Exhibit 4.2

HYDRO ONE LIMITED

MANAGEMENT’S REPORT

The Consolidated Financial Statements, Management’s Discussion and Analysis (MD&A) and related financial information have been prepared by the management of Hydro One Limited (Hydro One or the Company). Management is responsible for the integrity, consistency and reliability of all such information presented. The Consolidated Financial Statements have been prepared in accordance with United States Generally Accepted Accounting Principles and applicable securities legislation. The MD&A has been prepared in accordance with National Instrument 51-102.

The preparation of the Consolidated Financial Statements and information in the MD&A involves the use of estimates and assumptions based on management’s judgment, particularly when transactions affecting the current accounting period cannot be finalized with certainty until future periods. Estimates and assumptions are based on historical experience, current conditions and various other assumptions believed to be reasonable in the circumstances, with critical analysis of the significant accounting policies followed by the Company as described in Note 2 to the Consolidated Financial Statements. The preparation of the Consolidated Financial Statements and the MD&A includes information regarding the estimated impact of future events and transactions. The MD&A also includes information regarding sources of liquidity and capital resources, operating trends, risks and uncertainties. Actual results in the future may differ materially from the present assessment of this information because future events and circumstances may not occur as expected. The Consolidated Financial Statements and MD&A have been properly prepared within reasonable limits of materiality and in light of information up to February 12, 2018.

Management is responsible for establishing and maintaining adequate disclosure controls and procedures and internal control over financial reporting as described in the annual MD&A. Management evaluated the effectiveness of the design and operation of internal control over financial reporting based on the framework and criteria established in the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management concluded that the Company’s internal control over financial reporting was effective at a reasonable level of assurance as of December 31, 2017. As required, the results of that evaluation were reported to the Audit Committee of the Hydro One Board of Directors and the external auditors.

The Consolidated Financial Statements have been audited by KPMG LLP, independent external auditors appointed by the shareholders of the Company. The external auditors’ responsibility is to express their opinion on whether the Consolidated Financial Statements are fairly presented in accordance with United States Generally Accepted Accounting Principles. The Independent Auditors’ Report outlines the scope of their examination and their opinion.

The Hydro One Board of Directors, through its Audit Committee, is responsible for ensuring that management fulfills its responsibilities for financial reporting and internal control over reporting and disclosure. The Audit Committee of Hydro One met periodically with management, the internal auditors and the external auditors to satisfy itself that each group had properly discharged its respective responsibility and to review the Consolidated Financial Statements before recommending approval by the Board of Directors. The external auditors had direct and full access to the Audit Committee, with and without the presence of management, to discuss their audit findings.

On behalf of Hydro One’s management:

	Christopher Lopez Senior Vice President, Finance acting in the capacity of chief financial officer
Mayo Schmidt
President and Chief Executive Officer

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HYDRO ONE LIMITED

INDEPENDENT AUDITORS’ REPORT

To the Shareholders of Hydro One Limited

We have audited the accompanying consolidated financial statements of Hydro One Limited, which comprise the consolidated balance sheets as at December 31, 2017 and December 31, 2016, the consolidated statements of operations and comprehensive income, changes in equity and cash flows for the years then ended, and notes, comprising a summary of significant accounting policies and other explanatory information.

Management’s Responsibility for the Consolidated Financial Statements

Management is responsible for the preparation and fair presentation of these consolidated financial statements in accordance with United States Generally Accepted Accounting Principles, and for such internal control as management determines is necessary to enable the preparation of consolidated financial statements that are free from material misstatement, whether due to fraud or error.

Auditors’ Responsibility

Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits in accordance with Canadian generally accepted auditing standards. Those standards require that we comply with ethical requirements and plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the consolidated financial statements. The procedures selected depend on our judgment, including the assessment of the risks of material misstatement of the consolidated financial statements, whether due to fraud or error. In making those risk assessments, we consider internal control relevant to the entity’s preparation and fair presentation of the consolidated financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of accounting estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements.

We believe that the audit evidence we have obtained in our audits is sufficient and appropriate to provide a basis for our audit opinion.

Opinion

In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of Hydro One Limited as at December 31, 2017 and December 31, 2016, and its consolidated results of operations and its consolidated cash flows for the years then ended in accordance with United States Generally Accepted Accounting Principles.

Chartered Professional Accountants, Licensed Public Accountants

Toronto, Canada

February 12, 2018

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HYDRO ONE LIMITED

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

For the years ended December 31, 2017 and 2016

Year ended December 31 (millions of Canadian dollars, except per share amounts)	2017		2016
Revenues
Distribution (includes $279 related party revenues; 2016 – $160) (Note 27)		4,366		4,915
Transmission (includes $1,523 related party revenues; 2016 – $1,553) (Note 27)		1,578		1,584
Other		46		53
		5,990		6,552
Costs
Purchased power (includes $1,594 related party costs; 2016 – $2,103) (Note 27)		2,875		3,427
Operation, maintenance and administration (Note 27)		1,066		1,069
Depreciation and amortization (Note 5)		817		778
		4,758		5,274
Income before financing charges and income taxes		1,232		1,278
Financing charges (Note 6)		439		393
Income before income taxes		793		885
Income taxes (Note 7)		111		139
Net income		682		746
Other comprehensive income		1		—
Comprehensive income		683		746
Net income attributable to:
Noncontrolling interest (Note 26)		6		6
Preferred shareholders		18		19
Common shareholders		658		721
		682		746
Comprehensive income attributable to:
Noncontrolling interest (Note 26)		6		6
Preferred shareholders		18		19
Common shareholders		659		721
		683		746
Earnings per common share(Note 24)
Basic	$	1.11	$	1.21
Diluted	$	1.10	$	1.21
Dividends per common share declared (Note 23)	$	0.87	$	0.97

See accompanying notes to Consolidated Financial Statements.    

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HYDRO ONE LIMITED

CONSOLIDATED BALANCE SHEETS

At December 31, 2017 and 2016

December 31 (millions of Canadian dollars)	2017			2016
Assets
Current assets:
Cash and cash equivalents		25			50
Accounts receivable (Note 8)		636			838
Due from related parties (Note 27)		253			158
Other current assets (Note 9)		105			102
		1,019			1,148
Property, plant and equipment (Note 10)		19,947			19,140
Other long-term assets:
Regulatory assets (Note 12)		3,049			3,145
Deferred income tax assets (Note 7)		987			1,235
Intangible assets (Note 11)		369			349
Goodwill (Note 4)		325			327
Other assets		5			7
		4,735			5,063
Total assets		25,701			25,351
Liabilities
Current liabilities:
Short-term notes payable (Note 15)		926			469
Long-term debt payable within one year (Notes 15, 17)		752			602
Accounts payable and other current liabilities (Note 13)		905			945
Due to related parties (Note 27)		157			147
		2,740			2,163
Long-term liabilities:
Long-term debt (includes $541 measured at fair value; 2016 – $548) (Notes 15, 17)		9,315			10,078
Convertible debentures (Notes 16, 17)		487			—
Regulatory liabilities (Note 12)		128			209
Deferred income tax liabilities (Note 7)		71			60
Other long-term liabilities (Note 14)		2,707			2,752
		12,708			13,099
Total liabilities		15,448			15,262
Contingencies and Commitments (Notes 29, 30)
Subsequent Events (Note 32)
Noncontrolling interest subject to redemption (Note 26)		22			22
Equity
Common shares (Note 22)		5,631			5,623
Preferred shares (Note 22)		418			418
Additional paid-in capital (Note 25)		49			34
Retained earnings		4,090			3,950
Accumulated other comprehensive loss		(7	)		(8	)
Hydro One shareholders’ equity		10,181			10,017
Noncontrolling interest (Note 26)		50			50
Total equity		10,231			10,067
		25,701			25,351

See accompanying notes to Consolidated Financial Statements.

On behalf of the Board of Directors:

David Denison Chair	Philip Orsino Chair, Audit Committee

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HYDRO ONE LIMITED

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

For the years ended December 31, 2017 and 2016

Year ended December 31, 2017 (millions of Canadian dollars)	Common Shares		Preferred Shares		Additional Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Hydro One Shareholders’ Equity			Non- controlling Interest (Note 26)			Total Equity
January 1, 2017		5,623		418		34			3,950			(8	)		10,017			50			10,067
Net income		—		—		—			676			—			676			4			680
Other comprehensive income		—		—		—			—			1			1			—			1
Distributions to noncontrolling interest		—		—		—			—			—			—			(4	)		(4	)
Dividends on preferred shares		—		—		—			(18	)		—			(18	)		—			(18	)
Dividends on common shares		—		—		—			(518	)		—			(518	)		—			(518	)
Common shares issued		8		—		(8	)		—			—			—			—			—
Stock-based compensation (Note 25)		—		—		23			—			—			23			—			23
December 31, 2017		5,631		418		49			4,090			(7	)		10,181			50			10,231
Year ended December 31, 2016 (millions of Canadian dollars)	Common Shares		Preferred Shares		Additional Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Loss			Hydro One Shareholders’ Equity			Non- controlling Interest (Note 26)			Total Equity
January 1, 2016		5,623		418		10			3,806			(8	)		9,849			52			9,901
Net income		—		—		—			740			—			740			4			744
Other comprehensive income		—		—		—			—			—			—			—			—
Distributions to noncontrolling interest		—		—		—			—			—			—			(6	)		(6	)
Dividends on preferred shares		—		—		—			(19	)		—			(19	)		—			(19	)
Dividends on common shares		—		—		—			(577	)		—			(577	)		—			(577	)
Stock-based compensation (Note 25)		—		—		24			—			—			24			—			24
December 31, 2016		5,623		418		34			3,950			(8	)		10,017			50			10,067

See accompanying notes to Consolidated Financial Statements.    

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HYDRO ONE LIMITED

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the years ended December 31, 2017 and 2016

Year ended December 31(millions of Canadian dollars)	2017			2016
Operating activities
Net income		682			746
Environmental expenditures		(24	)		(20	)
Adjustments for non-cash items:
Depreciation and amortization (excluding asset removal costs)		727			688
Regulatory assets and liabilities		112			(16	)
Deferred income taxes		85			114
Other		21			10
Changes in non-cash balances related to operations (Note 28)		113			134
Net cash from operating activities		1,716			1,656
Financing activities
Long-term debt issued		—			2,300
Long-term debt repaid		(602	)		(502	)
Short-term notes issued		3,795			3,031
Short-term notes repaid		(3,338	)		(4,053	)
Convertible debentures issued (Note 16)		513			—
Dividends paid		(536	)		(596	)
Distributions paid to noncontrolling interest		(6	)		(9	)
Other (Note 16)		(27	)		(10	)
Net cash from (used in) financing activities		(201	)		161
Investing activities
Capital expenditures (Note 28)
Property, plant and equipment		(1,467	)		(1,600	)
Intangible assets		(80	)		(61	)
Acquisitions (Note 4)		—			(224	)
Capital contributions received (Note 28)		9			21
Other		(2	)		3
Net cash used in investing activities		(1,540	)		(1,861	)
Net change in cash and cash equivalents		(25	)		(44	)
Cash and cash equivalents, beginning of year		50			94
Cash and cash equivalents, end of year		25			50

See accompanying notes to Consolidated Financial Statements.    

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

For the years ended December 31, 2017 and 2016

1. DESCRIPTION OF THE BUSINESS

Hydro One Limited (Hydro One or the Company) was incorporated on August 31, 2015, under the Business Corporations Act (Ontario). On October 31, 2015, the Company acquired Hydro One Inc., a company previously wholly-owned by the Province of Ontario (Province). The acquisition of Hydro One Inc. by Hydro One was accounted for as a common control transaction and Hydro One is a continuation of business operations of Hydro One Inc. At December 31, 2017, the Province held approximately 47.4% (2016 - 70.1%) of the common shares of Hydro One.

The principal businesses of Hydro One are the transmission and distribution of electricity to customers within Ontario.

2. SIGNIFICANT ACCOUNTING POLICIES

Basis of Consolidation

These Consolidated Financial Statements include the accounts of the Company and its subsidiaries. Intercompany transactions and balances have been eliminated.

Basis of Accounting

These Consolidated Financial Statements are prepared and presented in accordance with United States (US) Generally Accepted Accounting Principles (GAAP) and in Canadian dollars.

Use of Management Estimates

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses, gains and losses during the reporting periods. Management evaluates these estimates on an ongoing basis based upon historical experience, current conditions, and assumptions believed to be reasonable at the time the assumptions are made, with any adjustments being recognized in results of operations in the period they arise. Significant estimates relate to regulatory assets and regulatory liabilities, environmental liabilities, pension benefits, post-retirement and post-employment benefits, asset retirement obligations, goodwill and asset impairments, contingencies, unbilled revenues, and deferred income tax assets and liabilities. Actual results may differ significantly from these estimates.

Rate Setting

The Company’s Transmission Business consists of the transmission business of Hydro One Inc., which includes the transmission business of Hydro One Networks Inc. (Hydro One Networks), Hydro One Sault Ste. Marie LP (HOSSM) (formerly Great Lakes Power Transmission LP), and its 66% interest in B2M Limited Partnership (B2M LP). The Company’s Distribution Business consists of the distribution business of Hydro One Inc., which includes the distribution businesses of Hydro One Networks, as well as Hydro One Remote Communities Inc. (Hydro One Remote Communities).

Transmission

In November 2017, the Ontario Energy Board (OEB) approved Hydro One Networks’ 2017 transmission rates revenue requirement of $1,438 million. See Note 12 - Regulatory Assets and Liabilities for additional information.

In December 2015, the OEB approved B2M LP’s 2015-2019 rates revenue requirements of $39 million, $36 million, $37 million, $38 million and $37 million for the respective years. On January 14, 2016, the OEB approved the B2M LP revenue requirement recovery through the 2016 Uniform Transmission Rates, and the establishment of a deferral account to capture costs of Tax Rate and Rule changes. On June 8, 2017, the OEB approved the 2017 rates revenue requirement of $34 million, updated for the cost of capital parameters.

On September 28, 2017, the OEB issued its Decision and Order on HOSSM’s 2017 transmission rates application, denying the requested revenue requirement for 2017. HOSSM’s 2016 approved revenue requirement of $41 million will remain in effect for 2017.

Distribution

In March 2015, the OEB approved Hydro One Networks’ distribution revenue requirements of $1,326 million for 2015, $1,430 million for 2016 and $1,486 million for 2017. The OEB has subsequently approved updated revenue requirements of $1,410 million for 2016 and $1,415 million for 2017.

On March 30, 2017, the OEB approved an increase of 1.9% to Hydro One Remote Communities’ basic rates for the distribution and generation of electricity, with an effective date of May 1, 2017.

Regulatory Accounting

The OEB has the general power to include or exclude revenues, costs, gains or losses in the rates of a specific period, resulting in a change in the timing of accounting recognition from that which would have been applied in an unregulated company. Such change in timing involves the application of rate-regulated accounting, giving rise to the recognition of regulatory assets and liabilities. The

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Company’s regulatory assets represent amounts receivable from future customers and costs that have been deferred for accounting purposes because it is probable that they will be recovered in future rates. In addition, the Company has recorded regulatory liabilities that generally represent amounts that are refundable to future customers. The Company continually assesses the likelihood of recovery of each of its regulatory assets and continues to believe that it is probable that the OEB will include its regulatory assets and liabilities in setting future rates. If, at some future date, the Company judges that it is no longer probable that the OEB will include a regulatory asset or liability in setting future rates, the appropriate carrying amount would be reflected in results of operations in the period that the assessment is made.

Cash and Cash Equivalents

Cash and cash equivalents include cash and short-term investments with an original maturity of three months or less.

Revenue Recognition

Transmission revenues are collected through OEB-approved rates, which are based on an approved revenue requirement that includes a rate of return. Such revenue is recognized as electricity is transmitted and delivered to customers.

Distribution revenues attributable to the delivery of electricity are based on OEB-approved distribution rates and are recognized on an accrual basis and include billed and unbilled revenues. Billed revenues are based on electricity delivered as measured from customer meters. At the end of each month, electricity delivered to customers since the date of the last billed meter reading is estimated, and the corresponding unbilled revenue is recorded. The unbilled revenue estimate is affected by energy consumption, weather, and changes in the composition of customer classes.

Distribution revenue also includes an amount relating to rate protection for rural, residential, and remote customers, which is received from the Independent Electricity System Operator (IESO) based on a standardized customer rate that is approved by the OEB.

Revenues also include amounts related to sales of other services and equipment. Such revenue is recognized as services are rendered or as equipment is delivered.

Revenues are recorded net of indirect taxes.

Accounts Receivable and Allowance for Doubtful Accounts

Billed accounts receivable are recorded at the invoiced amount, net of allowance for doubtful accounts. Unbilled accounts receivable are recorded at their estimated value. Overdue amounts related to regulated billings bear interest at OEB-approved rates. The allowance for doubtful accounts reflects the Company’s best estimate of losses on billed accounts receivable balances. The Company estimates the allowance for doubtful accounts on billed accounts receivable by applying internally developed loss rates to the outstanding receivable balances by aging category. Loss rates applied to the billed accounts receivable balances are based on historical overdue balances, customer payments and write-offs. Accounts receivable are written-off against the allowance when they are deemed uncollectible. The allowance for doubtful accounts is affected by changes in volume, prices and economic conditions.

Noncontrolling interest

Noncontrolling interest represents the portion of equity ownership in subsidiaries that is not attributable to shareholders of Hydro One. Noncontrolling interest is initially recorded at fair value and subsequently the amount is adjusted for the proportionate share of net income and other comprehensive income (OCI) attributable to the noncontrolling interest and any dividends or distributions paid to the noncontrolling interest.

