Document:

EX-4.4

 Exhibit 4.4 

HYDRO ONE LIMITED 
 CONDENSED INTERIM CONSOLIDATED STATEMENTS OF OPERATIONS
AND COMPREHENSIVE INCOME (unaudited) 
 For the three and nine months ended September 30, 2018 and 2017 

 

																	
	 	  	 Three months ended

September 30
	 	  	 Nine months ended

September 30
	 
	  (millions of Canadian dollars, except per share amounts)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Revenues
	  				  				  				  			
	 Distribution (includes $68 related party revenues; (2017 – $70) and $205 (2017—$213) for the
three and nine months ended September 30, respectively) (Note 23)
	  	 	1,103	 	  	 	1,040	 	  	 	3,284	 	  	 	3,317	 
	 Transmission (includes $475 related party revenues (2017 – $390) and $1,295 (2017 - $1,125) for the
three and nine months ended September 30, respectively) (Note 23)
	  	 	493	 	  	 	471	 	  	 	1,344	 	  	 	1,199	 
	 Other
	  	 	10	 	  	 	11	 	  	 	31	 	  	 	35	 
	 	  	 	1,606	 	  	 	1,522	 	  	 	4,659	 	  	 	4,551	 
					
	 Costs
	  				  				  				  			
	 Purchased power (includes $324 related party costs (2017 – $278) and $1,089 (2017 - $1,177) for the
three and nine months ended September 30, respectively) (Note 23)
	  	 	733	 	  	 	675	 	  	 	2,158	 	  	 	2,213	 
	 Operation, maintenance and administration (Note 23)
	  	 	271	 	  	 	277	 	  	 	797	 	  	 	822	 
	 Depreciation and amortization (Note 5)
	  	 	213	 	  	 	209	 	  	 	620	 	  	 	603	 
	 	  	 	1,217	 	  	 	1,161	 	  	 	3,575	 	  	 	3,638	 
					
	 Income before financing charges and income taxes
	  	 	389	 	  	 	361	 	  	 	1,084	 	  	 	913	 
	 Financing charges (Note 6)
	  	 	149	 	  	 	114	 	  	 	336	 	  	 	320	 
					
	 Income before income taxes
	  	 	240	 	  	 	247	 	  	 	748	 	  	 	593	 
	 Income taxes (Note 7)
	  	 	41	 	  	 	23	 	  	 	115	 	  	 	73	 
	 Net income
	  	 	199	 	  	 	224	 	  	 	633	 	  	 	520	 
					
	 Other comprehensive income
	  	 	2	 	  	 	—	 	  	 	2	 	  	 	1	 
	 Comprehensive income
	  	 	201	 	  	 	224	 	  	 	635	 	  	 	521	 
					
	 Net income attributable to:
	  				  				  				  			
	 Noncontrolling interest
	  	 	1	 	  	 	1	 	  	 	4	 	  	 	4	 
	 Preferred shareholders
	  	 	4	 	  	 	4	 	  	 	13	 	  	 	13	 
	 Common shareholders
	  	 	194	 	  	 	219	 	  	 	616	 	  	 	503	 
	 	  	 	199	 	  	 	224	 	  	 	633	 	  	 	520	 
					
	 Comprehensive income attributable to:
	  				  				  				  			
	 Noncontrolling interest
	  	 	1	 	  	 	1	 	  	 	4	 	  	 	4	 
	 Preferred shareholders
	  	 	4	 	  	 	4	 	  	 	13	 	  	 	13	 
	 Common shareholders
	  	 	196	 	  	 	219	 	  	 	618	 	  	 	504	 
	 	  	 	201	 	  	 	224	 	  	 	635	 	  	 	521	 
					
	 Earnings per common share (Note 21)
	  				  				  				  			
	 Basic
	  	$	0.33	 	  	$	0.37	 	  	$	1.03	 	  	$	0.85	 
	 Diluted
	  	$	0.32	 	  	$	0.37	 	  	$	1.03	 	  	$	0.84	 
	 Dividends per common share declared (Note
20)
	  	$	0.23	 	  	$	0.22	 	  	$	0.68	 	  	$	0.65	 

 See accompanying notes to Condensed Interim Consolidated Financial Statements (unaudited). 

