siting, regional planning, cost recovery or other issues or as a result of legal proceedings, variances between estimated and actual costs of construction contracts awarded and the potential for greater competition for new development projects. In addition, investments in transmission network upgrades for generator interconnection projects could change from prior estimates significantly due to changes in the MISO queue for generation projects and other factors beyond our control.

RESULTS OF OPERATIONS

Results of Operations and Variances



	Three months ended									Percentage
	March 31,						Increase			increase
(in thousands)	2016			2015			(decrease)			(decrease)
OPERATING REVENUES	$	280,133		$	272,487		$	7,646		2.8	%
OPERATING EXPENSES
Operation and maintenance	24,596			25,562			(966		)	(3.8	)%
General and administrative	45,708			40,894			4,814			11.8	%
Depreciation and amortization	38,872			34,435			4,437			12.9	%
Taxes other than income taxes	23,449			22,380			1,069			4.8	%
Other operating (income) and expenses — net	(264		)	(236		)	(28		)	11.9	%
Total operating expenses	132,361			123,035			9,326			7.6	%
OPERATING INCOME	147,772			149,452			(1,680		)	(1.1	)%
OTHER EXPENSES (INCOME)
Interest expense — net	50,417			48,474			1,943			4.0	%
Allowance for equity funds used during construction	(7,519		)	(7,549		)	30			(0.4	)%
Other income	(268		)	(253		)	(15		)	5.9	%
Other expense	1,162			1,188			(26		)	(2.2	)%
Total other expenses (income)	43,792			41,860			1,932			4.6	%
INCOME BEFORE INCOME TAXES	103,980			107,592			(3,612		)	(3.4	)%
INCOME TAX PROVISION	39,743			40,460			(717		)	(1.8	)%
NET INCOME	$	64,237		$	67,132		$	(2,895	)	(4.3	)%

Operating Revenues

Three months ended March 31, 2016 compared to three months ended March 31, 2015

The following table sets forth the components of and changes in operating revenues:



														Percentage
	2016					2015					Increase			increase
(in thousands)	Amount			Percentage		Amount			Percentage		(decrease)			(decrease)
Network revenues	$	203,281		72.6	%	$	196,976		72.3	%	$	6,305		3.2	%
Regional cost sharing revenues	83,878			29.9	%	74,550			27.4	%	9,328			12.5	%
Point-to-point	3,633			1.3	%	4,214			1.5	%	(581		)	(13.8	)%
Scheduling, control and dispatch	3,648			1.3	%	3,215			1.2	%	433			13.5	%
Other	3,161			1.1	%	1,075			0.4	%	2,086			194.0	%
Recognition of rate refund liability	(17,468		)	(6.2	)%	(7,543		)	(2.8	)%	(9,925		)	131.6	%
Total	$	280,133		100.0	%	$	272,487		100.0	%	$	7,646		2.8	%

Network revenues increased due primarily to higher net revenue requirements at our Regulated Operating Subsidiaries, partially offset by an increase in revenue credit resulting from higher regional revenue requirements and by the election of bonus depreciation as described in Note 3 of the condensed financial statements, during the three months ended March 31,

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2016 as compared to the same period in 2015. Higher net revenue requirements were due primarily to higher rate bases associated with higher balances of property, plant and equipment in-service.

Regional cost sharing revenues increased primarily due to additional capital projects identified by MISO and SPP as eligible for regional cost sharing and these projects being placed in-service, in addition to higher accumulated investment for the Thumb Loop Project and Kansas V-Plan Project during the three months ended March 31, 2016 as compared to the same period in 2015. We expect to continue to receive regional cost sharing revenues and the amounts could increase in the near future, including revenues associated with projects that have been or are expected to be approved for regional cost sharing.

The recognition of the refund liability for the potential refund relating to the ROE complaints, described in Note 10 to the condensed consolidated financial statements, resulted in a reduction to operating revenues of $17.5 million and $7.5 million during the three months ended March 31, 2016 and 2015, respectively. We are not able to estimate whether any required refunds would be applied to all components of revenue listed in the table above or only certain components.