If a transaction results in the acquisition of all, or part, of a noncontrolling interest in a subsidiary, the acquisition of the noncontrolling interest is accounted for as an equity transaction. No gain or loss is recognized in consolidated net income or comprehensive income as a result of changes in the noncontrolling interest, unless a change results in the loss of control by the Company.

Income Taxes

Current and deferred income taxes are computed based on the tax rates and tax laws enacted as at the balance sheet date. Tax benefits associated with income tax positions taken, or expected to be taken, in a tax return are recorded only when the “more-likely-than-not” recognition threshold is satisfied and are measured at the largest amount of benefit that has a greater than 50% likelihood of being realized upon settlement. Management evaluates each position based solely on the technical merits and facts and circumstances of the position, assuming the position will be examined by a taxing authority having full knowledge of all relevant information. Significant management judgment is required to determine recognition thresholds and the related amount of tax benefits to be recognized in the Consolidated Financial Statements. Management re-evaluates tax positions each period using new information about recognition or measurement as it becomes available.

Deferred Income Taxes

Deferred income taxes are provided for using the liability method. Under this method, deferred income tax liabilities are recognized on all taxable temporary differences between the tax bases and carrying amounts of assets and liabilities. Deferred income tax assets are recognized for deductible temporary differences between tax bases and carrying amounts of assets and liabilities, the carry forward unused tax credits and tax losses to the extent that it is more-likely-than-not that these deductions, credits, and losses

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

can be utilized. Deferred income tax assets and liabilities are measured at the tax rates that are expected to apply in the period when the liability is settled or the asset is realized, based on the tax rates and tax laws that have been enacted as at the balance sheet date. Deferred income taxes that are not included in the rate-setting process are charged or credited to the Consolidated Statements of Operations and Comprehensive Income.

Management reassesses the deferred income tax assets at each balance sheet date and reduces the amount to the extent that it is more-likely-than-not that the deferred income tax asset will not be realized. Previously unrecognized deferred income tax assets are reassessed at each balance sheet date and are recognized to the extent that it has become more-likely-than-not that the tax benefit will be realized.

The Company records regulatory assets and liabilities associated with deferred income tax assets and liabilities that will be included in the rate-setting process.

The Company uses the flow-through method to account for investment tax credits (ITCs) earned on eligible scientific research and experimental development expenditures, and apprenticeship job creation. Under this method, only non-refundable ITCs are recognized as a reduction to income tax expense.

Materials and Supplies

Materials and supplies represent consumables, small spare parts and construction materials held for internal construction and maintenance of property, plant and equipment. These assets are carried at average cost less any impairments recorded.

Property, Plant and Equipment

Property, plant and equipment is recorded at original cost, net of customer contributions, and any accumulated impairment losses. The cost of additions, including betterments and replacement asset components, is included on the Consolidated Balance Sheets as property, plant and equipment.

The original cost of property, plant and equipment includes direct materials, direct labour (including employee benefits), contracted services, attributable capitalized financing costs, asset retirement costs, and direct and indirect overheads that are related to the capital project or program. Indirect overheads include a portion of corporate costs such as finance, treasury, human resources, information technology and executive costs. Overhead costs, including corporate functions and field services costs, are capitalized on a fully allocated basis, consistent with an OEB-approved methodology.

Property, plant and equipment in service consists of transmission, distribution, communication, administration and service assets and land easements. Property, plant and equipment also includes future use assets, such as land, major components and spare parts, and capitalized project development costs associated with deferred capital projects.

Transmission

Transmission assets include assets used for the transmission of high-voltage electricity, such as transmission lines, support structures, foundations, insulators, connecting hardware and grounding systems, and assets used to step up the voltage of electricity from generating stations for transmission and to step down voltages for distribution, including transformers, circuit breakers and switches.

Distribution

Distribution assets include assets related to the distribution of low-voltage electricity, including lines, poles, switches, transformers, protective devices and metering systems.

Communication

Communication assets include fibre optic and microwave radio systems, optical ground wire, towers, telephone equipment and associated buildings.

Administration and Service

Administration and service assets include administrative buildings, personal computers, transport and work equipment, tools and other minor assets.

Easements

Easements include statutory rights of use for transmission corridors and abutting lands granted under the Reliable Energy and Consumer Protection Act, 2002, as well as other land access rights.

Intangible Assets

Intangible assets separately acquired or internally developed are measured on initial recognition at cost, which comprises purchased software, direct labour (including employee benefits), consulting, engineering, overheads and attributable capitalized financing charges. Following initial recognition, intangible assets are carried at cost, net of any accumulated amortization and accumulated impairment losses. The Company’s intangible assets primarily represent major computer applications.

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Capitalized Financing Costs

Capitalized financing costs represent interest costs attributable to the construction of property, plant and equipment or development of intangible assets. The financing cost of attributable borrowed funds is capitalized as part of the acquisition cost of such assets. The capitalized financing costs are a reduction of financing charges recognized in the Consolidated Statements of Operations and Comprehensive Income. Capitalized financing costs are calculated using the Company’s weighted average effective cost of debt.

Construction and Development in Progress

Construction and development in progress consists of the capitalized cost of constructed assets that are not yet complete and which have not yet been placed in service.

Depreciation and Amortization

The cost of property, plant and equipment and intangible assets is depreciated or amortized on a straight-line basis based on the estimated remaining service life of each asset category, except for transport and work equipment, which is depreciated on a declining balance basis.

The Company periodically initiates an external independent review of its property, plant and equipment and intangible asset depreciation and amortization rates, as required by the OEB. Any changes arising from OEB approval of such a review are implemented on a remaining service life basis, consistent with their inclusion in electricity rates. The most recent reviews resulted in changes to rates effective January 1, 2015 and January 1, 2017 for Hydro One Networks’ distribution and transmission businesses, respectively. A summary of average service lives and depreciation and amortization rates for the various classes of assets is included below:

	Average		Rate
	Service Life		Range		Average
Property, plant and equipment:
Transmission		55 years		1% - 3%		2%
Distribution		46 years		1% - 7%		2%
Communication		16 years		1% - 15%		6%
Administration and service		20 years		1% - 20%		6%
Intangible assets		10 years		10%		10%

In accordance with group depreciation practices, the original cost of property, plant and equipment, or major components thereof, and intangible assets that are normally retired, is charged to accumulated depreciation, with no gain or loss being reflected in results of operations. Where a disposition of property, plant and equipment occurs through sale, a gain or loss is calculated based on proceeds and such gain or loss is included in depreciation expense.

Acquisitions and Goodwill

The Company accounts for business acquisitions using the acquisition method of accounting and, accordingly, the assets and liabilities of the acquired entities are primarily measured at their estimated fair value at the date of acquisition. Costs associated with pending acquisitions are expensed as incurred. Goodwill represents the cost of acquired companies that is in excess of the fair value of the net identifiable assets acquired at the acquisition date. Goodwill is not included in rate base.

Goodwill is evaluated for impairment on an annual basis, or more frequently if circumstances require. The Company performs a qualitative assessment to determine whether it is more-likely-than-not that the fair value of the applicable reporting unit is less than its carrying amount. If the Company determines, as a result of its qualitative assessment, that it is not more-likely-than-not that the fair value of the applicable reporting unit is less than its carrying amount, no further testing is required. If the Company determines, as a result of its qualitative assessment, that it is more-likely-than-not that the fair value of the applicable reporting unit is less than its carrying amount, a goodwill impairment assessment is performed using a two-step, fair value-based test. The first step compares the fair value of the applicable reporting unit to its carrying amount, including goodwill. If the carrying amount of the applicable reporting unit exceeds its fair value, a second step is performed. The second step requires an allocation of fair value to the individual assets and liabilities using purchase price allocation in order to determine the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, an impairment loss is recorded as a reduction to goodwill and as a charge to results of operations.

Based on assessment performed as at September 30, 2017, the Company has concluded that goodwill was not impaired at December 31, 2017.

Long-Lived Asset Impairment

When circumstances indicate the carrying value of long-lived assets may not be recoverable, the Company evaluates whether the carrying value of such assets, excluding goodwill, has been impaired. For such long-lived assets, the Company evaluates whether impairment may exist by estimating future estimated undiscounted cash flows expected to result from the use and eventual disposition of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, a probability-weighted approach is used to develop estimates of future undiscounted cash flows. If the carrying value of the long-lived

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

asset is not recoverable based on the estimated future undiscounted cash flows, an impairment loss is recorded, measured as the excess of the carrying value of the asset over its fair value. As a result, the asset’s carrying value is adjusted to its estimated fair value.

Within its regulated business, the carrying costs of most of Hydro One’s long-lived assets are included in rate base where they earn an OEB-approved rate of return. Asset carrying values and the related return are recovered through approved rates. As a result, such assets are only tested for impairment in the event that the OEB disallows recovery, in whole or in part, or if such a disallowance is judged to be probable.

Hydro One regularly monitors the assets of its unregulated Hydro One Telecom subsidiary for indications of impairment. Management assesses the fair value of such long-lived assets using commonly accepted techniques. Techniques used to determine fair value include, but are not limited to, the use of recent third-party comparable sales for reference and internally developed discounted cash flow analysis. Significant changes in market conditions, changes to the condition of an asset, or a change in management’s intent to utilize the asset are generally viewed by management as triggering events to reassess the cash flows related to these long-lived assets. As at December 31, 2017 and 2016, no asset impairment had been recorded for assets within either the Company’s regulated or unregulated businesses.

Costs of Arranging Debt Financing

For financial liabilities classified as other than held-for-trading and for convertible debentures, the Company defers the external transaction costs related to obtaining financing and presents such amounts net of related debt or convertible debentures on the Consolidated Balance Sheets. Deferred issuance costs are amortized over the contractual life of the related debt or convertible debentures on an effective-interest basis and the amortization is included within financing charges in the Consolidated Statements of Operations and Comprehensive Income. Transaction costs for items classified as held-for-trading are expensed immediately.

Comprehensive Income

Comprehensive income is comprised of net income and OCI. Hydro One presents net income and OCI in a single continuous Consolidated Statement of Operations and Comprehensive Income.

Financial Assets and Liabilities

All financial assets and liabilities are classified into one of the following five categories: held-to-maturity; loans and receivables; held-for-trading; other liabilities; or available-for-sale. Financial assets and liabilities classified as held-for-trading are measured at fair value. All other financial assets and liabilities are measured at amortized cost, except accounts receivable and amounts due from related parties, which are measured at the lower of cost or fair value. Accounts receivable and amounts due from related parties are classified as loans and receivables. The Company considers the carrying amounts of accounts receivable and amounts due from related parties to be reasonable estimates of fair value because of the short time to maturity of these instruments. Provisions for impaired accounts receivable are recognized as adjustments to the allowance for doubtful accounts and are recognized when there is objective evidence that the Company will not be able to collect amounts according to the original terms. All financial instrument transactions are recorded at trade date.

Derivative instruments are measured at fair value. Gains and losses from fair valuation are included within financing charges in the period in which they arise. The Company determines the classification of its financial assets and liabilities at the date of initial recognition. The Company designates certain of its financial assets and liabilities to be held at fair value, when it is consistent with the Company’s risk management policy disclosed in Note 17 - Fair Value of Financial Instruments and Risk Management.

Derivative Instruments and Hedge Accounting

The Company closely monitors the risks associated with changes in interest rates on its operations and, where appropriate, uses various instruments to hedge these risks. Certain of these derivative instruments qualify for hedge accounting and are designated as accounting hedges, while others either do not qualify as hedges or have not been designated as hedges (hereinafter referred to as undesignated contracts) as they are part of economic hedging relationships.

The accounting guidance for derivative instruments requires the recognition of all derivative instruments not identified as meeting the normal purchase and sale exemption as either assets or liabilities recorded at fair value on the Consolidated Balance Sheets. For derivative instruments that qualify for hedge accounting, the Company may elect to designate such derivative instruments as either cash flow hedges or fair value hedges. The Company offsets fair value amounts recognized on its Consolidated Balance Sheets related to derivative instruments executed with the same counterparty under the same master netting agreement.

For derivative instruments that qualify for hedge accounting and which are designated as cash flow hedges, the effective portion of any gain or loss, net of tax, is reported as a component of accumulated OCI (AOCI) and is reclassified to results of operations in the same period or periods during which the hedged transaction affects results of operations. Any gains or losses on the derivative instrument that represent either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in results of operations. For fair value hedges, changes in fair value of both the derivative instrument and the underlying hedged exposure are recognized in the Consolidated Statements of Operations and Comprehensive Income in the current period. The gain or loss on the derivative instrument is included in the same line item as the offsetting gain or loss on the hedged item in

11

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

the Consolidated Statements of Operations and Comprehensive Income. The changes in fair value of the undesignated derivative instruments are reflected in results of operations.

Embedded derivative instruments are separated from their host contracts and are carried at fair value on the Consolidated Balance Sheets when: (a) the economic characteristics and risks of the embedded derivative are not clearly and closely related to the economic characteristics and risks of the host contract; (b) the hybrid instrument is not measured at fair value, with changes in fair value recognized in results of operations each period; and (c) the embedded derivative itself meets the definition of a derivative. The Company does not engage in derivative trading or speculative activities and had no embedded derivatives that required bifurcation at December 31, 2017 or 2016.

Hydro One periodically develops hedging strategies taking into account risk management objectives. At the inception of a hedging relationship where the Company has elected to apply hedge accounting, Hydro One formally documents the relationship between the hedged item and the hedging instrument, the related risk management objective, the nature of the specific risk exposure being hedged, and the method for assessing the effectiveness of the hedging relationship. The Company also assesses, both at the inception of the hedge and on a quarterly basis, whether the hedging instruments are effective in offsetting changes in fair values or cash flows of the hedged items.

Employee Future Benefits

Employee future benefits provided by Hydro One include pension, post-retirement and post-employment benefits. The costs of the Company’s pension, post-retirement and post-employment benefit plans are recorded over the periods during which employees render service.

The Company recognizes the funded status of its defined benefit pension, post-retirement and post-employment plans on its Consolidated Balance Sheets and subsequently recognizes the changes in funded status at the end of each reporting year. Defined benefit pension, post-retirement and post-employment plans are considered to be underfunded when the projected benefit obligation exceeds the fair value of the plan assets. Liabilities are recognized on the Consolidated Balance Sheets for any net underfunded projected benefit obligation. The net underfunded projected benefit obligation may be disclosed as a current liability, long-term liability, or both. The current portion is the amount by which the actuarial present value of benefits included in the benefit obligation payable in the next 12 months exceeds the fair value of plan assets. If the fair value of plan assets exceeds the projected benefit obligation of the plan, an asset is recognized equal to the net overfunded projected benefit obligation. The post-retirement and post-employment benefit plans are unfunded because there are no related plan assets.

Hydro One recognizes its contributions to the defined contribution pension plan as pension expense, with a portion being capitalized as part of labour costs included in capital expenditures. The expensed amount is included in operation, maintenance and administration costs in the Consolidated Statements of Operations and Comprehensive Income.

Defined Benefit Pension

Defined benefit pension costs are recorded on an accrual basis for financial reporting purposes. Pension costs are actuarially determined using the projected benefit method prorated on service and are based on assumptions that reflect management’s best estimate of the effect of future events, including future compensation increases. Past service costs from plan amendments and all actuarial gains and losses are amortized on a straight-line basis over the expected average remaining service period of active employees in the plan, and over the estimated remaining life expectancy of inactive employees in the plan. Pension plan assets, consisting primarily of listed equity securities as well as corporate and government debt securities, are fair valued at the end of each year. Hydro One records a regulatory asset equal to the net underfunded projected benefit obligation for its pension plan.

Post-retirement and Post-employment Benefits

Post-retirement and post-employment benefits are recorded and included in rates on an accrual basis. Costs are determined by independent actuaries using the projected benefit method prorated on service and based on assumptions that reflect management’s best estimates. Past service costs from plan amendments are amortized to results of operations based on the expected average remaining service period.

For post-retirement benefits, all actuarial gains or losses are deferred using the “corridor” approach. The amount calculated above the “corridor” is amortized to results of operations on a straight-line basis over the expected average remaining service life of active employees in the plan and over the remaining life expectancy of inactive employees in the plan. The post-retirement benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory asset, to the extent of the remeasurement adjustment.

For post-employment obligations, the associated regulatory liabilities representing actuarial gains on transition to US GAAP are amortized to results of operations based on the “corridor” approach. The actuarial gains and losses on post-employment obligations that are incurred during the year are recognized immediately to results of operations. The post-employment benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory asset, to the extent of the remeasurement adjustment.

All post-retirement and post-employment future benefit costs are attributed to labour and are either charged to results of operations or capitalized as part of the cost of property, plant and equipment and intangible assets.

12

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Stock-Based Compensation

Share Grant Plans

Hydro One measures share grant plans based on fair value of share grants as estimated based on the grant date common share price. The costs are recognized in the financial statements using the graded-vesting attribution method for share grant plans that have both a performance condition and a service condition. The Company records a regulatory asset equal to the accrued costs of share grant plans recognized in each period. Costs are transfered from the regulatory asset to labour costs at the time the share grants vest and are issued, and are recovered in rates. Forfeitures are recognized as they occur.