  

					
		 	1	 	

 HYDRO ONE LIMITED 

CONDENSED INTERIM CONSOLIDATED BALANCE SHEETS (unaudited) 
 At
September 30, 2018 and December 31, 2017 
  

									
	(millions of Canadian dollars)	  	September 30,
2018	 	 	December 31,
2017	 
	 Assets
	  				 			
	 Current assets:
	  				 			
	 Cash and cash equivalents
	  	 	613	 	 	 	25	 
	 Accounts receivable (Note 8)
	  	 	590	 	 	 	636	 
	 Due from related parties
	  	 	310	 	 	 	253	 
	 Other current assets (Note 9)
	  	 	129	 	 	 	105	 
	 	  	 	1,642	 	 	 	1,019	 
			
	 Property, plant and equipment (Note 10)
	  	 	20,475	 	 	 	19,947	 
	 Other long-term assets:
	  				 			
	 Regulatory assets (Note 11)
	  	 	3,227	 	 	 	3,049	 
	 Deferred income tax assets
	  	 	783	 	 	 	987	 
	 Intangible assets (net of accumulated amortization – $426; 2017 – $375)
	  	 	379	 	 	 	369	 
	 Goodwill
	  	 	325	 	 	 	325	 
	 Other assets
	  	 	6	 	 	 	5	 
		  	 	4,720	 	 	 	4,735	 
	 Total assets
	  	 	26,837	 	 	 	25,701	 
			
	 Liabilities
	  				 			
	 Current liabilities:
	  				 			
	 Short-term notes payable (Note 14)
	  	 	444	 	 	 	926	 
	 Long-term debt payable within one year (Notes 14, 16)
	  	 	981	 	 	 	752	 
	 Accounts payable and other current liabilities (Note 12)
	  	 	960	 	 	 	905	 
	 Due to related parties
	  	 	6	 	 	 	157	 
	 	  	 	2,391	 	 	 	2,740	 
			
	 Long-term liabilities:
	  				 			
	 Long-term debt (includes $839 measured at fair value; 2017 – $541) (Notes 14, 16)
	  	 	10,475	 	 	 	9,315	 
	 Convertible debentures (Notes 15, 16)
	  	 	489	 	 	 	487	 
	 Regulatory liabilities (Note 11)
	  	 	174	 	 	 	128	 
	 Deferred income tax liabilities
	  	 	74	 	 	 	71	 
	 Other long-term liabilities (Note 13)
	  	 	2,755	 	 	 	2,707	 
		  	 	13,967	 	 	 	12,708	 
	 Total liabilities
	  	 	16,358	 	 	 	15,448	 
			
	 Contingencies and Commitments (Notes 25, 26)
	  				 			
	 Subsequent Events (Note 28)
	  				 			
			
	 Noncontrolling interest subject to redemption
	  	 	21	 	 	 	22	 
			
	 Equity
	  				 			
	 Common shares (Note 19)
	  	 	5,641	 	 	 	5,631	 
	 Preferred shares (Note 19)
	  	 	418	 	 	 	418	 
	 Additional paid-in capital
	  	 	54	 	 	 	49	 
	 Retained earnings
	  	 	4,301	 	 	 	4,090	 
	 Accumulated other comprehensive loss
	  	 	(5	) 	 	 	(7	) 
	 Hydro One shareholders’ equity
	  	 	10,409	 	 	 	10,181	 
			
	 Noncontrolling interest
	  	 	49	 	 	 	50	 
	 Total equity
	  	 	10,458	 	 	 	10,231	 
	 	  	 	26,837	 	 	 	25,701	 

 See accompanying notes to Condensed Interim Consolidated Financial Statements (unaudited). 

  

					
		 	2	 	

 HYDRO ONE LIMITED 

CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) 

For the nine months ended September 30, 2018 and 2017 
  

																																	
	  Nine months ended September 30, 2018
  (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	 	 	Total
Equity	 
	 January 1, 2018
	  	 	5,631	 	  	 	418	 	  	 	49	 	 	 	4,090	 	 	 	(7	) 	 	 	10,181	 	 	 	50	 	 	 	10,231	 
	 Net income
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	629	 	 	 	—	 	 	 	629	 	 	 	3	 	 	 	632	 
	 Other comprehensive income
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	—	 	 	 	2	 	 	 	2	 	 	 	—	 	 	 	2	 
	 Distributions to noncontrolling interest
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(4	) 	 	 	(4	) 
	 Dividends on preferred shares
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	(13	) 	 	 	—	 	 	 	(13	) 	 	 	—	 	 	 	(13	) 
	 Dividends on common shares
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	(405	) 	 	 	—	 	 	 	(405	) 	 	 	—	 	 	 	(405	) 
	 Common shares issued
	  	 	10	 	  	 	—	 	  	 	(10	) 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	 Stock-based compensation
	  	 	—	 	  	 	—	 	  	 	15	 	 	 	—	 	 	 	—	 	 	 	15	 	 	 	—	 	 	 	15	 
	 September 30,
2018
	  	 	5,641	 	  	 	418	 	  	 	54	 	 	 	4,301	 	 	 	(5	) 	 	 	10,409	 	 	 	49	 	 	 	10,458	 
									