Operating revenues for the three months ended March 31, 2016 include revenue accruals and deferrals as described in Note 3 to the condensed consolidated financial statements.

Operating Expenses

Operation and maintenance expenses

Three months ended March 31, 2016 compared to three months ended March 31, 2015

Operation and maintenance expenses decreased due primarily to lower vegetation management requirements.

General and administrative expenses

Three months ended March 31, 2016 compared to three months ended March 31, 2015

General and administrative expenses increased due primarily to higher external legal, advisory and consulting services for the Merger of $9.9 million and higher compensation and benefit expenses of $2.9 million due to personnel additions and additional stock compensation expense. These increases were partially offset by lower development bonus expenses of $8.6 million as described under “Capital Project Updates and Other Recent Developments — Development Bonuses.”

Depreciation and amortization expenses

Three months ended March 31, 2016 compared to three months ended March 31, 2015

Depreciation and amortization expenses increased due primarily to a higher depreciable base resulting from property, plant and equipment in-service additions.

Taxes other than income taxes

Three months ended March 31, 2016 compared to three months ended March 31, 2015

Taxes other than income taxes increased due to higher property tax expenses due primarily to our Regulated Operating Subsidiaries’ 2015 capital additions, which are included in the assessments for 2016 personal property taxes.

Other Expenses (Income)

Three months ended March 31, 2016 compared to three months ended March 31, 2015

Interest Expense

Interest expense increased due primarily to the additional interest expense associated with the refund liability relating to the ROE complaints described in Note 10 to the financial statements.

Allowance for Equity Funds Used During Construction

Allowance for Equity Funds Used During Construction (“AFUDC equity”) were consistent with the prior period.

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Income Tax Provision

Three months ended March 31, 2016 compared to three months ended March 31, 2015

Our effective tax rates for the three months ended March 31, 2016 and 2015 were 38.2% and 37.6%, respectively. Our effective tax rate in both periods exceeded our 35% statutory federal income tax rate due primarily to state income taxes as well as the non-deductibility of certain costs incurred to facilitate the consummation of the proposed Merger, partially offset by the tax effects of AFUDC equity which reduced the effective tax rate. The amount of income tax expense relating to AFUDC equity was recognized as a regulatory asset and not included in the income tax provision. We recorded a state income tax provision of $3.9 million (net of federal deductibility) during the three months ended March 31, 2016 compared to a state income tax provision of $4.0 million (net of federal deductibility) for the three months ended March 31, 2015.

LIQUIDITY AND CAPITAL RESOURCES

We expect to maintain our approach to fund our future capital requirements with cash from operations at our Regulated Operating Subsidiaries, our existing cash and cash equivalents, issuances under our commercial paper program and amounts available under our revolving credit agreements (the terms of which are described in Note 5 to the condensed consolidated financial statements). In addition, we may from time to time secure debt and equity funding in the capital markets, although we can provide no assurance that we will be able to obtain financing on favorable terms or at all. As market conditions warrant, we may also from time to time repurchase debt or equity securities issued by us, in the open market, in privately negotiated transactions, by tender offer or otherwise. We expect that our capital requirements will arise principally from our need to:


•	Fund capital expenditures at our Regulated Operating Subsidiaries. Our plans with regard to property, plant and equipment investments are described in detail above under “— Capital Investment and Operating Results Trends.”


•	Fund business development expenses and related capital expenditures. We are pursuing development activities for transmission projects that will continue to result in the incurrence of development expenses and could result in significant capital expenditures.


•	Fund working capital requirements.


•	Fund our debt service requirements, including principal repayments and periodic interest payments. We expect our interest payments to increase each year as a result of additional debt expected to be incurred to fund our capital expenditures and for general corporate purposes.


•	Fund contributions to our retirement benefit plans, as described in Note 8 to the condensed consolidated financial statements. We expect to contribute $15.4 million to these plans in 2016.

In addition to the expected capital requirements above, any adverse determinations relating to the regulatory matters or contingencies described in Notes 3 and 10 to the condensed consolidated financial statements would result in additional capital requirements.