Deferred Share Unit (DSU) Plans

The Company records the liabilities associated with its Directors’ and Management DSU Plans at fair value at each reporting date until settlement, recognizing compensation expense over the vesting period on a straight-line basis. The fair value of the DSU liability is based on the Company’s common share closing price at the end of each reporting period.

Long-term Incentive Plan (LTIP)

The Company measures the restricted share units (RSUs) and performance share units (PSUs), issued under its LTIP, at fair value based on the grant date common share price. The related compensation expense is recognized over the vesting period on a straight-line basis. Forfeitures are recognized as they occur.

Loss Contingencies

Hydro One is involved in certain legal and environmental matters that arise in the normal course of business. In the preparation of its Consolidated Financial Statements, management makes judgments regarding the future outcome of contingent events and records a loss for a contingency based on its best estimate when it is determined that such loss is probable and the amount of the loss can be reasonably estimated. Where the loss amount is recoverable in future rates, a regulatory asset is also recorded. When a range estimate for the probable loss exists and no amount within the range is a better estimate than any other amount, the Company records a loss at the minimum amount within the range.

Management regularly reviews current information available to determine whether recorded provisions should be adjusted and whether new provisions are required. Estimating probable losses may require analysis of multiple forecasts and scenarios that often depend on judgments about potential actions by third parties, such as federal, provincial and local courts or regulators. Contingent liabilities are often resolved over long periods of time. Amounts recorded in the Consolidated Financial Statements may differ from the actual outcome once the contingency is resolved. Such differences could have a material impact on future results of operations, financial position and cash flows of the Company.

Provisions are based upon current estimates and are subject to greater uncertainty where the projection period is lengthy. A significant upward or downward trend in the number of claims filed, the nature of the alleged injuries, and the average cost of resolving each claim could change the estimated provision, as could any substantial adverse or favourable verdict at trial. A federal or provincial legislative outcome or structured settlement could also change the estimated liability. Legal fees are expensed as incurred.

Environmental Liabilities

Environmental liabilities are recorded in respect of past contamination when it is determined that future environmental remediation expenditures are probable under existing statute or regulation and the amount of the future expenditures can be reasonably estimated. Hydro One records a liability for the estimated future expenditures associated with contaminated land assessment and remediation and for the phase-out and destruction of polychlorinated biphenyl (PCB)-contaminated mineral oil removed from electrical equipment, based on the present value of these estimated future expenditures. The Company determines the present value with a discount rate equal to its credit-adjusted risk-free interest rate on financial instruments with comparable maturities to the pattern of future environmental expenditures. As the Company anticipates that the future expenditures will continue to be recoverable in future rates, an offsetting regulatory asset has been recorded to reflect the future recovery of these environmental expenditures from customers. Hydro One reviews its estimates of future environmental expenditures annually, or more frequently if there are indications that circumstances have changed.

Asset Retirement Obligations

Asset retirement obligations are recorded for legal obligations associated with the future removal and disposal of long-lived assets. Such obligations may result from the acquisition, construction, development and/or normal use of the asset. Conditional asset retirement obligations are recorded when there is a legal obligation to perform a future asset retirement activity but where the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the Company. In such a case, the obligation to perform the asset retirement activity is unconditional even though uncertainty exists about the timing and/or method of settlement.

When recording an asset retirement obligation, the present value of the estimated future expenditures required to complete the asset retirement activity is recorded in the period in which the obligation is incurred, if a reasonable estimate can be made. In general, the present value of the estimated future expenditures is added to the carrying amount of the associated asset and the

13

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

resulting asset retirement cost is depreciated over the estimated useful life of the asset. Where an asset is no longer in service when an asset retirement obligation is recorded, the asset retirement cost is recorded in results of operations.

Some of the Company’s transmission and distribution assets, particularly those located on unowned easements and rights-of-way, may have asset retirement obligations, conditional or otherwise. The majority of the Company’s easements and rights-of-way are either of perpetual duration or are automatically renewed annually. Land rights with finite terms are generally subject to extension or renewal. As the Company expects to use the majority of its facilities in perpetuity, no asset retirement obligations have been recorded for these assets. If, at some future date, a particular facility is shown not to meet the perpetuity assumption, it will be reviewed to determine whether an estimable asset retirement obligation exists. In such a case, an asset retirement obligation would be recorded at that time.

The Company’s asset retirement obligations recorded to date relate to estimated future expenditures associated with the removal and disposal of asbestos-containing materials installed in some of its facilities.

3. NEW ACCOUNTING PRONOUNCEMENTS

The following tables present Accounting Standards Updates (ASUs) issued by the Financial Accounting Standards Board that are applicable to Hydro One:

Recently Adopted Accounting Guidance

ASU	Date issued	Description	Effective date	Anticipated impact on Hydro One
2016-06	March 2016	Contingent call (put) options that are assessed to accelerate the payment of principal on debt instruments need to meet the criteria of being “clearly and closely related” to their debt hosts.	January 1, 2017	No impact upon adoption
Recently Issued Accounting Guidance Not Yet Adopted
ASU	Date issued	Description	Effective date	Anticipated impact on Hydro One
2014-09   2015-14   2016-08   2016-10   2016-12   2016-20   2017-05   2017-10   2017-13   2017-14	May 2014 – November 2017	ASU 2014-09 was issued in May 2014 and provides guidance on revenue recognition relating to the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. ASU 2015-14 deferred the effective date of ASU 2014-09 by one year. Additional ASUs were issued in 2016 and 2017 that simplify transition and provide clarity on certain aspects of the new standard.	January 1, 2018	Hydro One has completed the review of all its revenue streams and has concluded that there will be no material impact upon adoption.
2016-02   2018-01	February 2016 – January 2018	Lessees are required to recognize the rights and obligations resulting from operating leases as assets (right to use the underlying asset for the term of the lease) and liabilities (obligation to make future lease payments) on the balance sheet. ASU 2018-01 permits an entity to elect an optional practical expedient to not evaluate under Topic 842 land easements that exist or expired before the entity’s adoption of Topic 842 and that were not previously accounted for as leases under Topic 840.	January 1, 2019	An initial assessment is currently underway encompassing a review of existing leases, which will be followed by a review of relevant contracts. No quantitative determination has been made at this time. The Company is on track for implementation of this standard by the effective date.
2016-15	August 2016	The amendments provide guidance for eight specific cash flow issues with the objective of reducing the existing diversity in practice.	January 1, 2018	No material impact
2017-01	January 2017	The amendment clarifies the definition of a business and provides additional guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses.	January 1, 2018	No material impact
2017-04	January 2017	The amendment removes the second step of the current two-step goodwill impairment test to simplify the process of testing goodwill.	January 1, 2020	Under assessment
2017-07	March 2017	Service cost components of net benefit cost associated with defined benefit plans are required to be reported in the same line as other compensation costs arising from services rendered by the Company’s employees. All other components of net benefit cost are to be presented in the income statement separately from the service cost component. Only the service cost component is eligible for capitalization where applicable.	January 1, 2018	Hydro One has applied for a regulatory deferral account to maintain the capitalization of OPEB related costs. As such, there will be no material impact.

14

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

ASU	Date issued	Description	Effective date	Anticipated impact on Hydro One
2017-09	May 2017	Changes to the terms or conditions of a share-based payment award will require an entity to apply modified accounting unless the modified award meets all conditions stipulated in this ASU.	January 1, 2018	No impact
2017-11	July 2017	When determining whether certain financial instruments should be classified as liabilities or equity instruments, a down round feature no longer precludes equity classification when assessing whether the instrument is indexed to an entity’s own stock.	January 1, 2019	Under assessment
2017-12	August 2017	Amendments will better align an entity’s risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results.	January 1, 2019	Under assessment

4. BUSINESS COMBINATIONS

Avista Corporation Purchase Agreement

On July 19, 2017, Hydro One reached an agreement to acquire Avista Corporation (Merger) for approximately $6.7 billion in an all-cash transaction. Avista Corporation is an investor-owned utility providing electric generation, transmission, and distribution services. It is headquartered in Spokane, Washington, with service areas in Washington, Idaho, Oregon, Montana and Alaska. The closing of the Merger is subject to receipt of certain regulatory and government approvals, and the satisfaction of customary closing conditions. See Note 16 - Convertible Debentures and Note 17 - Fair Value of Financial Instruments and Risk Management for details of convertible debentures and foreign exchange contract, respectively, related to financing of the Merger.

Acquisition of HOSSM

On October 31, 2016, Hydro One acquired HOSSM, an Ontario regulated electricity transmission business operating along the eastern shore of Lake Superior, north and east of Sault Ste. Marie, Ontario from Brookfield Infrastructure Holdings Inc. The total purchase price for HOSSM was approximately $376 million, including the assumption of approximately $150 million in outstanding indebtedness. During 2017, the Company completed the final determination of the fair value of assets acquired and liabilities assumed with no significant changes, which resulted in a total goodwill of approximately $157 million arising from the HOSSM acquisition. The difference between the preliminary and final purchase price allocation to fair value of assets acquired and liabilities related to a $2 million decrease in deferred income tax liabilities which resulted in a corresponding decrease to goodwill. The following table summarizes the final fair value of the assets acquired and liabilities assumed:

(millions of dollars)
Cash and cash equivalents	5
Property, plant and equipment	221
Intangible assets	1
Regulatory assets	50
Goodwill	157
Working capital	(2	)
Long-term debt	(186	)
Pension and post-employment benefit liabilities, net	(5	)
Deferred income taxes	(15	)
	226

Goodwill arising from the HOSSM acquisition consists largely of the synergies and economies of scale expected from combining the operations of Hydro One and HOSSM. HOSSM contributed revenues of $6 million and less than $1 million of net income to the Company’s consolidated financial results for the year ended December 31, 2016. All costs related to the acquisition have been expensed through the Consolidated Statements of Operations and Comprehensive Income. HOSSM’s financial information was not material to the Company’s consolidated financial results for the year ended December 31, 2016 and therefore, has not been disclosed on a pro forma basis.

Agreement to Purchase Orillia Power

On August 15, 2016, the Company reached an agreement to acquire Orillia Power Distribution Corporation (Orillia Power), an electricity distribution company located in Simcoe County, Ontario, from the City of Orillia for approximately $41 million, including the assumption of approximately $15 million in outstanding indebtedness and regulatory liabilities, subject to closing adjustments. The acquisition is subject to regulatory approval by the OEB.

15

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

5. DEPRECIATION AND AMORTIZATION

Year ended December 31 (millions of dollars)	2017			2016
Depreciation of property, plant and equipment		641			612
Asset removal costs		90			90
Amortization of intangible assets		62			56
Amortization of regulatory assets		24			20
		817			778
6.   FINANCING CHARGES
Year ended December 31 (millions of dollars)	2017			2016
Interest on long-term debt		450			424
Interest on convertible debentures		24			—
Interest on short-term notes		6			9
Unrealized loss on foreign exchange contract		3			—
Other		14			16
Less:   Interest capitalized on construction and development in progress		(56	)		(54	)
Interest earned on cash and cash equivalents		(2	)		(2	)
		439			393

7. INCOME TAXES

Income tax expense differs from the amount that would have been recorded using the combined Canadian federal and Ontario statutory income tax rate. The reconciliation between the statutory and the effective tax rates is provided as follows:

Year ended December 31 (millions of dollars)	2017			2016
Income before income taxes		793			885
Income taxes at statutory rate of 26.5% (2016 - 26.5%)		210			235
Increase (decrease) resulting from:
Net temporary differences recoverable in future rates charged to customers:
Capital cost allowance in excess of depreciation and amortization		(55	)		(53	)
Pension contributions in excess of pension expense		(13	)		(16	)
Overheads capitalized for accounting but deducted for tax purposes		(17	)		(16	)
Interest capitalized for accounting but deducted for tax purposes		(15	)		(14	)
Environmental expenditures		(6	)		(5	)
Other		3			5
Net temporary differences		(103	)		(99	)
Net permanent differences		4			3
Total income taxes		111			139
The major components of income tax expense are as follows:
Year ended December 31 (millions of dollars)	2017			2016
Current income taxes		26			25
Deferred income taxes		85			114
Total income taxes		111			139
Effective income tax rate		14.0%			15.7%

16

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Deferred Income Tax Assets and Liabilities

Deferred income tax assets and liabilities expected to be included in the rate-setting process are offset by regulatory assets and liabilities to reflect the anticipated recovery or disposition of these balances within future electricity rates. Deferred income tax assets and liabilities arise from differences between the tax basis and the carrying amounts of the assets and liabilities. At December 31, 2017 and 2016, deferred income tax assets and liabilities consisted of the following:

December 31 (millions of dollars)	2017			2016
Deferred income tax assets
Depreciation and amortization in excess of capital cost allowance		125			495
Non-depreciable capital property		271			271
Post-retirement and post-employment benefits expense in excess of cash payments		561			607
Environmental expenditures		71			74
Non-capital losses		255			213
Tax credit carryforwards		49			27
Investment in subsidiaries		84			75
Other		13			3
		1,429			1,765
Less: valuation allowance		(364	)		(352	)
Total deferred income tax assets		1,065			1,413
Less: current portion		—			—
		1,065			1,413
Deferred income tax liabilities
Regulatory amounts that are not recognized for tax purposes		(47	)		(153	)
Goodwill		(10	)		(10	)
Capital cost allowance in excess of depreciation and amortization		(75	)		(64	)
Other		(17	)		(11	)
Total deferred income tax liabilities		(149	)		(238	)
Less: current portion		—			—
		(149	)		(238	)
Net deferred income tax assets		916			1,175

The net deferred income tax assets are presented on the Consolidated Balance Sheets as follows:

December 31(millions of dollars)	2017			2016
Long-term:
Deferred income tax assets		987			1,235
Deferred income tax liabilities		(71	)		(60	)
Net deferred income tax assets		916			1,175

The valuation allowance for deferred tax assets as at December 31, 2017 was $364 million (2016 - $352 million). The valuation allowance primarily relates to temporary differences for non-depreciable assets and investments in subsidiaries. As of December 31, 2017 and 2016, the Company had non-capital losses carried forward available to reduce future years’ taxable income, which expire as follows:

Year of expiry (millions of dollars)	2017		2016
2034		2		2
2035		222		222
2036		560		580
2037		175		—
Total losses		959		804

17

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

8. ACCOUNTS RECEIVABLE

December 31 (millions of dollars)	2017			2016
Accounts receivable – billed		298			431
Accounts receivable – unbilled		367			442
Accounts receivable, gross		665			873
Allowance for doubtful accounts		(29	)		(35	)
Accounts receivable, net		636			838
The following table shows the movements in the allowance for doubtful accounts for the years ended December 31, 2017 and 2016:
Year ended December 31 (millions of dollars)	2017			2016
Allowance for doubtful accounts – beginning		(35	)		(61	)
Write-offs		25			37
Additions to allowance for doubtful accounts		(19	)		(11	)
Allowance for doubtful accounts – ending		(29	)		(35	)
9.   OTHER CURRENT ASSETS
December 31(millions of dollars)	2017			2016
Regulatory assets (Note 12)		46			37
Materials and supplies		18			19
Prepaid expenses and other assets		41			46
		105			102

10. PROPERTY, PLANT AND EQUIPMENT

December 31, 2017(millions of dollars)	Property, Plant and Equipment		Accumulated Depreciation		Construction in Progress		Total
Transmission		15,509		5,162		989		11,336
Distribution		10,213		3,513		149		6,849
Communication		1,266		853		31		444
Administration and service		1,561		857		46		750
Easements		638		70		—		568
		29,187		10,455		1,215		19,947
December 31, 2016(millions of dollars)	Property, Plant and Equipment		Accumulated Depreciation		Construction in Progress		Total
Transmission		14,692		4,862		910		10,740
Distribution		9,656		3,305		243		6,594
Communication		1,233		777		20		476
Administration and service		1,632		924		61		769
Easements		628		67		—		561
		27,841		9,935		1,234		19,140

Financing charges capitalized on property, plant and equipment under construction were $54 million in 2017 (2016 - $52 million).

11. INTANGIBLE ASSETS

December 31, 2017 (millions of dollars)	Intangible Assets		Accumulated Amortization		Development in Progress		Total
Computer applications software		698		370		41		369
Other		5		5		—		—
		703		375		41		369
December 31, 2016 (millions of dollars)	Intangible Assets		Accumulated Amortization		Development in Progress		Total
Computer applications software		621		326		53		348
Other		5		4		—		1
		626		330		53		349

18

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Financing charges capitalized to intangible assets under development were $2 million in 2017 (2016 - $2 million). The estimated annual amortization expense for intangible assets is as follows: 2018 - $67 million; 2019 - $57 million; 2020 - $40 million; 2021 - $39 million; and 2022 - $36 million.

12. REGULATORY ASSETS AND LIABILITIES

Regulatory assets and liabilities arise as a result of the rate-setting process. Hydro One has recorded the following regulatory assets and liabilities:

December 31 (millions of dollars)	2017			2016
Regulatory assets:
Deferred income tax regulatory asset		1,762			1,587
Pension benefit regulatory asset		981			900
Post-retirement and post-employment benefits		36			243
Environmental		196			204
Share-based compensation		40			31
Debt premium		27			32
Foregone revenue deferral		23			—
Distribution system code exemption		10			10
B2M LP start-up costs		4			5
Retail settlement variance account		—			145
2015-2017 rate rider		—			7
Pension cost variance		—			4
Other		16			14
Total regulatory assets		3,095			3,182
Less: current portion		(46	)		(37	)
		3,049			3,145
Regulatory liabilities:
Green Energy expenditure variance		60			69
External revenue variance		46			64
CDM deferral variance		28			54
Pension cost variance		23			—
2015-2017 rate rider		6			—
Deferred income tax regulatory liability		5			4
Other		17			18
Total regulatory liabilities		185			209
Less: current portion		(57	)		—
		128			209

Deferred Income Tax Regulatory Asset and Liability

Deferred income taxes are recognized on temporary differences between the carrying amount of assets and liabilities in the financial statements and the corresponding tax bases used in the computation of taxable income. The Company has recognized regulatory assets and liabilities that correspond to deferred income taxes that flow through the rate-setting process. In the absence of rate-regulated accounting, the Company’s income tax expense would have been recognized using the liability method and there would be no regulatory accounts established for taxes to be recovered through future rates. As a result, the 2017 income tax expense would have been higher by approximately $113 million (2016 - $104 million).