	  Nine months ended September 30, 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	 	 	Total
Equity	 
	 January 1, 2017
	  	 	5,623	 	  	 	418	 	  	 	34	 	 	 	3,950	 	 	 	(8	) 	 	 	10,017	 	 	 	50	 	 	 	10,067	 
	 Net income
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	516	 	 	 	—	 	 	 	516	 	 	 	3	 	 	 	519	 
	 Other comprehensive income
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	—	 	 	 	1	 	 	 	1	 	 	 	—	 	 	 	1	 
	 Distributions to noncontrolling interest
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(3	) 	 	 	(3	) 
	 Dividends on preferred shares
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	(13	) 	 	 	—	 	 	 	(13	) 	 	 	—	 	 	 	(13	) 
	 Dividends on common shares
	  	 	—	 	  	 	—	 	  	 	—	 	 	 	(387	) 	 	 	—	 	 	 	(387	) 	 	 	—	 	 	 	(387	) 
	 Common shares issued
	  	 	8	 	  	 	—	 	  	 	(8	) 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 
	 Stock-based compensation
	  	 	—	 	  	 	—	 	  	 	18	 	 	 	—	 	 	 	—	 	 	 	18	 	 	 	—	 	 	 	18	 
	 September 30,
2017
	  	 	5,631	 	  	 	418	 	  	 	44	 	 	 	4,066	 	 	 	(7	) 	 	 	10,152	 	 	 	50	 	 	 	10,202	 

 See accompanying notes to Condensed Interim Consolidated Financial Statements (unaudited). 

  

					
		 	3	 	

 HYDRO ONE LIMITED 

CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) 
 For the
three and nine months ended September 30, 2018 and 2017 
  

																	
	 	  	Three months ended
September 30	 	 	Nine months ended
September 30	 
	  (millions of Canadian dollars)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Operating activities
	  				 				 				 			
	 Net income
	  	 	199	 	 	 	224	 	 	 	633	 	 	 	520	 
	 Environmental expenditures
	  	 	(7	) 	 	 	(7	) 	 	 	(17	) 	 	 	(19	) 
	 Adjustments for non-cash items:
	  				 				 				 			
	 Depreciation and amortization (excluding asset removal costs)
	  	 	188	 	 	 	187	 	 	 	549	 	 	 	537	 
	 Regulatory assets and liabilities
	  	 	(29	) 	 	 	(32	) 	 	 	(32	) 	 	 	92	 
	 Deferred income taxes
	  	 	36	 	 	 	17	 	 	 	95	 	 	 	55	 
	 Unrealized loss (gain) on foreign exchange contract
	  	 	24	 	 	 	—	 	 	 	(25	) 	 	 	—	 
	 Other
	  	 	12	 	 	 	1	 	 	 	27	 	 	 	9	 
	 Changes in non-cash
balances related to operations (Note 24)
	  	 	85	 	 	 	52	 	 	 	(54	) 	 	 	(1	) 
	 Net cash from operating activities
	  	 	508	 	 	 	442	 	 	 	1,176	 	 	 	1,193	 
					