We believe that we have sufficient capital resources to meet our currently anticipated short-term needs. We rely on both internal and external sources of liquidity to provide working capital and fund capital investments. ITC Holdings’ sources of cash are dividends and other payments received by us from our Regulated Operating Subsidiaries and any of our other subsidiaries as well as the proceeds raised from the sale of our debt and equity securities. Each of our Regulated Operating Subsidiaries, while wholly owned by ITC Holdings, is legally distinct from ITC Holdings and has no obligation, contingent or otherwise, to make funds available to us.

We expect to continue to utilize our commercial paper program and revolving credit agreements as well as our cash and cash equivalents as needed to meet our short-term cash requirements. As of March 31, 2016, we had consolidated indebtedness under our revolving and term loan credit agreements of $593.8 million, with unused capacity under our revolving credit agreements of $767.2 million. Additionally, ITC Holdings had $307.0 million of commercial paper issued and outstanding as of March 31, 2016 with the ability to issue an additional $93.0 million under the commercial paper program. See Note 5 to the condensed consolidated financial statements for a detailed discussion of the commercial paper program and our revolving credit agreements as well as the debt issuance in 2016.

As of March 31, 2016, we had approximately $607.1 million of debt maturing within one year, which we expect to refinance with long-term debt. To address our long-term capital requirements as well as repay debt maturing within one year, we expect that we will need to obtain additional debt financing. Certain of our capital projects could be delayed if we experience difficulties in accessing capital. We expect to be able to obtain such additional financing as needed, in amounts and upon terms that will be reasonably satisfactory to us due to our strong credit ratings and our historical ability to obtain financing.

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Credit Ratings

Credit ratings by nationally recognized statistical rating agencies are an important component of our liquidity profile. Credit ratings relate to our ability to issue debt securities and the cost to borrow money, and should not be viewed as an indication of future stock performance or a recommendation to buy, sell or hold securities. Ratings are subject to revision or withdrawal at any time and each rating should be evaluated independently of any other rating. Our current credit ratings are displayed in the following table. An explanation of these ratings may be obtained from the respective rating agency.



Issuer	Issuance	Standard and Poor’s Ratings Services (a)	Moody’s Investor Service, Inc. (b)
ITC Holdings	Senior Unsecured Notes	BBB+	Baa2
ITC Holdings	Commercial Paper	A-2	Prime-2
ITCTransmission	First Mortgage Bonds	A	A1
METC	Senior Secured Notes	A	A1
ITC Midwest	First Mortgage Bonds	A	A1
ITC Great Plains	First Mortgage Bonds	A	A1

____________________________

(a)

On June 8, 2015, Standard and Poor’s Ratings Services (“Standard and Poor’s”) assigned a short-term issuer credit rating to ITC Holdings, which applies to the commercial paper program discussed in Note 5 to the condensed consolidated financial statements. Additionally, on December 3, 2015, Standard and Poor’s reaffirmed the senior unsecured credit rating of ITC Holdings and the secured credit ratings of the Regulated Operating Subsidiaries. On February 9, 2016, Standard and Poor’s revised the outlook of the issuer credit ratings of ITC Holdings and the Regulated Operating Subsidiaries to negative from developing, subsequent to the announcement of the Merger.

(b)

On June 9, 2015, Moody’s Investor Service, Inc. (“Moody’s”) assigned a short-term commercial paper rating to ITC Holdings, which applies to the commercial paper program discussed in Note 5 to the condensed consolidated financial statements. Additionally, on April 15, 2016, Moody’s reaffirmed the credit ratings for the associated debt for ITC Holdings, ITCTransmission, ITC Midwest and ITC Great Plains. On April 26, 2016, Moody’s assigned a senior secured rating to METC’s 3.90% Senior Secured Note issuance described in Note 5 to the condensed consolidated financial statements. All of the credit ratings have a stable outlook.

Covenants

Our debt instruments contain numerous financial and operating covenants that place significant restrictions on certain transactions as well as require us to meet certain financial ratios, which are described in Note 5 to the condensed consolidated financial statements and in our Form 10-K for the fiscal year ended December 31, 2015. As of March 31, 2016, we were not in violation of any debt covenant. In the event of a downgrade in our credit ratings, none of the covenants would be directly impacted, although the borrowing costs under our revolving and term loan credit agreements would increase.