On September 28, 2017, the OEB issued its Decision and Order on Hydro One Networks’ 2017 and 2018 transmission rates revenue requirements (Decision). In its Decision, the OEB concluded that the net deferred tax asset resulting from transition from the payments in lieu of tax regime under the Electricity Act (Ontario) to tax payments under the federal and provincial tax regime should not accrue entirely to Hydro One’s shareholders and that a portion should be shared with ratepayers. On November 9, 2017, the OEB issued a Decision and Order that calculated the portion of the tax savings that should be shared with ratepayers. The OEB’s calculation would result in an impairment of Hydro One Networks’ transmission deferred income tax regulatory asset of up to approximately $515 million. If the OEB were to apply the same calculation for sharing in Hydro One Networks’ 2018-2022 distribution rates, for which a decision is currently outstanding, it would result in an additional impairment of up to approximately $370 million related to Hydro One Networks’ distribution deferred income tax regulatory asset. In October 2017, the Company filed a Motion to Review and Vary (Motion) the Decision and filed an appeal with the Divisional Court of Ontario (Appeal). On December 19, 2017, the OEB granted a hearing of the merits of the Motion which is scheduled for mid-February 2018. In both cases, the Company’s position is that the OEB made errors of fact and law in its determination of allocation of the tax savings between the shareholders and ratepayers. The Appeal is being held in abeyance pending the outcome of the Motion. If the Decision is upheld, based on the facts known at

19

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

this time, the exposure from the potential impairments would be a one-time decrease in net income of up to approximately $885 million. Based on the assumptions that the OEB applies established rate making principles in a manner consistent with its past practice and does not exercise its discretion to take other policy considerations into account, management is of the view that it is likely that the Company’s Motion will be granted and the aforementioned tax savings will be allocated to the benefit of Hydro One shareholders.

Pension Benefit Regulatory Asset

In accordance with OEB rate orders, pension costs are recovered on a cash basis as employer contributions are paid to the pension fund in accordance with the Pension Benefits Act (Ontario). The Company recognizes the net unfunded status of pension obligations on the Consolidated Balance Sheets with an offset to the associated regulatory asset. A regulatory asset is recognized because management considers it to be probable that pension benefit costs will be recovered in the future through the rate-setting process. The pension benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory asset, to the extent of the remeasurement adjustment. In the absence of rate-regulated accounting, OCI would have been lower by $80 million and operation, maintenance and administration expenses would have been higher by $1 million (2016 - OCI higher by $52 million).

Post-Retirement and Post-Employment Benefits

The Company recognizes the net unfunded status of post-retirement and post-employment obligations on the Consolidated Balance Sheets with an incremental offset to the associated regulatory assets. A regulatory asset is recognized because management considers it to be probable that post-retirement and post-employment benefit costs will be recovered in the future through the rate-setting process. The post-retirement and post-employment benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory asset, to the extent of the remeasurement adjustment. In the absence of rate-regulated accounting, 2017 OCI would have been higher by $207 million (2016 - lower by $3 million).

Environmental

Hydro One records a liability for the estimated future expenditures required to remediate environmental contamination. Because such expenditures are expected to be recoverable in future rates, the Company has recorded an equivalent amount as a regulatory asset. In 2017, the environmental regulatory asset increased by $1 million (2016 - decreased by $1 million) to reflect related changes in the Company’s PCB liability, and increased by $7 million (2016 - $10 million) due to changes in the land assessment and remediation liability. The environmental regulatory asset is amortized to results of operations based on the pattern of actual expenditures incurred and charged to environmental liabilities. The OEB has the discretion to examine and assess the prudency and the timing of recovery of all of Hydro One’s actual environmental expenditures. In the absence of rate-regulated accounting, 2017 operation, maintenance and administration expenses would have been higher by $8 million (2016 - $9 million). In addition, 2017 amortization expense would have been lower by $24 million (2016 - $20 million), and 2017 financing charges would have been higher by $8 million (2016 - $8 million).

Share-based Compensation

The Company recognizes costs associated with share grant plans in a regulatory asset as management considers it probable that share grant plans’ costs will be recovered in the future through the rate-setting process. In the absence of rate-regulated accounting, 2017 operation, maintenance and administration expenses would have been higher by $8 million (2016 - $9 million). Share grant costs are transferred to labour costs at the time the share grants vest and are issued, and are recovered in rates in accordance with recovery of said labour costs.

Debt Premium

The value of debt assumed in the acquisition of HOSSM has been recorded at fair value in accordance with US GAAP - Business Combinations. The OEB allows for recovery of interest at the coupon rate of the Senior Secured Bonds and a regulatory asset has been recorded for the difference between the fair value and face value of this debt. The debt premium is recovered over the remaining term of the debt.

Foregone Revenue Deferral

As part of its September 2017 decision on Hydro One Networks’ transmission rate application for 2017 and 2018 rates, the OEB approved the foregone revenue account to record the difference between revenue earned under the rates approved as part of the decision, effective January 1, 2017, and revenue earned under the interim rates until the approved 2017 rates were implemented. The OEB approved a similar account for B2M LP in June 2017 to record the difference between revenue earned under the newly approved rates, effective January 1, 2017, and the revenue recorded under the interim 2017 rates. The balances of these accounts will be returned to or recovered from ratepayers, respectively, over a one-year period ending December 31, 2018. The draft rate order submitted by Hydro One Networks was approved by the OEB in November, 2017. This draft rate order reflects the September 2017 decision, including a reduction of the amount of cash taxes approved for recovery in transmission rates due to the OEB’s basis to share the savings resulting from a deferred tax asset with ratepayers. The Company’s position in the aforementioned Motion is that the OEB made errors of fact and law in its determination of allocation of the tax savings between the shareholders and

20

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

ratepayers. Therefore, the Company has also reflected the impact of the Company’s position with respect to the Motion in the Foregone Revenue Deferral account. The timing for recovery of this impact will be determined as part of the outcome of the Motion.

Distribution System Code (DSC) Exemption

In June 2010, Hydro One Networks filed an application with the OEB regarding the OEB’s new cost responsibility rules contained in the OEB’s October 2009 Notice of Amendment to the DSC, with respect to the connection of certain renewable generators that were already connected or that had received a connection impact assessment prior to October 21, 2009. The application sought approval to record and defer the unanticipated costs incurred by Hydro One Networks that resulted from the connection of certain renewable generation facilities. The OEB ruled that identified specific expenditures can be recorded in a deferral account subject to the OEB’s review in subsequent Hydro One Networks distribution applications. In March 2015, the OEB approved the disposition of the DSC exemption deferral account balance at December 31, 2013, including accrued interest, which was recovered through the 2015-2017 Rate Rider. In addition, the OEB also approved Hydro One’s request to discontinue this deferral account. There were no additions to this regulatory account in 2017 or 2016. The remaining balance in this account at December 31, 2016, including accrued interest, was requested for recovery through the 2018-2022 distribution rate application.

B2M LP Start-up Costs

In December 2015, OEB issued its decision on B2M LP’s application for 2015-2019 and as part of the decision approved the recovery of $8 million of start-up costs relating to B2M LP. The costs are being recovered over a four-year period which began in 2016, in accordance with the OEB decision.

Retail Settlement Variance Account (RSVA)

Hydro One has deferred certain retail settlement variance amounts under the provisions of Article 490 of the OEB’s Accounting Procedures Handbook. In March 2015, the OEB approved the disposition of the total RSVA balance accumulated from January 2012 to December 2013, including accrued interest, to be recovered through the 2015-2017 Rate Rider.

2015-2017 Rate Rider

In March 2015, as part of its decision on Hydro One Networks’ distribution rate application for 2015-2019, the OEB approved the disposition of certain deferral and variance accounts, including RSVAs and accrued interest. The 2015-2017 Rate Rider account included the balances approved for disposition by the OEB and was disposed of in accordance with the OEB decision over a 32-month period ended on December 31, 2017. The balance remaining in the account represents an over-collection to be returned to ratepayers in a future rate application. We have not requested recovery of the remaining balance of this account in the current distribution rate application.

Pension Cost Variance

A pension cost variance account was established for Hydro One Networks’ transmission and distribution businesses to track the difference between the actual pension expenses incurred and estimated pension costs approved by the OEB. The balance in this regulatory account reflects the deficit of pension costs paid as compared to OEB-approved amounts. In March 2015, the OEB approved the disposition of the distribution business portion of the total pension cost variance account at December 31, 2013, including accrued interest, which was recovered through the 2015-2017 Rate Rider. In September 2017, the OEB approved the disposition of the transmission business portion of the total pension cost variance account as at December 31, 2015, including accrued interest, which is being recovered over a two-year period ending December 31, 2018. In the absence of rate-regulated accounting, 2017 revenue would have been higher by $24 million (2016 - $25 million).

Green Energy Expenditure Variance

In April 2010, the OEB requested the establishment of deferral accounts which capture the difference between the revenue recorded on the basis of Green Energy Plan expenditures incurred and the actual recoveries received.

External Revenue Variance

In May 2009, the OEB approved forecasted amounts related to export service revenue, external revenue from secondary land use, and external revenue from station maintenance and engineering and construction work. In November 2012, the OEB again approved forecasted amounts related to these revenue categories and extended the scope to encompass all other external revenues. The external revenue variance account balance reflects the excess of actual external revenues compared to the OEB-approved forecasted amounts. In September 2017, the OEB approved the disposition of the external revenue variance account as at December 31, 2015, including accrued interest, which is being returned to customers over a two-year period ending December 31, 2018.

CDM Deferral Variance Account

As part of Hydro One Networks’ application for 2013 and 2014 transmission rates, Hydro One agreed to establish a new regulatory deferral variance account to track the impact of actual Conservation and Demand Management (CDM) and demand response results on the load forecast compared to the estimated load forecast included in the revenue requirement. The balance in the CDM deferral variance account relates to the actual 2013 and 2014 CDM compared to the amounts included in 2013 and 2014 revenue

21

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

requirements, respectively. There were no additions to this regulatory account in 2017 or 2016. The balance of the account at December 31, 2015, including interest, was approved for disposition in the 2017-2018 transmission rate decision and is currently being drawn down over a 2-year period ending December 31, 2018.

13. ACCOUNTS PAYABLE AND OTHER CURRENT LIABILITIES

December 31 (millions of dollars)	2017		2016
Accounts payable		177		181
Accrued liabilities		572		659
Accrued interest		99		105
Regulatory liabilities (Note 12)		57		—
		905		945
14.  OTHER LONG-TERM LIABILITIES
December 31 (millions of dollars)	2017		2016
Post-retirement and post-employment benefit liability (Note 19)		1,519		1,641
Pension benefit liability (Note 19)		981		900
Environmental liabilities (Note 20)		168		177
Asset retirement obligations (Note 21)		9		9
Long-term accounts payable and other liabilities		30		25
		2,707		2,752

15. DEBT AND CREDIT AGREEMENTS

Short-Term Notes and Credit Facilities

Hydro One meets its short-term liquidity requirements in part through the issuance of commercial paper under Hydro One Inc.’s Commercial Paper Program which has a maximum authorized amount of $1.5 billion. These short-term notes are denominated in Canadian dollars with varying maturities up to 365 days. The Commercial Paper Program is supported by Hydro One Inc.’s committed revolving credit facilities totalling $2.3 billion.

At December 31, 2017, Hydro One’s consolidated committed, unsecured and undrawn credit facilities totalling $2,550 million consisted of the following:

(millions of dollars)	Maturity		Amount
Hydro One Inc.
Revolving standby credit facility		June 20221		2,300
Hydro One
Five-year senior, revolving term credit facility		November 2021		250
Total				2,550

¹ In June 2017, the maturity date of Hydro One Inc.‘s $2.3 billion credit facilities was extended from June 2021 to June 2022.

The Company may use the credit facilities for working capital and general corporate purposes. If used, interest on the credit facilities would apply based on Canadian benchmark rates. The obligation of each lender to make any credit extension under its credit facility is subject to various conditions including that no event of default has occurred or would result from such credit extension.

22

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Long-Term Debt

The following table presents long-term debt outstanding at December 31, 2017 and 2016:

December 31 (millions of dollars)	2017			2016
5.18% Series 13 notes due 2017		—			600
2.78% Series 28 notes due 2018		750			750
Floating-rate Series 31 notes due 20191		228			228
1.48% Series 37 notes due 20192		500			500
4.40% Series 20 notes due 2020		300			300
1.62% Series 33 notes due 20202		350			350
1.84% Series 34 notes due 2021		500			500
3.20% Series 25 notes due 2022		600			600
2.77% Series 35 notes due 2026		500			500
7.35% Debentures due 2030		400			400
6.93% Series 2 notes due 2032		500			500
6.35% Series 4 notes due 2034		385			385
5.36% Series 9 notes due 2036		600			600
4.89% Series 12 notes due 2037		400			400
6.03% Series 17 notes due 2039		300			300
5.49% Series 18 notes due 2040		500			500
4.39% Series 23 notes due 2041		300			300
6.59% Series 5 notes due 2043		315			315
4.59% Series 29 notes due 2043		435			435
4.17% Series 32 notes due 2044		350			350
5.00% Series 11 notes due 2046		325			325
3.91% Series 36 notes due 2046		350			350
3.72% Series 38 notes due 2047		450			450
4.00% Series 24 notes due 2051		225			225
3.79% Series 26 notes due 2062		310			310
4.29% Series 30 notes due 2064		50			50
Hydro One Inc. long-term debt (a)		9,923			10,523
6.6% Senior Secured Bonds due 2023 (Face value - $110 million)		136			144
4.6% Note Payable due 2023 (Face value - $36 million)		40			40
HOSSM long-term debt (b)		176			184
		10,099			10,707
Add: Net unamortized debt premiums		14			15
Add: Unrealized mark-to-market gain2		(9	)		(2	)
Less: Deferred debt issuance costs		(37	)		(40	)
Total long-term debt		10,067			10,680

¹  The interest rates of the floating-rate notes are referenced to the three-month Canadian dollar bankers’ acceptance rate, plus a margin.

²  The unrealized mark-to-market net gain relates to $50 million of the Series 33 notes due 2020 and $500 million Series 37 notes due 2019. The unrealized mark-to-market net gain is offset by a $9 million (2016 - $2 million) unrealized mark-to-market net loss on the related fixed-to-floating interest-rate swap agreements, which are accounted for as fair value hedges.

(a) Hydro One Inc. long-term debt

At December 31, 2017, long-term debt of $9,923 million (2016 - $10,523 million) was outstanding, the majority of which was issued under Hydro One Inc.’s Medium Term Note (MTN) Program. The maximum authorized principal amount of notes issuable under the current MTN Program prospectus filed in December 2015 is $3.5 billion. At December 31 2017, $1.2 billion remained available for issuance until January 2018. In 2017, no long-term debt was issued and $600 million of long-term debt was repaid under the MTN Program (2016 - $2,300 million issued and $500 million repaid).

(b) HOSSM long-term debt

At December 31, 2017, long-term debt of $176 million (2016 - $184 million), with a face value of $146 million (2016 - $148 million) was held by HOSSM. In 2017, $2 million of HOSSM long-term debt was repaid (2016 - $2 million).

23

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

The total long-term debt is presented on the consolidated balance sheets as follows:

December 31 (millions of dollars)	2017		2016
Current liabilities:
Long-term debt payable within one year		752		602
Long-term liabilities:
Long-term debt		9,315		10,078
Total long-term debt		10,067		10,680

Principal and Interest Payments

Principal repayments and related weighted average interest rates are summarized by the number of years to maturity in the following table:

	Long-term Debt		Weighted Average
	Principal Repayments		Interest Rate
Years to Maturity	(millions of dollars)		(%)
1 year		752		2.8
2 years		731		1.6
3 years		653		2.9
4 years		503		1.9
5 years		604		3.2
		3,243		2.5
6 – 10 years		631		3.5
Over 10 years		6,195		5.2
		10,069		4.2

Interest payment obligations related to long-term debt are summarized by year in the following table:

	Interest Payments
Year	(millions of dollars)
2018		426
2019		402
2020		384
2021		370
2022		355
		1,937
2023-2027		1,672
2028+		4,081
		7,690

16. CONVERTIBLE DEBENTURES

(millions of dollars, except as otherwise noted)
Maturity date	September 30, 2027
Coupon rate	4.00%
Conversion price per common share	$    21.40
Carrying value at December 31, 2016	—
Receipt of Initial Instalment, net of deferred financing costs	486
Amortization of deferred financing costs	1
Carrying value at December 31, 2017	487
Face value at December 31, 2017	513

On August 9, 2017, in connection with the acquisition of Avista Corporation, the Company completed the sale of $1,540 million aggregate principal amount of 4.00% convertible unsecured subordinated debentures (Convertible Debentures) represented by instalment receipts, which included the exercise in full of the over-allotment option granted to the underwriters to purchase an additional $140 million aggregate principal amount of the Convertible Debentures (Debenture Offering).