	 Financing activities
	  				 				 				 			
	 Long-term debt issued
	  	 	—	 	 	 	—	 	 	 	1,400	 	 	 	—	 
	 Long-term debt repaid
	  	 	—	 	 	 	—	 	 	 	(1	) 	 	 	(1	) 
	 Short-term notes issued
	  	 	445	 	 	 	1,232	 	 	 	2,987	 	 	 	2,810	 
	 Short-term notes repaid
	  	 	(1,049	) 	 	 	(1,053	) 	 	 	(3,469	) 	 	 	(2,385	) 
	 Convertible debentures issued (Note 15)
	  	 	—	 	 	 	513	 	 	 	—	 	 	 	513	 
	 Dividends paid
	  	 	(141	) 	 	 	(135	) 	 	 	(418	) 	 	 	(400	) 
	 Distributions paid to noncontrolling interest
	  	 	(1	) 	 	 	(1	) 	 	 	(6	) 	 	 	(4	) 
	 Other
	  	 	—	 	 	 	(27	) 	 	 	(6	) 	 	 	(27	) 
	 Net cash from (used in) financing activities
	  	 	(746	) 	 	 	529	 	 	 	487	 	 	 	506	 
					
	 Investing activities
	  				 				 				 			
	 Capital expenditures (Note 24)
	  				 				 				 			
	 Property, plant and equipment
	  	 	(370	) 	 	 	(358	) 	 	 	(1,022	) 	 	 	(1,071	) 
	 Intangible assets
	  	 	(25	) 	 	 	(24	) 	 	 	(61	) 	 	 	(57	) 
	 Capital contributions received
	  	 	—	 	 	 	—	 	 	 	—	 	 	 	9	 
	 Other
	  	 	1	 	 	 	—	 	 	 	8	 	 	 	(8	) 
	 Net cash used in investing activities
	  	 	(394	) 	 	 	(382	) 	 	 	(1,075	) 	 	 	(1,127	) 
					
	 Net change in cash and cash equivalents
	  	 	(632	) 	 	 	589	 	 	 	588	 	 	 	572	 
	 Cash and cash equivalents, beginning of period
	  	 	1,245	 	 	 	33	 	 	 	25	 	 	 	50	 
	 Cash and cash equivalents, end of period
	  	 	613	 	 	 	622	 	 	 	613	 	 	 	622	 

 See accompanying notes to Condensed Interim Consolidated Financial Statements (unaudited). 

  

					
		 	4	 	

 HYDRO ONE LIMITED 
 NOTES
TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) 
 For the three and nine months ended September 30, 2018 and 2017 

 

	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 September 30, 2018, the Province held approximately 47.4% (December 31, 2017 - 47.4%) of the common shares of Hydro One. The principal businesses of Hydro One are the transmission and
distribution of electricity to customers within Ontario. 
 Earnings for interim periods may not be indicative of results for the year due to the impact
of seasonal weather conditions on customer demand and market pricing. 
 Rate Setting 

Transmission 
 In December 2017, the Ontario
Energy Board (OEB) approved Hydro One Networks Inc.‘s (Hydro One Networks) 2018 rates revenue requirement of $1,511 million. See Note 11 - Regulatory Assets and Liabilities for additional information. 

On May 10, 2018, the OEB issued its Decision and Rate Order on B2M LP’s 2018 transmission application reflecting revenue requirement of
$36 million, effective January 1, 2018. 
 Distribution 

In March 2017, Hydro One Networks filed an application with the OEB for 2018-2022 distribution rates. The requested revenue requirements, updated in June
2018, are $1,514 million for 2018, $1,561 million for 2019, $1,607 million for 2020, $1,681 million for 2021, and $1,722 million for 2022. The OEB decision on this application is pending. 

On November 17, 2017, Hydro One filed with the OEB a request for 2018 interim rates based on 2017
OEB-approved rates, adjusted for an updated load forecast. On December 1, 2017, the OEB denied this request and set interim 2018 rates based on 2017 OEB-approved
rates with no adjustments. 
  

	2.	 SIGNIFICANT ACCOUNTING POLICIES 

Basis of Consolidation 
 These unaudited condensed interim
Consolidated Financial Statements (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) for interim financial statements and in Canadian dollars. 

The accounting policies applied are consistent with those outlined in Hydro One’s annual audited consolidated financial statements for the year ended
December 31, 2017, with the exception of the adoption of new accounting standards as described below and in Note 3 - New Accounting Pronouncements. These Consolidated Financial Statements reflect adjustments, that are, in the opinion of
management, necessary to reflect fairly the financial position and results of operations for the respective periods. These Consolidated Financial Statements do not include all disclosures required in the annual financial statements and should be
read in conjunction with the 2017 annual audited consolidated financial statements. 
 Revenue Recognition 

The Company adopted Accounting Standard Codification (ASC) 606 - Revenue from Contracts with Customers on January 1, 2018 using the
retrospective method, without the election of any practical expedients. There was no material impact to the Company’s revenue recognition policy as a result of adopting ASC 606. 