Cash Flows From Operating Activities

Net cash provided by operating activities was $87.8 million and $66.9 million for the three months ended March 31, 2016 and 2015, respectively. The increase in cash provided by operating activities was due primarily to an increase in cash received from operating revenues of $10.7 million and a decrease in payments of operating expenses of $6.3 million during the three months ended March 31, 2016 compared to the same period in 2015.

Cash Flows From Investing Activities

Net cash used in investing activities was $195.2 million and $178.2 million for the three months ended March 31, 2016 and 2015, respectively. The increase in cash used in investing activities was due primarily to the timing of payments for investments in property, plant and equipment during the three months ended March 31, 2016 compared to the same period in 2015.

Cash Flows From Financing Activities

Net cash provided by financing activities was $101.8 million and $92.7 million for the three months ended March 31, 2016 and 2015, respectively. The increase in cash provided by financing activities was due primarily to lower net payments of $13.9 million associated with refundable deposits for transmission network upgrades during the three months ended March

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31, 2016 compared to the same period in 2015. This increase was partially offset by an additional $3.4 million of dividend payments.

CONTRACTUAL OBLIGATIONS

Our contractual obligations are described in our Form 10-K for the year ended December 31, 2015. There have been no material changes to that information since December 31, 2015, other than the items listed below and described in Note 5 to the condensed consolidated financial statements:


•	Changes in amounts borrowed under our unsecured, unguaranteed revolving credit agreements;


•	Changes in commercial paper issued under the commercial paper program for ITC Holdings; and


•	The issuance of $200.0 million of 3.90% Senior Secured Notes, due April 26, 2046, by METC, with the net proceeds to be used to repay the $200.0 million borrowed under METC’s term loan credit agreement.

CRITICAL ACCOUNTING POLICIES

Our condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The preparation of these condensed consolidated financial statements requires the application of appropriate technical accounting rules and guidance, as well as the use of estimates. The application of these policies necessarily involves judgments regarding future events. These estimates and judgments, in and of themselves, could materially impact the condensed consolidated financial statements and disclosures based on varying assumptions, as future events rarely develop exactly as forecasted, and even the best estimates routinely require adjustment. The accounting policies discussed in “Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies” in our Form 10-K for the fiscal year ended December 31, 2015 are considered by management to be the most important to an understanding of the consolidated financial statements because of their significance to the portrayal of our financial condition and results of operations or because their application places the most significant demands on management’s judgment and estimates about the effect of matters that are inherently uncertain. There have been no material changes to that information during the three months ended March 31, 2016.

RECENT ACCOUNTING PRONOUNCEMENTS

See Note 2 to the condensed consolidated financial statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Fixed Rate Debt

Based on the borrowing rates currently available for bank loans with similar terms and average maturities, the fair value of our consolidated long-term debt and debt maturing within one year, excluding revolving and term loan credit agreements and commercial paper, was $3,951.5 million at March 31, 2016. The total book value of our consolidated long-term debt and debt maturing within one year, excluding revolving and term loan credit agreements and commercial paper, was $3,654.4 million at March 31, 2016. We performed an analysis calculating the impact of changes in interest rates on the fair value of long-term debt and debt maturing within one year, excluding revolving and term loan credit agreements and commercial paper, at March 31, 2016. An increase in interest rates of 10% (from 5.0% to 5.5%, for example) at March 31, 2016 would decrease the fair value of debt by $157.4 million, and a decrease in interest rates of 10% at March 31, 2016 would increase the fair value of debt by $170.9 million at that date.

Revolving and Term Loan Credit Agreements

At March 31, 2016, we had a consolidated total of $593.8 million outstanding under our revolving and term loan credit agreements, which are variable rate loans and fair value approximates book value. A 10% increase or decrease in borrowing rates under the revolving and term loan credit agreements compared to the weighted average rates in effect at March 31, 2016 would increase or decrease interest expense by $0.9 million, respectively, for an annual period with a constant borrowing level of $593.8 million.