The Convertible Debentures were sold on an instalment basis at a price of $1,000 per Convertible Debenture, of which $333 (Initial Instalment) was paid on closing of the Debenture Offering and the remaining $667 (Final Instalment) is payable on a date (Final Instalment Date) to be fixed by the Company following satisfaction of conditions precedent to the closing of the acquisition of Avista Corporation. The gross proceeds received from the Initial Instalment were $513 million. The Company incurred financing costs of

24

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

$27 million, which are being amortized to financing charges over approximately 10 years, the contractual term of the Convertible Debentures, using the effective interest rate method.

The Convertible Debentures will mature on September 30, 2027. A coupon rate of 4% is paid on the $1,540 million aggregate principal amount of the Convertible Debentures, and based on the carrying value of the Initial Instalment, this translates into an effective annual yield of 12%. After the Final Instalment Date, the interest rate will be 0%. The interest expense recorded in 2017 is $24 million.

If the Final Instalment Date occurs on a day that is prior to the first anniversary of the closing of the Debenture Offering, holders of the Convertible Debentures who have paid the Final Instalment on or before the Final Instalment Date will be entitled to receive, in addition to the payment of accrued and unpaid interest to and including the Final Instalment Date, an amount equal to the interest that would have accrued from the day following the Final Instalment Date to and including the first anniversary of the closing of the Debenture Offering had the Convertible Debentures remained outstanding and continued to accrue interest until and including such date (Make-Whole Payment). No Make-Whole Payment will be payable if the Final Instalment Date occurs on or after the first anniversary of the closing of the Debenture Offering.

At the option of the holders and provided that payment of the Final Instalment has been made, each Convertible Debenture will be convertible into common shares of the Company at any time on or after the Final Instalment Date, but prior to the earlier of maturity or redemption by the Company, at a conversion price of $21.40 per common share, being a conversion rate of 46.7290 common shares per $1,000 principal amount of Convertible Debentures. The conversion feature meets the definition of a Beneficial Conversion Feature (BCF), with an intrinsic value of approximately $92 million. Due to the contingency associated with the debentureholders’ ability to exercise the conversion, the BCF has not been recognized. Between the time the contingency is resolved and the Final Instalment Date, the Company will recognize approximately $92 million of interest expense associated with amortization of the BCF.

Prior to the Final Instalment Date, the Convertible Debentures may not be redeemed by the Company, except that the Convertible Debentures will be redeemed by the Company at a price equal to their principal amount plus accrued and unpaid interest following the earlier of: (i) notification to holders that the conditions necessary to approve the acquisition of Avista Corporation will not be satisfied; (ii) termination of the acquisition agreement; and (iii) May 1, 2019 if notice of the Final Instalment Date has not been given to holders on or before April 30, 2019. Upon any such redemption, the Company will pay for each Convertible Debenture (i) $333 plus accrued and unpaid interest to the holder of the instalment receipt; and (ii) $667 to the selling debentureholder on behalf of the holder of the instalment receipt in satisfaction of the final instalment. In addition, after the Final Instalment Date, any Convertible Debentures not converted may be redeemed by the Company at a price equal to their principal amount plus any unpaid interest, which accrued prior to and including the Final Instalment Date.

At maturity, the Company will have the right to pay the principal amount due in common shares, which will be valued at 95% of their weighted average trading price on the Toronto Stock Exchange for the 20 consecutive trading days ending five trading days preceding the maturity date.

17. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

Fair value is considered to be the exchange price in an orderly transaction between market participants to sell an asset or transfer a liability at the measurement date. The fair value definition focuses on an exit price, which is the price that would be received in the sale of an asset or the amount that would be paid to transfer a liability.

Hydro One classifies its fair value measurements based on the following hierarchy, as prescribed by the accounting guidance for fair value, which prioritizes the inputs to valuation techniques used to measure fair value into three levels:

Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Hydro One has the ability to access. An active market for the asset or liability is one in which transactions for the asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.

Level 2 inputs are those other than quoted market prices that are observable, either directly or indirectly, for an asset or liability. Level 2 inputs include, but are not limited to, quoted prices for similar assets or liabilities in an active market, quoted prices for identical or similar assets or liabilities in markets that are not active and inputs other than quoted market prices that are observable for the asset or liability, such as interest-rate curves and yield curves observable at commonly quoted intervals, volatilities, credit risk and default rates. A Level 2 measurement cannot have more than an insignificant portion of the valuation based on unobservable inputs.

Level 3 inputs are any fair value measurements that include unobservable inputs for the asset or liability for more than an insignificant portion of the valuation. A Level 3 measurement may be based primarily on Level 2 inputs.

Non-Derivative Financial Assets and Liabilities

At December 31, 2017 and 2016, the Company’s carrying amounts of cash and cash equivalents, accounts receivable, due from related parties, short-term notes payable, accounts payable, and due to related parties are representative of fair value due to the short-term nature of these instruments.

25

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Fair Value Measurements of Long-Term Debt

The fair values and carrying values of the Company’s long-term debt at December 31, 2017 and 2016 are as follows:

December 31 (millions of dollars)	2017 Carrying Value		2017 Fair Value		2016 Carrying Value		2016 Fair Value
$50 million of MTN Series 33 notes		49		49		50		50
$500 million MTN Series 37 notes		492		492		498		498
Other notes and debentures		9,526		11,027		10,132		11,462
Long-term debt, including current portion		10,067		11,568		10,680		12,010

Fair Value Measurements of Derivative Instruments

At December 31, 2017, Hydro One Inc. had interest-rate swaps in the amount of $550 million (2016 – $550 million) that were used to convert fixed-rate debt to floating-rate debt. These swaps are classified as fair value hedges. Hydro One Inc.’s fair value hedge exposure was approximately 6% (2016 – 5%) of its total long-term debt. At December 31, 2017, Hydro One Inc. had the following interest-rate swaps designated as fair value hedges:

• a $50 million fixed-to-floating interest-rate swap agreement to convert $50 million of the $350 million MTN Series 33 notes maturing April 30, 2020 into three-month variable rate debt; and

• two $125 million and one $250 million fixed-to-floating interest-rate swap agreements to convert the $500 million MTN Series 37 notes maturing November 18, 2019 into three-month variable rate debt.

At December 31, 2017 and 2016, the Company had no interest-rate swaps classified as undesignated contracts.

In October 2017, the Company entered into a deal-contingent foreign exchange forward contract to convert $1.4 billion Canadian to US dollars at an initial forward rate of 1.27486 Canadian per 1.00 US dollars, and a range up to 1.28735 Canadian per 1.00 US dollars based on the settlement date. The contract is contingent on the Company closing the proposed Avista Corporation acquisition (see Note 4 - Business Combinations) and is intended to mitigate the foreign currency risk related to the portion of the Avista Corporation acquisition purchase price financed with the issuance of Convertible Debentures (see Note 16 - Convertible Debentures). If the acquisition does not close, the contract would not be completed and no amounts would be exchanged. The contract can be executed upon approval of the acquisition up to March 31, 2019. This contract is an economic hedge and does not qualify for hedge accounting. It has been accounted for as an undesignated contract.

Fair Value Hierarchy

The fair value hierarchy of financial assets and liabilities at December 31, 2017 and 2016 is as follows:

December 31, 2017 (millions of dollars)	Carrying Value		Fair   Value		Level 1		Level 2		Level 3
Assets:
Cash and cash equivalents		25		25		25		—		—
		25		25		25		—		—
Liabilities:
Short-term notes payable		926		926		926		—		—
Long-term debt, including current portion		10,067		11,568		—		11,568		—
Convertible debentures		487		574		574		—		—
Derivative instruments
Fair value hedges – interest-rate swaps		9		9		9		—		—
Foreign exchange contract		3		3		—		—		3
		11,492		13,080		1,509		11,568		3
December 31, 2016 (millions of dollars)	Carrying Value		Fair Value		Level 1		Level 2		Level 3
Assets:
Cash and cash equivalents		50		50		50		—		—
		50		50		50		—		—
Liabilities:
Short-term notes payable		469		469		469		—		—
Long-term debt, including current portion		10,680		12,010		—		12,010		—
Derivative instruments
Fair value hedges – interest-rate swaps		2		2		2		—		—
		11,151		12,481		471		12,010		—

26

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Cash and cash equivalents include cash and short-term investments. The carrying values are representative of fair value because of the short-term nature of these instruments.

The fair value of the hedged portion of the long-term debt is primarily based on the present value of future cash flows using a swap yield curve to determine the assumption for interest rates. The fair value of the unhedged portion of the long-term debt is based on unadjusted period-end market prices for the same or similar debt of the same remaining maturities.

The fair value of the convertible debentures is based on their closing price on December 29, 2017 (last business day in December 2017), as posted on the Toronto Stock Exchange.

The Company uses derivative instruments as an economic hedge for foreign exchange risk. The value of the foreign exchange contract is derived using valuation models commonly used for derivatives. These valuation models require a variety of inputs, including contractual terms, forward price yield curves,probability of closing the Avista Corporation acquisition, and the contract settlement of date. The Company’s valuation models also reflect measurements for credit risk. The fair value of the foreign exchange contract includes significant unobservable inputs, and therefore has been classified accordingly as Level 3. The significant unobservable inputs used in the fair value measurement of the foreign exchange contract relates to the assessment of probabililty of closing the Avista Corporation acquisition and the contract settlement date.

Changes in the Fair Value of Financial Instruments Classified in Level 3

The following table summarizes the changes in fair value of financial instruments classified in Level 3 for the years ended December 31, 2017 and 2016.

Year ended December 31 (millions of dollars)	2017		2016
Fair value, beginning of year		—		—
Unrealized loss on foreign exchange contract included in financing charges (Note 6)		3		—
Fair value, end of year		3		—

There were no transfers between any of the fair value levels during the years ended December 31, 2017 or 2016.

Risk Management

Exposure to market risk, credit risk and liquidity risk arises in the normal course of the Company’s business.

Market Risk

Market risk refers primarily to the risk of loss which results from changes in costs, foreign exchange rates and interest rates. The Company is exposed to fluctuations in interest rates, as its regulated return on equity is derived using a formulaic approach that takes anticipated interest rates into account. The Company is not currently exposed to material commodity price risk.

The Company uses a combination of fixed and variable-rate debt to manage the mix of its debt portfolio. The Company also uses derivative financial instruments to manage interest-rate risk. The Company utilizes interest-rate swaps, which are typically designated as fair value hedges, as a means to manage its interest rate exposure to achieve a lower cost of debt. The Company may also utilize interest-rate derivative instruments to lock in interest-rate levels in anticipation of future financing.

A hypothetical 100 basis points increase in interest rates associated with variable-rate debt would not have resulted in a significant decrease in Hydro One’s net income for the years ended December 31, 2017 and 2016.

The Company is exposed to foreign exchange fluctuations as a result of entering into a deal-contingent foreign exchange forward agreement (see section Fair Value Measurements of Derivative Instruments above).This agreement is intended to mitigate the foreign currency risk related to the portion of the Avista Corporation acquisition purchase price financed with the issuance of Convertible Debentures (see Note 16 - Convertible Debentures).

For derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative instrument as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in the Consolidated Statements of Operations and Comprehensive Income. The net unrealized loss (gain) on the hedged debt and the related interest-rate swaps for the years ended December 31, 2017 and 2016 was not material.

Credit Risk

Financial assets create a risk that a counterparty will fail to discharge an obligation, causing a financial loss. At December 31, 2017 and 2016, there were no significant concentrations of credit risk with respect to any class of financial assets. The Company’s revenue is earned from a broad base of customers. As a result, Hydro One did not earn a material amount of revenue from any single customer.

At December 31, 2017 and 2016, there was no material accounts receivable balance due from any single customer. At December 31, 2017, the Company’s provision for bad debts was $29 million (2016 – $35 million). Adjustments and write-offs are determined on the basis of a review of overdue accounts, taking into consideration historical experience. At December 31, 2017, approximately 5% (2016 – 6%) of the Company’s net accounts receivable were outstanding for more than 60 days.

27

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Hydro One manages its counterparty credit risk through various techniques including: entering into transactions with highly rated counterparties; limiting total exposure levels with individual counterparties; entering into master agreements which enable net settlement and the contractual right of offset; and monitoring the financial condition of counterparties. The Company monitors current credit exposure to counterparties both on an individual and an aggregate basis. The Company’s credit risk for accounts receivable is limited to the carrying amounts on the Consolidated Balance Sheets.

Derivative financial instruments result in exposure to credit risk since there is a risk of counterparty default. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date. At December 31, 2017 and 2016, the counterparty credit risk exposure on the fair value of these interest-rate swap contracts was not material. At December 31, 2017, Hydro One’s credit exposure for all derivative instruments, and applicable payables and receivables, had a credit rating of investment grade, with four financial institutions as the counterparties.

Liquidity Risk

Liquidity risk refers to the Company’s ability to meet its financial obligations as they come due. Hydro One meets its short-term liquidity requirements using cash and cash equivalents on hand, funds from operations, the issuance of commercial paper, and the revolving standby credit facilities. The short-term liquidity under the Commercial Paper Program, revolving standby credit facilities, and anticipated levels of funds from operations are expected to be sufficient to fund normal operating requirements.

18. CAPITAL MANAGEMENT

The Company’s objectives with respect to its capital structure are to maintain effective access to capital on a long-term basis at reasonable rates, and to deliver appropriate financial returns. In order to ensure ongoing access to capital, the Company targets to maintain strong credit quality. At December 31, 2017 and 2016, the Company’s capital structure was as follows:

December 31 (millions of dollars)	2017			2016
Long-term debt payable within one year		752			602
Short-term notes payable		926			469
Less: cash and cash equivalents		(25	)		(50	)
		1,653			1,021
Long-term debt		9,315			10,078
Convertible debentures		487			—
Preferred shares		418			418
Common shares		5,631			5,623
Retained earnings		4,090			3,950
Total capital		21,594			21,090

Hydro One Inc. and HOSSM have customary covenants typically associated with long-term debt. Hydro One Inc.’s long-term debt and credit facility covenants limit permissible debt to 75% of its total capitalization, limit the ability to sell assets and impose a negative pledge provision, subject to customary exceptions. At December 31, 2017, the Company was in compliance with all financial covenants and limitations associated with the outstanding borrowings and credit facilities.

19. PENSION AND POST-RETIREMENT AND POST-EMPLOYMENT BENEFITS

Hydro One has a defined benefit pension plan (Pension Plan), a defined contribution pension plan (DC Plan), a supplemental pension plan (Supplemental Plan), and post-retirement and post-employment benefit plans.

DC Plan

Hydro One established a DC Plan effective January 1, 2016. The DC Plan covers eligible management employees hired on or after January 1, 2016, as well as management employees hired before January 1, 2016 who were not eligible or had not irrevocably elected to join the Pension Plan as of September 30, 2015. Members of the DC Plan have an option to contribute 4%, 5% or 6% of their pensionable earnings, with matching contributions by Hydro One.

Hydro One contributions to the DC Plan for the year ended December 31, 2017 were $1 million (2016 - less than $1 million). At December 31, 2017, Company contributions payable included in accrued liabilities on the Consolidated Balance Sheets were less than $1 million (2016 - less than $1 million).

Pension Plan, Supplemental Plan, and Post-Retirement and Post-Employment Plans

The Pension Plan is a defined benefit contributory plan which covers eligible regular employees of Hydro One and its subsidiaries. The Pension Plan provides benefits based on highest three-year average pensionable earnings. For management employees who commenced employment on or after January 1, 2004, and for The Society of Energy Professionals (The Society)-represented staff hired after November 17, 2005, benefits are based on highest five-year average pensionable earnings. After retirement, pensions

28

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

are indexed to inflation. Membership in the Pension Plan was closed to management employees who were not eligible or had not irrevocably elected to join the Pension Plan as of September 30, 2015. These employees are eligible to join the DC Plan.

Company and employee contributions to the Pension Plan are based on actuarial valuations performed at least every three years. Annual Pension Plan contributions for 2017 of $87 million (2016 - $108 million) were based on an actuarial valuation effective December 31, 2016 (2016 - based on an actuarial valuation effective December 31, 2015) and the level of pensionable earnings. Estimated annual Pension Plan contributions for 2018 and 2019 are approximately $71 million for each year based on the actuarial valuation as at December 31, 2016 and projected levels of pensionable earnings. Future minimum contributions beyond 2019 will be based on an actuarial valuation effective no later than December 31, 2019. Contributions are payable one month in arrears. All of the contributions are expected to be in the form of cash.

The Supplemental Plan provides members of the Pension Plan with benefits that would have been earned and payable under the Pension Plan but for limitations imposed by the Income Tax Act (Canada). The Supplemental Plan obligation is included with other post-retirement and post-employment benefit obligations on the Consolidated Balance Sheets.

Hydro One recognizes the overfunded or underfunded status of the Pension Plan, and post-retirement and post-employment benefit plans (Plans) as an asset or liability on its Consolidated Balance Sheets, with offsetting regulatory assets and liabilities as appropriate. The underfunded benefit obligations for the Plans, in the absence of regulatory accounting, would be recognized in AOCI. The impact of changes in assumptions used to measure pension, post-retirement and post-employment benefit obligations is generally recognized over the expected average remaining service period of the employees. The measurement date for the Plans is December 31.

							Post-Retirement and
	Pension Benefits						Post-Employment Benefits
Year ended December 31 (millions of dollars)	2017			2016			2017			2016
Change in projected benefit obligation
Projected benefit obligation, beginning of year		7,774			7,683			1,690			1,610
Current service cost		147			144			49			42
Employee contributions		49			45			—			—
Interest cost		304			308			67			67
Benefits paid		(368	)		(354	)		(44	)		(43	)
Net actuarial loss (gain)		352			(52	)		(197	)		14
Projected benefit obligation, end of year		8,258			7,774			1,565			1,690
Change in plan assets
Fair value of plan assets, beginning of year		6,874			6,731			—			—
Actual return on plan assets		662			370			—			—
Benefits paid		(368	)		(354	)		(34	)		(43	)
Employer contributions		87			108			34			43
Employee contributions		49			45			—			—
Administrative expenses		(27	)		(26	)		—			—
Fair value of plan assets, end of year		7,277			6,874			—			—
Unfunded status		981			900			1,565			1,690

Hydro One presents its benefit obligations and plan assets net on its Consolidated Balance Sheets as follows:

					Post-Retirement and
	Pension Benefits				Post-Employment Benefits
December 31 (millions of dollars)	2017		2016		2017		2016
Other assets1		1		1		—		—
Accrued liabilities		—		—		53		56
Pension benefit liability		981		900		—		—
Post-retirement and post-employment benefit liability2		—		—		1,519		1,641
Net unfunded status		980		899		1,572		1,697

¹  Represents the funded status of HOSSM defined benefit pension plan.

²  Includes $7 million (2016 - $7 million) relating to HOSSM post-employment benefit plans.

The funded or unfunded status of the pension, post-retirement and post-employment benefit plans refers to the difference between the fair value of plan assets and the projected benefit obligations for the Plans. The funded/unfunded status changes over time due to several factors, including contribution levels, assumed discount rates and actual returns on plan assets.

29

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

The following table provides the projected benefit obligation (PBO), accumulated benefit obligation (ABO) and fair value of plan assets for the Pension Plan:

December 31 (millions of dollars)	2017		2016
PBO		8,258		7,774
ABO		7,614		7,094
Fair value of plan assets		7,277		6,874

On an ABO basis, the Pension Plan was funded at 96% at December 31, 2017 (2016 - 97%). On a PBO basis, the Pension Plan was funded at 88% at December 31, 2017 (2016 - 88%). The ABO differs from the PBO in that the ABO includes no assumption about future compensation levels.

Components of Net Periodic Benefit Costs

The following table provides the components of the net periodic benefit costs for the years ended December 31, 2017 and 2016 for the Pension Plan:

Year ended December 31 (millions of dollars)	2017			2016
Current service cost		147			144
Interest cost		304			308
Expected return on plan assets, net of expenses		(442	)		(432	)
Amortization of actuarial losses		79			96
Net periodic benefit costs		88			116
Charged to results of operations1		39			48

¹  The Company accounts for pension costs consistent with their inclusion in OEB-approved rates. During the year ended December 31, 2017, pension costs of $87 million (2016 - $108 million) were attributed to labour, of which $39 million (2016 - $48 million) was charged to operations, and $48 million (2016 - $60 million) was capitalized as part of the cost of property, plant and equipment and intangible assets.

The following table provides the components of the net periodic benefit costs for the years ended December 31, 2017 and 2016 for the post-retirement and post-employment benefit plans:

Year ended December 31 (millions of dollars)	2017		2016
Current service cost		49		42
Interest cost		67		67
Amortization of actuarial losses		16		15
Net periodic benefit costs		132		124
Charged to results of operations		59		55

Assumptions

The measurement of the obligations of the Plans and the costs of providing benefits under the Plans involves various factors, including the development of valuation assumptions and accounting policy elections. When developing the required assumptions, the Company considers historical information as well as future expectations. The measurement of benefit obligations and costs is impacted by several assumptions including the discount rate applied to benefit obligations, the long-term expected rate of return on plan assets, Hydro One’s expected level of contributions to the Plans, the incidence of mortality, the expected remaining service period of plan participants, the level of compensation and rate of compensation increases, employee age, length of service, and the anticipated rate of increase of health care costs, among other factors. The impact of changes in assumptions used to measure the obligations of the Plans is generally recognized over the expected average remaining service period of the plan participants. In selecting the expected rate of return on plan assets, Hydro One considers historical economic indicators that impact asset returns, as well as expectations regarding future long-term capital market performance, weighted by target asset class allocations. In general, equity securities, real estate and private equity investments are forecasted to have higher returns than fixed-income securities.

The following weighted average assumptions were used to determine the benefit obligations at December 31, 2017 and 2016:

					Post-Retirement and
	Pension Benefits				Post-Employment Benefits
Year ended December 31	2017		2016		2017		2016
Significant assumptions:
Weighted average discount rate		3.40%		3.90%		3.40%		3.90%
Rate of compensation scale escalation (long-term)		2.50%		2.50%		2.50%		2.50%
Rate of cost of living increase		2.00%		2.00%		2.00%		2.00%
Rate of increase in health care cost trends1		—		—		4.04%		4.36%

¹  5.26% per annum in 2018, grading down to 4.04% per annum in and after 2031 (2016 - 6.25% in 2017, grading down to 4.36% per annum in and after 2031).

30

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

The following weighted average assumptions were used to determine the net periodic benefit costs for the years ended December 31, 2017 and 2016. Assumptions used to determine current year-end benefit obligations are the assumptions used to estimate the subsequent year’s net periodic benefit costs.

Year ended December 31	2017		2016
Pension Benefits:
Weighted average expected rate of return on plan assets		6.50%		6.50%
Weighted average discount rate		3.90%		4.00%
Rate of compensation scale escalation (long-term)		2.50%		2.50%
Rate of cost of living increase		2.00%		2.00%
Average remaining service life of employees (years)		15		15
Post-Retirement and Post-Employment Benefits:
Weighted average discount rate		3.90%		4.10%
Rate of compensation scale escalation (long-term)		2.50%		2.50%
Rate of cost of living increase		2.00%		2.00%
Average remaining service life of employees (years)		15.2		15.3
Rate of increase in health care cost trends1		4.36%		4.36%

¹  6.25% per annum in 2017, grading down to 4.36% per annum in and after 2031 (2016 - 6.38% in 2016, grading down to 4.36% per annum in and after 2031).

The discount rate used to determine the current year pension obligation and the subsequent year’s net periodic benefit costs is based on a yield curve approach. Under the yield curve approach, expected future benefit payments for each plan are discounted by a rate on a third-party bond yield curve corresponding to each duration. The yield curve is based on “AA” long-term corporate bonds. A single discount rate is calculated that would yield the same present value as the sum of the discounted cash flows.

The effect of a 1% change in health care cost trends on the projected benefit obligation for the post-retirement and post-employment benefits at December 31, 2017 and 2016 is as follows:

December 31 (millions of dollars)	2017			2016
Projected benefit obligation:
Effect of a 1% increase in health care cost trends		250			289
Effect of a 1% decrease in health care cost trends		(189	)		(221	)

The effect of a 1% change in health care cost trends on the service cost and interest cost for the post-retirement and post-employment benefits for the years ended December 31, 2017 and 2016 is as follows:

Year ended December 31 (millions of dollars)	2017			2016
Service cost and interest cost:
Effect of a 1% increase in health care cost trends		29			23
Effect of a 1% decrease in health care cost trends		(20	)		(17	)

The following approximate life expectancies were used in the mortality assumptions to determine the projected benefit obligations for the pension and post-retirement and post-employment plans at December 31, 2017 and 2016:

December 31, 2017 Life expectancy at 65 for a member currently at					December 31, 2016 Life expectancy at 65 for a member currently at
Age 65		Age 45		Age 65		Age 45
Male	Female	Male	Female	Male	Female	Male	Female
22	24	23	24	22	24	23	24

Estimated Future Benefit Payments

At December 31, 2017, estimated future benefit payments to the participants of the Plans were:

(millions of dollars)	Pension Benefits		Post-Retirement and          Post-Employment Benefits
2018		326		53
2019		335		54
2020		342		56
2021		350		57
2022		358		58
2023 through to 2027		1,886		312
Total estimated future benefit payments through to 2027		3,597		590

31

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Components of Regulatory Assets

A portion of actuarial gains and losses and prior service costs is recorded within regulatory assets on Hydro One’s Consolidated Balance Sheets to reflect the expected regulatory inclusion of these amounts in future rates, which would otherwise be recorded in OCI. The following table provides the actuarial gains and losses and prior service costs recorded within regulatory assets:

Year ended December 31 (millions of dollars)	2017			2016
Pension Benefits:
Actuarial loss (gain) for the year		159			35
Amortization of actuarial losses		(79	)		(96	)
		80			(61	)
Post-Retirement and Post-Employment Benefits:
Actuarial loss (gain) for the year		(197	)		14
Amortization of actuarial losses		(16	)		(15	)
Amounts not subject to regulatory treatment		6			4
		(207	)		3

The following table provides the components of regulatory assets that have not been recognized as components of net periodic benefit costs for the years ended December 31, 2017 and 2016:

Year ended December 31 (millions of dollars)	2017		2016
Pension Benefits:
Actuarial loss		981		900
Post-Retirement and Post-Employment Benefits:
Actuarial loss		36		243

The following table provides the components of regulatory assets at December 31 that are expected to be amortized as components of net periodic benefit costs in the following year:

	Pension Benefits				Post-Retirement and   Post-Employment Benefits
December 31 (millions of dollars)	2017		2016		2017		2016
Actuarial loss		84		79		2		6

Pension Plan Assets

Investment Strategy

On a regular basis, Hydro One evaluates its investment strategy to ensure that Pension Plan assets will be sufficient to pay Pension Plan benefits when due. As part of this ongoing evaluation, Hydro One may make changes to its targeted asset allocation and investment strategy. The Pension Plan is managed at a net asset level. The main objective of the Pension Plan is to sustain a certain level of net assets in order to meet the pension obligations of the Company. The Pension Plan fulfills its primary objective by adhering to specific investment policies outlined in its Summary of Investment Policies and Procedures (SIPP), which is reviewed and approved by the Human Resource Committee of Hydro One’s Board of Directors. The Company manages net assets by engaging knowledgeable external investment managers who are charged with the responsibility of investing existing funds and new funds (current year’s employee and employer contributions) in accordance with the approved SIPP. The performance of the managers is monitored through a governance structure. Increases in net assets are a direct result of investment income generated by investments held by the Pension Plan and contributions to the Pension Plan by eligible employees and by the Company. The main use of net assets is for benefit payments to eligible Pension Plan members.

Pension Plan Asset Mix

At December 31, 2017, the Pension Plan target asset allocations and weighted average asset allocations were as follows:

	Target Allocation (%)		Pension Plan Assets (%)
Equity securities		55		60
Debt securities		35		31
Other1		10		9
		100		100

¹  Other investments include real estate and infrastructure investments.

At December 31, 2017, the Pension Plan held $11 million (2016 - $11 million) Hydro One corporate bonds and $415 million (2016 - $450 million) of debt securities of the Province.

32

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Concentrations of Credit Risk

Hydro One evaluated its Pension Plan’s asset portfolio for the existence of significant concentrations of credit risk as at December 31, 2017 and 2016. Concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, concentrations in a type of industry, and concentrations in individual funds. At December 31, 2017 and 2016, there were no significant concentrations (defined as greater than 10% of plan assets) of risk in the Pension Plan’s assets.

The Pension Plan’s Statement of Investment Beliefs and Guidelines provides guidelines and restrictions for eligible investments taking into account credit ratings, maximum investment exposure and other controls in order to limit the impact of this risk. The Pension Plan manages its counterparty credit risk with respect to bonds by investing in investment-grade and government bonds and with respect to derivative instruments by transacting only with highly rated financial institutions, and also by ensuring that exposure is diversified across counterparties. The risk of default on transactions in listed securities is considered minimal, as the trade will fail if either party to the transaction does not meet its obligation.

Fair Value Measurements

The following tables present the Pension Plan assets measured and recorded at fair value on a recurring basis and their level within the fair value hierarchy at December 31, 2017 and 2016:

December 31, 2017 (millions of dollars)	Level 1		Level 2		Level 3		Total
Pooled funds		—		16		549		565
Cash and cash equivalents		153		—		—		153
Short-term securities		—		109		—		109
Derivative instruments		—		5		—		5
Corporate shares - Canadian		921		—		—		921
Corporate shares - Foreign		3,307		125		—		3,432
Bonds and debentures - Canadian		—		1,879		—		1,879
Bonds and debentures - Foreign		—		194		—		194
Total fair value of plan assets1		4,381		2,328		549		7,258

¹  At December 31, 2017, the total fair value of Pension Plan assets and liabilities excludes $28 million of interest and dividends receivable, $10 million of pension administration expenses payable, $1 million of sold investments receivable, and $1 million of purchased investments payable.

December 31, 2016 (millions of dollars)	Level 1		Level 2		Level 3		Total
Pooled funds		—		20		425		445
Cash and cash equivalents		146		—		—		146
Short-term securities		—		127		—		127
Corporate shares - Canadian		911		—		—		911
Corporate shares - Foreign		2,985		113		—		3,098
Bonds and debentures - Canadian		—		1,943		—		1,943
Bonds and debentures - Foreign		—		193		—		193
Total fair value of plan assets1		4,042		2,396		425		6,863

¹  At December 31, 2016, the total fair value of Pension Plan assets excludes $27 million of interest and dividends receivable, $15 million of purchased investments payable, $9 million of pension administration expenses payable, and $7 million of sold investments receivable.

See note 17 - Fair Value of Financial Instruments and Risk Management for a description of levels within the fair value hierarchy.

Changes in the Fair Value of Financial Instruments Classified in Level 3

The following table summarizes the changes in fair value of financial instruments classified in Level 3 for the years ended December 31, 2017 and 2016. The Pension Plan classifies financial instruments as Level 3 when the fair value is measured based on at least one significant input that is not observable in the markets or due to lack of liquidity in certain markets. The gains and losses presented in the table below may include changes in fair value based on both observable and unobservable inputs.

Year ended December 31 (millions of dollars)	2017			2016
Fair value, beginning of year		425			301
Realized and unrealized gains		(31	)		23
Purchases		171			151
Sales and disbursements		(16	)		(50	)
Fair value, end of year		549			425

There were no significant transfers between any of the fair value levels during the years ended December 31, 2017 and 2016.

The Company performs sensitivity analysis for fair value measurements classified in Level 3, substituting the unobservable inputs with one or more reasonably possible alternative assumptions. This sensitivity analysis resulted in negligible changes in the fair value of financial instruments classified in this level.

33

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Valuation Techniques Used to Determine Fair Value

Pooled funds mainly consist of private equity, real estate and infrastructure investments. Private equity investments represent private equity funds that invest in operating companies that are not publicly traded on a stock exchange. Investment strategies in private equity include limited partnerships in businesses that are characterized by high internal growth and operational efficiencies, venture capital, leveraged buyouts and special situations such as distressed investments. Real estate and infrastructure investments represent funds that invest in real assets which are not publicly traded on a stock exchange. Investment strategies in real estate include limited partnerships that seek to generate a total return through income and capital growth by investing primarily in global and Canadian limited partnerships. Investment strategies in infrastructure include limited partnerships in core infrastructure assets focusing on assets that generate stable, long-term cash flows and deliver incremental returns relative to conventional fixed-income investments. Private equity, real estate and infrastructure valuations are reported by the fund manager and are based on the valuation of the underlying investments which includes inputs such as cost, operating results, discounted future cash flows and market-based comparable data. Since these valuation inputs are not highly observable, private equity and infrastructure investments have been categorized as Level 3 within pooled funds.

Cash equivalents consist of demand cash deposits held with banks and cash held by the investment managers. Cash equivalents are categorized as Level 1.

Short-term securities are valued at cost plus accrued interest, which approximates fair value due to their short-term nature. Short-term securities are categorized as Level 2.

Derivative instruments are used to hedge the Pension Plan’s foreign currency exposure back to Canadian dollars. The most significant currencies being hedged against the Canadian dollar are the United States dollar, Euro, and Japanese Yen. The terms to maturity of the forward exchange contracts at December 31, 2017 are within three months. The fair value of the derivative instruments is determined using inputs other than quoted prices that are observable for these assets. The fair value is determined using standard interpolation methodology primarily based on the World Markets exchange rates. Derivative instruments are categorized as Level 2.

Corporate shares are valued based on quoted prices in active markets and are categorized as Level 1. Investments denominated in foreign currencies are translated into Canadian currency at year-end rates of exchange.

Bonds and debentures are presented at published closing trade quotations, and are categorized as Level 2.