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Commercial Paper

At March 31, 2016, ITC Holdings had $307.0 million of commercial paper issued and outstanding, net of discount, under the commercial paper program. Due to the short-term nature of these financial instruments, the carrying value approximates fair value. A 10% increase or decrease in interest rates for commercial paper would increase or decrease interest expense by $0.3 million for an annual period with a continuous level of commercial paper outstanding of $307.0 million.

Derivative Instruments and Hedging Activities

We use derivative financial instruments, including interest rate swap contracts, to manage our exposure to fluctuations in interest rates. The use of these financial instruments mitigates exposure to these risks and the variability of our operating results. We are not a party to leveraged derivatives and do not enter into derivative financial instruments for trading or speculative purposes. As of March 31, 2016, we held 10-year interest rate swap contracts with a notional amount of $200.0 million, which manage interest rate risk associated with the forecasted future issuance of fixed-rate debt related to (1) the expected refinancing of the ITC Holdings 5.875% Senior Notes, due September 30, 2016 (“5.875% Senior Notes”) and (2) the expected financing required to repay the amount borrowed under ITC Holdings’ term loan credit agreement, due September 30, 2016 (“Term Loan”). As of March 31, 2016, ITC Holdings had $139.2 million and $160.9 million outstanding under the 5.875% Senior Notes and Term Loan, respectively. See Note 5 to the condensed consolidated financial statements for further discussion on these interest rate swaps.

Other

As described in our Form 10-K for the fiscal year ended December 31, 2015, we are subject to commodity price risk from market price fluctuations, and to credit risk primarily with DTE Electric, Consumers Energy and IP&L, our primary customers. There have been no material changes in these risks during the three months ended March 31, 2016.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to provide reasonable assurance that material information required to be disclosed in our reports that we file or submit under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and 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 financial disclosure. In designing and evaluating the disclosure controls and procedures, management recognized that a control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, with a company have been detected.

As of the end of the period covered by this report, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective at a reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes in our internal control over financial reporting during the three months ended March 31, 2016 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

See Note 3 to the condensed consolidated financial statements for discussion of the challenges against ITC Midwest and METC relating to the use of bonus depreciation as well as Note 10 to the condensed consolidated financial statements for a description of recent developments in the ROE complaints filed against all MISO TOs, including our MISO Regulated Operating Subsidiaries, and pending litigation associated with the proposed Merger with Fortis.

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ITEM 1A. RISK FACTORS

For information regarding risk factors affecting us, see “Item 1A Risk Factors” of our Form 10-K for the fiscal year ended December 31, 2015. There have been no material changes to the risk factors set forth therein.

ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table sets forth the repurchases of common stock for the quarter ended March 31, 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 (in millions)
Period	Total Number of Shares Purchased	Average Price Paid per Share
January (a)	609	$	39.69	—	$	—
February (a)	12,991	39.82		—	—
March (a)	686	42.66		—	—
Total (b)	14,286	$	39.95	—

____________________________


(a)	Shares acquired were delivered to us by employees as payment of tax withholding obligations due to us upon the vesting of restricted stock.


(b)	Amount does not include 14,589 shares deemed issued and repurchased for accounting purposes in connection with the payment of the exercise price and tax withholding obligations relating to net option exercises.

We currently have no publicly announced share repurchase authorization and are generally restricted by the Merger Agreement from making repurchases without the consent of Fortis.

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ITEM 6. EXHIBITS

The following exhibits are filed as part of this report (unless otherwise noted to be previously filed, and therefore incorporated herein by reference). Our SEC file number is 001-32576.



Exhibit No.			Description of Document

2.1			Agreement and Plan of Merger, dated as of February 9, 2016, among FortisUS Inc., Element Acquisition Sub Inc., Fortis Inc., and ITC Holdings Corp. (filed with Registrant’s Form 8-K filed on February 11, 2016).

4.44			Eighth Supplemental Indenture, dated as of March 31, 2016, between Michigan Electric Transmission Company, LLC and Bank of New York Mellon Trust Company, N.A. (as successor to JPMorgan Chase Bank), as trustee (filed with Registrant’s Form 8-K filed on April 26, 2016)

10.155			Letter Agreement, dated as of February 8, 2016, between ITC Holdings Corp. and Joseph L. Welch (filed with Registrant’s Form 8-K filed on February 11, 2016).