20. ENVIRONMENTAL LIABILITIES

The following tables show the movements in environmental liabilities for the years ended December 31, 2017 and 2016:

Year ended December 31, 2017 (millions of dollars)	PCB			Land Assessment and Remediation			Total
Environmental liabilities - beginning		143			61			204
Interest accretion		6			2			8
Expenditures		(16	)		(8	)		(24	)
Revaluation adjustment		1			7			8
Environmental liabilities - ending		134			62			196
Less: current portion		(20	)		(8	)		(28	)
		114			54			168
Year ended December 31, 2016 (millions of dollars)	PCB			Land Assessment and Remediation			Total
Environmental liabilities - beginning		148			59			207
Interest accretion		7			1			8
Expenditures		(11	)		(9	)		(20	)
Revaluation adjustment		(1	)		10			9
Environmental liabilities - ending		143			61			204
Less: current portion		(18	)		(9	)		(27	)
		125			52			177

The following tables show the reconciliation between the undiscounted basis of the environmental liabilities and the amount recognized on the Consolidated Balance Sheets after factoring in the discount rate:

December 31, 2017 (millions of dollars)	PCB			Land Assessment and Remediation			Total
Undiscounted environmental liabilities		142			64			206
Less: discounting environmental liabilities to present value		(8	)		(2	)		(10	)
Discounted environmental liabilities		134			62			196

34

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

December 31, 2016(millions of dollars)	PCB			Land Assessment and Remediation			Total
Undiscounted environmental liabilities		158			66			224
Less: discounting environmental liabilities to present value		(15	)		(5	)		(20	)
Discounted environmental liabilities		143			61			204

At December 31, 2017, the estimated future environmental expenditures were as follows:

(millions of dollars)
2018	28
2019	27
2020	32
2021	34
2022	31
Thereafter	54
	206

Hydro One records a liability for the estimated future expenditures for land assessment and remediation and for the phase-out and destruction of PCB-contaminated mineral oil removed from electrical equipment when it is determined that future environmental remediation expenditures are probable under existing statute or regulation and the amount of the future expenditures can be reasonably estimated.

There are uncertainties in estimating future environmental costs due to potential external events such as changes in legislation or regulations, and advances in remediation technologies. In determining the amounts to be recorded as environmental liabilities, the Company estimates the current cost of completing required work and makes assumptions as to when the future expenditures will actually be incurred, in order to generate future cash flow information. A long-term inflation rate assumption of approximately 2% has been used to express these current cost estimates as estimated future expenditures. Future expenditures have been discounted using factors ranging from approximately 2.0% to 6.3%, depending on the appropriate rate for the period when expenditures are expected to be incurred. All factors used in estimating the Company’s environmental liabilities represent management’s best estimates of the present value of costs required to meet existing legislation or regulations. However, it is reasonably possible that numbers or volumes of contaminated assets, cost estimates to perform work, inflation assumptions and the assumed pattern of annual cash flows may differ significantly from the Company’s current assumptions. In addition, with respect to the PCB environmental liability, the availability of critical resources such as skilled labour and replacement assets and the ability to take maintenance outages in critical facilities may influence the timing of expenditures.

PCBs

The Environment Canada regulations, enacted under the Canadian Environmental Protection Act, 1999, govern the management, storage and disposal of PCBs based on certain criteria, including type of equipment, in-use status, and PCB-contamination thresholds. Under current regulations, Hydro One’s PCBs have to be disposed of by the end of 2025, with the exception of specifically exempted equipment. Contaminated equipment will generally be replaced, or will be decontaminated by removing PCB-contaminated insulating oil and retro filling with replacement oil that contains PCBs in concentrations of less than 2 ppm.

The Company’s best estimate of the total estimated future expenditures to comply with current PCB regulations is $142 million (2016 - $158 million). These expenditures are expected to be incurred over the period from 2018 to 2025. As a result of its annual review of environmental liabilities, the Company recorded a revaluation adjustment in 2017 to increase the PCB environmental liability by $1 million (2016 - reduce by $1 million).

Land Assessment and Remediation

The Company’s best estimate of the total estimated future expenditures to complete its land assessment and remediation program is $64 million (2016 - $66 million). These expenditures are expected to be incurred over the period from 2018 to 2044. As a result of its annual review of environmental liabilities, the Company recorded a revaluation adjustment in 2017 to increase the land assessment and remediation environmental liability by $7 million (2016 - $10 million).

21. ASSET RETIREMENT OBLIGATIONS

Hydro One records a liability for the estimated future expenditures for the removal and disposal of asbestos-containing materials installed in some of its facilities. Asset retirement obligations, which represent legal obligations associated with the retirement of certain tangible long-lived assets, are computed as the present value of the projected expenditures for the future retirement of specific assets and are recognized in the period in which the liability is incurred, if a reasonable estimate can be made. If the asset remains in service at the recognition date, the present value of the liability is added to the carrying amount of the associated asset in the period the liability is incurred and this additional carrying amount is depreciated over the remaining life of the asset. If an asset retirement obligation is recorded in respect of an out-of-service asset, the asset retirement cost is charged to results of operations. Subsequent to the initial recognition, the liability is adjusted for any revisions to the estimated future cash flows associated

35

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

with the asset retirement obligation, which can occur due to a number of factors including, but not limited to, cost escalation, changes in technology applicable to the assets to be retired, changes in legislation or regulations, as well as for accretion of the liability due to the passage of time until the obligation is settled. Depreciation expense is adjusted prospectively for any increases or decreases to the carrying amount of the associated asset.

In determining the amounts to be recorded as asset retirement obligations, the Company estimates the current fair value for completing required work and makes assumptions as to when the future expenditures will actually be incurred, in order to generate future cash flow information. A long-term inflation assumption of approximately 2% has been used to express these current cost estimates as estimated future expenditures. Future expenditures have been discounted using factors ranging from approximately 3.0% to 5.0%, depending on the appropriate rate for the period when expenditures are expected to be incurred. All factors used in estimating the Company’s asset retirement obligations represent management’s best estimates of the cost required to meet existing legislation or regulations. However, it is reasonably possible that numbers or volumes of contaminated assets, cost estimates to perform work, inflation assumptions and the assumed pattern of annual cash flows may differ significantly from the Company’s current assumptions. Asset retirement obligations are reviewed annually or more frequently if significant changes in regulations or other relevant factors occur. Estimate changes are accounted for prospectively.

At December 31, 2017, Hydro One had recorded asset retirement obligations of $9 million (2016 - $9 million), primarily consisting of the estimated future expenditures associated with the removal and disposal of asbestos-containing materials installed in some of its facilities. The amount of interest recorded is nominal.

22. SHARE CAPITAL

Common Shares

The Company is authorized to issue an unlimited number of common shares. At December 31, 2017, the Company had 595,386,711 (2016 – 595,000,000) common shares issued and outstanding.

The amount and timing of any dividends payable by Hydro One is at the discretion of the Hydro One Board of Directors and is established on the basis of Hydro One’s results of operations, maintenance of its deemed regulatory capital structure, financial condition, cash requirements, the satisfaction of solvency tests imposed by corporate laws for the declaration and payment of dividends and other factors that the Board of Directors may consider relevant.

The following tables present the changes to common shares during the years ended December 31, 2017 and 2016:

	Ownership by
Year ended December 31, 2017 (number of shares)	Public			Province			Total
Common shares – beginning		178,196,340			416,803,660			595,000,000
Secondary offering1		120,000,000			(120,000,000	)		—
Common shares issued - share grants2		371,611			—			371,611
Common shares issued - LTIP3		15,100			—			15,100
Sale of common shares4		14,391,012			(14,391,012	)		—
Common shares – ending		312,974,063			282,412,648			595,386,711
		52.6	%		47.4	%		100	%

¹  On May 17, 2017, Hydro One announced the closing of a secondary offering by the Province, on a bought deal basis, of 120 million common shares of Hydro One on the Toronto Stock Exchange. Hydro One did not receive any of the proceeds from the sale of the common shares by the Province.

²  On April 1, 2017, Hydro One issued from treasury 371,611 common shares in accordance with provisions of the Power Workers’ Union (PWU) Share Grant Plan.

³  In 2017, Hydro One issued from treasury 15,100 common shares in accordance with provisions of the LTIP.

⁴  On December 29, 2017, the Province sold 14,391,012 common shares of Hydro One to OFN Power Holdings LP, a limited partnership wholly-owned by Ontario First Nations Sovereign Wealth LP, which is in turn owned by 129 First Nations in Ontario. Hydro One did not receive any of the proceeds from the sale of the common shares by the Province.

	Ownership by
Year ended December 31, 2016 (number of shares)	Public			Province			Total
Common shares – beginning		94,896,340			500,103,660			595,000,000
Secondary offering1		83,300,000			(83,300,000	)		—
Common shares – ending		178,196,340			416,803,660			595,000,000
		29.9	%		70.1	%		100	%

¹  On April 14, 2016, Hydro One announced the closing of a secondary offering by the Province, on a bought deal basis, of 72,434,800 common shares of Hydro One on the Toronto Stock Exchange. In addition, the Province granted the underwriters an over-allotment option to purchase up to an additional 10,865,200 common shares of Hydro One which was fully exercised and closed on April 29, 2016. Hydro One did not receive any of the proceeds from the sale of common shares by the Province.

Preferred Shares

The Company is authorized to issue an unlimited number of preferred shares, issuable in series. At December 31, 2017 and 2016, two series of preferred shares are authorized for issuance: the Series 1 preferred shares and the Series 2 preferred shares. At

36

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

December 31, 2017 and 2016, the Company had 16,720,000 Series 1 preferred shares and no Series 2 preferred shares issued and outstanding.

Hydro One may from time to time issue preferred shares in one or more series. Prior to issuing shares in a series, the Hydro One Board of Directors is required to fix the number of shares in the series and determine the designation, rights, privileges, restrictions and conditions attaching to that series of preferred shares. Holders of Hydro One’s preferred shares are not entitled to receive notice of, to attend or to vote at any meeting of the shareholders of Hydro One except that votes may be granted to a series of preferred shares when dividends have not been paid on any one or more series as determined by the applicable series provisions. Each series of preferred shares ranks on parity with every other series of preferred shares, and are entitled to a preference over the common shares and any other shares ranking junior to the preferred shares, with respect to dividends and the distribution of assets and return of capital in the event of the liquidation, dissolution or winding up of Hydro One.

For the period commencing from the date of issue of the Series 1 preferred shares and ending on and including November 19, 2020, the holders of Series 1 preferred shares are entitled to receive fixed cumulative preferential dividends of $1.0625 per share per year, if and when declared by the Board of Directors, payable quarterly. The dividend rate will reset on November 20, 2020 and every five years thereafter at a rate equal to the sum of the then five-year Government of Canada bond yield and 3.53%. The Series 1 preferred shares will not be redeemable by Hydro One prior to November 20, 2020, but will be redeemable by Hydro One on November 20, 2020 and on November 20 of every fifth year thereafter at a redemption price equal to $25.00 for each Series 1 preferred share redeemed, plus any accrued or unpaid dividends. The holders of Series 1 preferred shares will have the right, at their option, on November 20, 2020 and on November 20 of every fifth year thereafter, to convert all or any of their Series 1 preferred shares into Series 2 preferred shares on a one-for-one basis, subject to certain restrictions on conversion. At December 31, 2017, no preferred share dividends were in arrears.

The holders of Series 2 preferred shares will be entitled to receive quarterly floating rate cumulative dividends, if and when declared by the Board of Directors, at a rate equal to the sum of the then three-month Government of Canada treasury bill rate and 3.53% as reset quarterly. The Series 2 preferred shares will not be redeemable by Hydro One prior to November 20, 2020, but will be redeemable by Hydro One at a redemption price equal to $25.00 for each Series 2 preferred share redeemed, if redeemed on November 20, 2025 or on November 20 of every fifth year thereafter, or $25.50 for each Series 2 preferred share redeemed, if redeemed on any other date after November 20, 2020, in each case plus any accrued or unpaid dividends. The holders of Series 2 preferred shares will have the right, at their option, on November 20, 2025 and on November 20 of every fifth year thereafter, to convert all or any of their Series 2 preferred shares into Series 1 preferred shares on a one-for-one basis, subject to certain restrictions on conversion.

Share Ownership Restrictions

The Electricity Act imposes share ownership restrictions on securities of Hydro One carrying a voting right (Voting Securities). These restrictions provide that no person or company (or combination of persons or companies acting jointly or in concert) may beneficially own or exercise control or direction over more than 10% of any class or series of Voting Securities, including common shares of the Company (Share Ownership Restrictions). The Share Ownership Restrictions do not apply to Voting Securities held by the Province, nor to an underwriter who holds Voting Securities solely for the purpose of distributing those securities to purchasers who comply with the Share Ownership Restrictions.

23. DIVIDENDS

In 2017, preferred share dividends in the amount of $18 million (2016 - $19 million) and common share dividends in the amount of $518 million (2016 - $577 million) were declared. The 2016 common share dividends include $77 million for the post-Initial Public Offering (IPO) period from November 5 to December 31, 2015, and $500 million for the year ended December 31, 2016.

24. EARNINGS PER COMMON SHARE

Basic earnings per common share (EPS) is calculated by dividing net income attributable to common shareholders of Hydro One by the weighted average number of common shares outstanding.

Diluted EPS is calculated by dividing net income attributable to common shareholders of Hydro One by the weighted average number of common shares outstanding adjusted for the effects of potentially dilutive stock-based compensation plans, including the share grant plans and the LTIP, which are calculated using the treasury stock method.

37

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Year ended December 31	2017		2016
Net income attributable to common shareholders (millions of dollars)		658		721
Weighted average number of shares
Basic		595,287,586		595,000,000
Effect of dilutive stock-based compensation plans		2,234,665		1,700,823
Diluted		597,522,251		596,700,823
EPS
Basic		$1.11		$1.21
Diluted		$1.10		$1.21

The common shares contingently issuable as a result of the Convertible Debentures are not included in diluted EPS until conditions for closing the Avista Corporation acquisition are met.

25. STOCK-BASED COMPENSATION

Share Grant Plans

Hydro One has two share grant plans (Share Grant Plans), one for the benefit of certain members of the PWU (PWU Share Grant Plan) and one for the benefit of certain members of The Society (Society Share Grant Plan).

The PWU Share Grant Plan provides for the issuance of common shares of Hydro One from treasury to certain eligible members of the PWU annually, commencing on April 1, 2017 and continuing until the earlier of April 1, 2028 or the date an eligible employee no longer meets the eligibility criteria of the PWU Share Grant Plan. To be eligible, an employee must be a member of the Pension Plan on April 1, 2015, be employed on the date annual share issuance occurs and continue to have under 35 years of service. The requisite service period for the PWU Share Grant Plan began on July 3, 2015, which is the date the share grant plan was ratified by the PWU. The number of common shares issued annually to each eligible employee will be equal to 2.7% of such eligible employee’s salary as at April 1, 2015, divided by $20.50, being the price of the common shares of Hydro One in the IPO. The aggregate number of common shares issuable under the PWU Share Grant Plan shall not exceed 3,981,763 common shares. In 2015, 3,979,062 common shares were granted under the PWU Share Grant Plan.

The Society Share Grant Plan provides for the issuance of common shares of Hydro One from treasury to certain eligible members of The Society annually, commencing on April 1, 2018 and continuing until the earlier of April 1, 2029 or the date an eligible employee no longer meets the eligibility criteria of the Society Share Grant Plan. To be eligible, an employee must be a member of the Pension Plan on September 1, 2015, be employed on the date annual share issuance occurs and continue to have under 35 years of service. Therefore the requisite service period for the Society Share Grant Plan began on September 1, 2015. The number of common shares issued annually to each eligible employee will be equal to 2.0% of such eligible employee’s salary as at September 1, 2015, divided by $20.50, being the price of the common shares of Hydro One in the IPO. The aggregate number of common shares issuable under the Society Share Grant Plan shall not exceed 1,434,686 common shares. In 2015, 1,433,292 common shares were granted under the Society Share Grant Plan.

The fair value of the Hydro One 2015 share grants of $111 million was estimated based on the grant date share price of $20.50 and is recognized using the graded-vesting attribution method as the share grant plans have both a performance condition and a service condition. In 2017, 371,611 common shares were granted under the Share Grant Plans (2016 - nil). Total share based compensation recognized during 2017 was $17 million (2016 - $21 million) and was recorded as a regulatory asset.

A summary of share grant activity under the Share Grant Plans during years ended December 31, 2017 and 2016 is presented below:

Year ended December 31, 2017	Share Grants (number of common shares)			Weighted-Average Price
Share grants outstanding - beginning		5,334,415			$20.50
Vested and issued1		(371,611	)		—
Forfeited		(137,072	)		$20.50
Share grants outstanding - ending		4,825,732			$20.50

¹ On April 1, 2017, Hydro One issued from treasury 371,611 common shares to eligible employees in accordance with provisions of the PWU Share Grant Plan.

Year ended December 31, 2016	Share Grants (number of common shares)			Weighted-Average Price
Share grants outstanding - beginning		5,412,354			$20.50
Forfeited		(77,939	)		$20.50
Share grants outstanding - ending		5,334,415			$20.50

38

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Directors’ DSU Plan

Under the Directors’ DSU Plan, directors can elect to receive credit for their annual cash retainer in a notional account of DSUs in lieu of cash. Hydro One’s Board of Directors may also determine from time to time that special circumstances exist that would reasonably justify the grant of DSUs to a director as compensation in addition to any regular retainer or fee to which the director is entitled. Each DSU represents a unit with an underlying value equivalent to the value of one common share of the Company and is entitled to accrue common share dividend equivalents in the form of additional DSUs at the time dividends are paid, subsequent to declaration by Hydro One’s Board of Directors.

During the years ended December 31, 2017 and 2016, the Company granted awards under the Directors’ DSU Plan, as follows:

Year ended December 31 (number of DSUs)	2017		2016
DSUs outstanding - beginning		99,083		20,525
DSUs granted		88,007		78,558
DSUs outstanding - ending		187,090		99,083

For the year ended December 31, 2017, an expense of $2 million (2016 - $2 million) was recognized in earnings with respect to the Directors’ DSU Plan. At December 31, 2017, a liability of $4 million (2016 - $2 million), related to outstanding DSUs has been recorded at the closing price of the Company’s common shares of $22.40 and is included in long-term accounts payable and other liabilities on the Consolidated Balance Sheets.