10.156			Summary of 2016 Incentive Compensation Plan.

10.157			Amendment No. 1, dated as of April 7, 2016, to the Revolving Credit Agreement, dated as of March 28, 2014, by and among ITC Holdings, as the borrower, various financial institutions and other persons from time to time parties thereto as lenders, JPMorgan Chase Bank, N.A., as administrative agent, J.P. Morgan Securities LLC, Barclays Bank PLC and Wells Fargo Securities, LLC, as joint lead arrangers and joint bookrunners, and Barclays Bank PLC and Wells Fargo Bank, National Association, as syndication agents (filed with Registrant’s Form 8-K filed on April 11, 2016).

10.158			Amendment No. 1, dated as of April 7, 2016, to the Revolving Credit Agreement, dated as of March 28, 2014, by and among ITCTransmission, as the borrower, various financial institutions and other persons from time to time parties thereto as lenders, JPMorgan Chase Bank, N.A., as administrative agent, J.P. Morgan Securities LLC, Barclays Bank PLC and Wells Fargo Securities, LLC, as joint lead arrangers and joint bookrunners, and Barclays Bank PLC and Wells Fargo Bank, National Association, as syndication agents (filed with Registrant’s Form 8-K filed on April 11, 2016).

10.159			Amendment No. 1, dated as of April 7, 2016, to the Revolving Credit Agreement, dated as of March 28, 2014, by and among METC, as the borrower, various financial institutions and other persons from time to time parties thereto as lenders, JPMorgan Chase Bank, N.A., as administrative agent, J.P. Morgan Securities LLC, Barclays Bank PLC and Wells Fargo Securities, LLC, as joint lead arrangers and joint bookrunners, and Barclays Bank PLC and Wells Fargo Bank, National Association, as syndication agents (filed with Registrant’s Form 8-K filed on April 11, 2016).

10.160			Amendment No. 1, dated as of April 7, 2016, to the Revolving Credit Agreement, dated as of March 28, 2014, by and among ITC Midwest, as the borrower, various financial institutions and other persons from time to time parties thereto as lenders, JPMorgan Chase Bank, N.A., as administrative agent, J.P. Morgan Securities LLC, Barclays Bank PLC and Wells Fargo Securities, LLC, as joint lead arrangers and joint bookrunners, and Barclays Bank PLC and Wells Fargo Bank, National Association, as syndication agents (filed with Registrant’s Form 8-K filed on April 11, 2016).

10.161			Amendment No. 1, dated as of April 7, 2016, to the Revolving Credit Agreement, dated as of March 28, 2014, by and among ITC Great Plains, as the borrower, various financial institutions and other persons from time to time parties thereto as lenders, JPMorgan Chase Bank, N.A., as administrative agent, J.P. Morgan Securities LLC, Barclays Bank PLC and Wells Fargo Securities, LLC, as joint lead arrangers and joint bookrunners, and Barclays Bank PLC and Wells Fargo Bank, National Association, as syndication agents (filed with Registrant’s Form 8-K filed on April 11, 2016).

31.1			Certification of Chief Executive Officer pursuant to Rule 13a-14 of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2			Certification of Chief Financial Officer pursuant to Rule 13a-14 of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32			Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.INS			XBRL Instance Document

101.SCH			XBRL Taxonomy Extension Schema

101.CAL			XBRL Taxonomy Extension Calculation Linkbase

101.DEF			XBRL Taxonomy Extension Definition Database

101.LAB			XBRL Taxonomy Extension Label Linkbase

101.PRE			XBRL Taxonomy Extension Presentation Linkbase

Table of Contents

SIGNATURES

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

Dated: April 28, 2016



ITC HOLDINGS CORP.
By:	/s/ Joseph L. Welch
	Joseph L. Welch
	President and Chief Executive Officer (duly authorized officer)


By:	/s/ Rejji P. Hayes
	Rejji P. Hayes
	Senior Vice President and Chief Financial Officer (principal financial and accounting officer)