Management DSU Plan

Under the Management DSU Plan, eligible executive employees can elect to receive a specified proportion of their annual short-term incentive in a notional account of DSUs in lieu of cash. Each DSU represents a unit with an underlying value equivalent to the value of one common share of the Company and is entitled to accrue common share dividend equivalents in the form of additional DSUs at the time dividends are paid, subsequent to declaration by Hydro One’s Board of Directors.

During the years ended December 31, 2017 and 2016, the Company granted awards under the Management DSU Plan, as follows:

Year ended December 31 (number of DSUs)	2017			2016
DSUs outstanding - beginning		—			—
Granted		68,897			—
Paid		(1,068	)		—
DSUs outstanding - ending		67,829			—

For the year ended December 31, 2017, an expense of $2 million (2016 - $nil) was recognized in earnings with respect to the Management DSU Plan. At December 31, 2017, a liability of $2 million (2016 - $nil) related to outstanding DSUs has been recorded at the closing price of the Company’s common shares of $22.40 and is included in long-term accounts payable and other liabilities on the Consolidated Balance Sheets.

Employee Share Ownership Plan

In 2015, Hydro One established Employee Share Ownership Plans (ESOP) for certain eligible management and non-represented employees (Management ESOP) and for certain eligible Society-represented staff (Society ESOP). Under the Management ESOP, the eligible management and non-represented employees may contribute between 1% and 6% of their base salary towards purchasing common shares of Hydro One. The Company matches 50% of their contributions, up to a maximum Company contribution of $25,000 per calendar year. Under the Society ESOP, the eligible Society-represented staff may contribute between 1% and 4% of their base salary towards purchasing common shares of Hydro One. The Company matches 25% of their contributions, with no maximum Company contribution per calendar year. In 2017, Company contributions made under the ESOP were $2 million (2016 - $2 million).

LTIP

Effective August 31, 2015, the Board of Directors of Hydro One adopted an LTIP. Under the LTIP, long-term incentives are granted to certain executive and management employees of Hydro One and its subsidiaries, and all equity-based awards will be settled in newly issued shares of Hydro One from treasury, consistent with the provisions of the plan. The aggregate number of shares issuable under the LTIP shall not exceed 11,900,000 shares of Hydro One.

The LTIP provides flexibility to award a range of vehicles, RSUs, PSUs, stock options, share appreciation rights, restricted shares, deferred share units and other share-based awards. The mix of vehicles is intended to vary by role to recognize the level of executive accountability for overall business performance.

39

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

During 2017 and 2016, the Company granted awards under its LTIP as follows:

	PSUs						RSUs
Year ended December 31 (number of units)	2017			2016			2017			2016
Units outstanding - beginning		230,600			—			254,150			—
Units granted		303,240			235,420			242,860			258,970
Units vested		(609	)		—			(14,079	)		—
Units forfeited		(103,251	)		(4,820	)		(89,501	)		(4,820	)
Units outstanding - ending		429,980			230,600			393,430			254,150

The grant date total fair value of the awards granted in 2017 was $13 million (2016 - $12 million). The compensation expense related to these awards recognized by the Company during 2017 was $6 million (2016 - $3 million).

26. NONCONTROLLING INTEREST

On December 16, 2014, transmission assets totalling $526 million were transferred from Hydro One Networks to B2M LP. This was financed by 60% debt ($316 million) and 40% equity ($210 million). On December 17, 2014, the Saugeen Ojibway Nation (SON) acquired a 34.2% equity interest in B2M LP for consideration of $72 million, representing the fair value of the equity interest acquired. The SON’s initial investment in B2M LP consists of $50 million of Class A units and $22 million of Class B units.

The Class B units have a mandatory put option which requires that upon the occurrence of an enforcement event (i.e. an event of default such as a debt default by the SON or insolvency event), Hydro One purchase the Class B units of B2M LP for net book value on the redemption date. The noncontrolling interest relating to the Class B units is classified on the Consolidated Balance Sheet as temporary equity because the redemption feature is outside the control of the Company. The balance of the noncontrolling interest is classified within equity.

The following tables show the movements in noncontrolling interest during the years ended December 31, 2017 and 2016:

Year ended December 31, 2017 (millions of dollars)	Temporary Equity			Equity			Total
Noncontrolling interest - beginning		22			50			72
Distributions to noncontrolling interest		(2	)		(4	)		(6	)
Net income attributable to noncontrolling interest		2			4			6
Noncontrolling interest - ending		22			50			72
Year ended December 31, 2016 (millions of dollars)	Temporary Equity			Equity			Total
Noncontrolling interest - beginning		23			52			75
Distributions to noncontrolling interest		(3	)		(6	)		(9	)
Net income attributable to noncontrolling interest		2			4			6
Noncontrolling interest - ending		22			50			72

40

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

27. RELATED PARTY TRANSACTIONS

The Province is a shareholder of Hydro One with approximately 47.4% ownership at December 31, 2017. The IESO, Ontario Power Generation Inc. (OPG), Ontario Electricity Financial Corporation (OEFC), and the OEB, are related parties to Hydro One because they are controlled or significantly influenced by the Province. Hydro One Brampton was a related party until February 28, 2017, when it was acquired from the Province by Alectra Inc., and subsequent to the acquisition by Alectra Inc., is no longer a related party to Hydro One.

Year ended December 31 (millions of dollars)
Related Party	Transaction	2017		2016
Province	Dividends paid		301		451
IESO	Power purchased		1,583		2,096
	Revenues for transmission services		1,521		1,549
	Amounts related to electricity rebates		357		—
	Distribution revenues related to rural rate protection		247		125
	Distribution revenues related to the supply of electricity to remote northern communities		32		32
	Funding received related to CDM programs		59		63
OPG	Power purchased		9		6
	Revenues related to provision of construction and equipment maintenance services		3		5
	Costs related to the purchase of services		1		1
OEFC	Power purchased from power contracts administered by the OEFC		2		1
OEB	OEB fees		8		11
Hydro One Brampton	Cost recovery from management, administrative and smart meter network services		—		3

Sales to and purchases from related parties are based on the requirements of the OEB’s Affiliate Relationships Code. Outstanding balances at period end are interest-free and settled in cash.

28. CONSOLIDATED STATEMENTS OF CASH FLOWS

The changes in non-cash balances related to operations consist of the following:

Year ended December 31 (millions of dollars)	2017			2016
Accounts receivable		195			(60	)
Due from related parties		(95	)		33
Materials and supplies		1			2
Prepaid expenses and other assets		7			(15	)
Accounts payable		7			19
Accrued liabilities		(89	)		53
Due to related parties		10			9
Accrued interest		(6	)		9
Long-term accounts payable and other liabilities		(2	)		6
Post-retirement and post-employment benefit liability		85			78
		113			134

Capital Expenditures

The following table reconciles investments in property, plant and equipment and the amounts presented in the Consolidated Statements of Cash Flows after accounting for capitalized depreciation and the net change in related accruals:

Year ended December 31 (millions of dollars)	2017			2016
Capital investments in property, plant and equipment		(1,493	)		(1,630	)
Capitalized depreciation and net change in accruals included in capital investments in property, plant and equipment		26			30
Cash outflow for capital expenditures – property, plant and equipment		(1,467	)		(1,600	)

The following table reconciles investments in intangible assets and the amounts presented in the Consolidated Statements of Cash Flows after accounting for the net change in related accruals:

Year ended December 31 (millions of dollars)	2017			2016
Capital investments in intangible assets		(74	)		(67	)
Net change in accruals included in capital investments in intangible assets		(6	)		6
Cash outflow for capital expenditures – intangible assets		(80	)		(61	)

41

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

Capital Contributions

Hydro One enters into contracts governed by the OEB Transmission System Code when a transmission customer requests a new or upgraded transmission connection. The customer is required to make a capital contribution to Hydro One based on the shortfall between the present value of the costs of the connection facility and the present value of revenues. The present value of revenues is based on an estimate of load forecast for the period of the contract with Hydro One. Once the connection facility is commissioned, in accordance with the OEB Transmission System Code, Hydro One will periodically reassess the estimated of load forecast which will lead to a decrease, or an increase in the capital contributions from the customer. The increase or decrease in capital contributions is recorded directly to fixed assets in service. In 2017, capital contributions from these reassessments totalled $9 million (2016 - $21 million), which represents the difference between the revised load forecast of electricity transmitted compared to the load forecast in the original contract, subject to certain adjustments.

Supplementary Information

Year ended December 31 (millions of dollars)	2017		2016
Net interest paid		475		418
Income taxes paid		12		32

29. CONTINGENCIES

Legal Proceedings

Hydro One is involved in various lawsuits and claims in the normal course of business. In the opinion of management, the outcome of such matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations or cash flows.

Hydro One Inc., Hydro One Networks, Hydro One Remote Communities, and Norfolk Power Distribution Inc. are defendants in a class action suit in which the representative plaintiff is seeking up to $125 million in damages related to allegations of improper billing practices. The plaintiff’s motion for certification was dismissed by the court on November 28, 2017, but the plaintiff has appealed the court’s decision, and it is likely that no decision will be rendered by the appeal court until the second half of 2018. At this time, an estimate of a possible loss related to this claim cannot be made.

To date, four putative class action lawsuits have been filed by purported Avista Corporation shareholders in relation to the Merger. First, Fink v. Morris, et al., was filed in Washington state court and the amended complaint names as defendants Avista Corporation’s directors, Hydro One, Olympus Holding Corp., Olympus Corp., and Bank of America Merrill Lynch. The suit alleges that Avista Corporation’s directors breached their fiduciary duties in relation to the Merger, aided and abetted by Hydro One, Olympus Holding Corp., Olympus Corp. and Bank of America Merrill Lynch. The Washington state court issued an order staying the litigation until after the plaintiffs file an amended complaint, which must be no later than 30 days after Avista Corporation or Hydro One publicly announces that the Merger has closed. Second, Jenß v. Avista Corp., et al., Samuel v. Avista Corp., et al., and Sharpenter v. Avista Corp., et al., were each filed in the US District Court for the Eastern District of Washington and named as defendants Avista Corporation and its directors; Sharpenter also named Hydro One, Olympus Holding Corp., and Olympus Corp. The lawsuits alleged that the preliminary proxy statement omitted material facts necessary to make the statements therein not false or misleading. Jenß, Samuel, and Sharpenter were all voluntarily dismissed by the respective plaintiffs with no consideration paid by any of the defendants. The one remaining class action is consistent with expectations for US merger transactions and, while there is no certainty as to outcome, Hydro One believes that the lawsuit is not material to Hydro One.

Transfer of Assets

The transfer orders by which the Company acquired certain of Ontario Hydro’s businesses as of April 1, 1999 did not transfer title to some assets located on Reserves (as defined in the Indian Act (Canada)). Currently, the OEFC holds these assets. Under the terms of the transfer orders, the Company is required to manage these assets until it has obtained all consents necessary to complete the transfer of title of these assets to itself. The Company cannot predict the aggregate amount that it may have to pay, either on an annual or one-time basis, to obtain the required consents. In 2017, the Company paid approximately $2 million (2016 - $1 million) in respect of consents obtained. If the Company cannot obtain the required consents, the OEFC will continue to hold these assets for an indefinite period of time. If the Company cannot reach a satisfactory settlement, it may have to relocate these assets to other locations at a cost that could be substantial or, in a limited number of cases, to abandon a line and replace it with diesel-generation facilities. The costs relating to these assets could have a material adverse effect on the Company’s results of operations if the Company is not able to recover them in future rate orders.

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HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

30. COMMITMENTS

The following table presents a summary of Hydro One’s commitments under leases, outsourcing and other agreements due in the next 5 years and thereafter:

December 31, 2017 (millions of dollars)	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter
Outsourcing agreements		139		95		2		2		2		7
Long-term software/meter agreement		17		17		16		2		1		3
Operating lease commitments		12		7		11		6		4		4

Outsourcing Agreements

Hydro One has agreements with Inergi LP (Inergi) for the provision of back office and IT outsourcing services, including settlements, source to pay services, pay operations services, information technology and finance and accounting services, expiring on December 31, 2019, and for the provision of customer service operations outsourcing services expiring on February 28, 2018. Hydro One is currently in the process of insourcing the customer service operations services and will not be renewing the existing agreement for these services with Inergi. Agreements have been reached with The Society and the PWU to facilitate the insourcing of these services effective March 1, 2018.

Brookfield Global Integrated Solutions (formerly Brookfield Johnson Controls Canada LP) (Brookfield) provides services to Hydro One, including facilities management and execution of certain capital projects as deemed required by the Company. The agreement with Brookfield for these services expires in December 2024.

Long-term Software/Meter Agreement

Trilliant Holdings Inc. and Trilliant Networks (Canada) Inc. (collectively Trilliant) provide services to Hydro One for the supply, maintenance and support services for smart meters and related hardware and software, including additional software licences, as well as certain professional services. The agreement with Trilliant for these services expires in December 2025, but Hydro One has the option to renew for an additional term of five years at its sole discretion.

Operating Leases

Hydro One is committed as lessee to irrevocable operating lease contracts for buildings used in administrative and service-related functions and storing telecommunications equipment. These leases have typical terms of between three and five years, but several leases have lesser or greater terms to address special circumstances and/or opportunities. Renewal options, which are generally prevalent in most leases, have similar terms of three to five years. All leases include a clause to enable upward revision of the rental charge on an annual basis or on renewal according to prevailing market conditions or pre-established rents. There are no restrictions placed upon Hydro One by entering into these leases. During the year ended December 31, 2017, the Company made lease payments totalling $12 million (2016 - $11 million).

Other Commitments

The following table presents a summary of Hydro One’s other commercial commitments by year of expiry in the next 5 years and thereafter:

December 31, 2017 (millions of dollars)	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter
Credit facilities		—		—		—		250		2,300		—
Letters of credit1		177		—		—		—		—		—
Guarantees2		325		—		—		—		—		—

¹  Letters of credit consist of a $154 million letter of credit related to retirement compensation arrangements, a $16 million letter of credit provided to the IESO for prudential support, $6 million in letters of credit to satisfy debt service reserve requirements, and $1 million in letters of credit for various operating purposes.

²  Guarantees consist of prudential support provided to the IESO by Hydro One Inc. on behalf of its subsidiaries.

Prudential Support

Purchasers of electricity in Ontario, through the IESO, are required to provide security to mitigate the risk of their default based on their expected activity in the market. The IESO could draw on these guarantees and/or letters of credit if these purchasers fail to make a payment required by a default notice issued by the IESO. The maximum potential payment is the face value of any letters of credit plus the amount of the parental guarantees.

Retirement Compensation Arrangements

Bank letters of credit have been issued to provide security for Hydro One Inc.’s liability under the terms of a trust fund established pursuant to the supplementary pension plan for eligible employees of Hydro One Inc. The supplementary pension plan trustee is required to draw upon these letters of credit if Hydro One Inc. is in default of its obligations under the terms of this plan. Such obligations include the requirement to provide the trustee with an annual actuarial report as well as letters of credit sufficient to

43

HYDRO ONE LIMITED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2017 and 2016

secure Hydro One Inc.’s liability under the plan, to pay benefits payable under the plan and to pay the letter of credit fee. The maximum potential payment is the face value of the letters of credit.

31. SEGMENTED REPORTING

Hydro One has three reportable segments:

• The Transmission Segment, which comprises the transmission of high voltage electricity across the province, interconnecting more than 70 local distribution companies and certain large directly connected industrial customers throughout the Ontario electricity grid;

• The Distribution Segment, which comprises the delivery of electricity to end customers and certain other municipal electricity distributors; and

• Other Segment, which includes certain corporate activities and the operations of the Company’s telecommunications business.

The designation of segments has been based on a combination of regulatory status and the nature of the services provided. Operating segments of the Company are determined based on information used by the chief operating decision maker in deciding how to allocate resources and evaluate the performance of each of the segments. The Company evaluates segment performance based on income before financing charges and income taxes from continuing operations (excluding certain allocated corporate governance costs).

Year ended December 31, 2017 (millions of dollars)	Transmission		Distribution		Other			Consolidated
Revenues		1,578		4,366		46			5,990
Purchased power		—		2,875		—			2,875
Operation, maintenance and administration		375		593		98			1,066
Depreciation and amortization		420		390		7			817
Income (loss) before financing charges and income taxes		783		508		(59	)		1,232
Capital investments		968		588		11			1,567
Year ended December 31, 2016 (millions of dollars)	Transmission		Distribution		Other			Consolidated
Revenues		1,584		4,915		53			6,552
Purchased power		—		3,427		—			3,427
Operation, maintenance and administration		382		608		79			1,069
Depreciation and amortization		390		379		9			778
Income (loss) before financing charges and income taxes		812		501		(35	)		1,278
Capital investments		988		703		6			1,697
Total Assets by Segment:
December 31 (millions of dollars)					2017			2016
Transmission						13,608			13,071
Distribution						9,259			9,379
Other						2,834			2,901
Total assets						25,701			25,351
Total Goodwill by Segment:
December 31 (millions of dollars)					2017			2016
Transmission (Note 4)						157			159
Distribution						168			168
Total goodwill						325			327

All revenues, costs and assets, as the case may be, are earned, incurred or held in Canada.

32. SUBSEQUENT EVENTS

Dividends

On February 12, 2018, preferred share dividends in the amount of $4 million and common share dividends in the amount of $131 million ($0.22 per common share) were declared.

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