Nature of Revenues 
 Transmission revenues
predominantly consist of transmission tariffs, which are collected through OEB-approved Uniform Transmission Rates (UTR) and the monthly peak demand for electricity across Hydro One’s high-voltage
network. OEB-approved UTR is based on an approved revenue requirement that includes a rate of return. The transmission tariffs are designed to recover revenues necessary to support the Company’s
transmission system with sufficient capacity to accommodate the maximum expected demand which is influenced by weather and economic conditions. Transmission revenues are 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. 

  

					
		 	5	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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. 
 Employee Future Benefits 

The Company adopted Accounting Standard Update (ASU) 2017-07 on January 1, 2018. The Company used the
retrospective method for guidance relating to the presentation of the service cost component and the other components of net periodic pension and post-retirement benefit costs in the Statement of Operations and Comprehensive Income. There was no
change in presentation in the Statement of Operations and Comprehensive Income. The Company used the prospective method for guidance relating to the capitalization of the service cost component of net periodic pension and post-retirement and
post-employment benefit costs in assets. Upon adoption of ASU 2017-07, the Company recognized the Post-Retirement and Post-Employment Benefits Non-Service Costs
Regulatory Asset. See below and Note 11 - Regulatory Assets and Liabilities for additional information. 
 Defined Benefit Pension 

Defined benefit pension costs are recorded on an accrual basis for financial reporting purposes. Hydro One records a regulatory asset equal to the net
underfunded projected benefit obligation for its defined benefit pension plan. Defined benefit pension costs are attributed to labour and a portion not exceeding the service cost component of accrual basis defined benefit pension costs is
capitalized as part of the cost of property, plant and equipment and intangible assets. The remaining defined benefit pension costs are charged to results of operations (operation, maintenance and administration costs). 

Post-Retirement and Post-Employment Benefits 

All post-retirement and post-employment benefit costs are attributed to labour and are either charged to results of operations (operation, maintenance and
administration costs) or capitalized as part of the cost of property, plant and equipment and intangible assets for service cost component and to regulatory assets for all other components of the benefit costs, consistent with their inclusion in OEB-approved rates. 
  

	3.	 NEW ACCOUNTING PRONOUNCEMENTS 

The following tables present ASC guidance issued by the Financial Accounting Standards Board that are applicable to Hydro One: 

Recently Adopted Accounting Guidance 
  

									
	  Guidance	  	Date issued	  	Description	  	Effective date	  	Impact on Hydro One
	  ASC 606	  	 May 2014 –
 November
2017
	  	ASC 606 Revenue from Contracts with Customers replaced ASC 605 Revenue Recognition. ASC 606 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.	  	January 1, 2018	  	 Hydro One adopted ASC 606 on January 1, 2018 using the retrospective method, without the election of any
practical expedients and there was no material impact to the Company’s revenue recognition policy upon adoption. The Company has included the disclosure requirements of ASC 606 for interim periods in the year of adoption.

 

	  ASU   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 applied for a regulatory asset to maintain the capitalization of post-employment benefit related costs and as such, there is no material impact upon adoption. See Note 2 -
Significant Accounting Policies and Note 11 - Regulatory Assets and Liabilities.

  

					
		 	6	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

									
	Recently Issued Accounting Guidance Not Yet Adopted
					
	  Guidance	  	Date issued	  	Description	  	Effective date	  	Anticipated impact on Hydro One
	   2016-02

  2018-01
   2018-10
   2018-11
	  	February 2016 – July 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 ASC 842 land easements that exist or expired before the entity’s adoption of ASC 842 and that were not previously accounted for as leases under ASC 840. ASU 2018-10 amends narrow
aspects of ASC 842. ASU 2018-11 provides entities with an additional and option transition method in adopting ASC 842. ASU 2018-11 also permits lessors to elect an
optional practical expedient to not separate non-lease components from the associated lease component by underlying asset classes.

 
	  	January 1, 2019	  	The Company has reviewed a substantial number of existing leases and relevant contracts and continues its assessment activities. No quantitative determination has been made at this time. The
Company is on track for implementation of this standard by the effective date.
	  2018-07	  	June 2018	  	 Expansion in the scope of ASC 718 to include share-based payment
transactions for acquiring goods and services from non-employees. Previously, ASC 718 was only applicable to share-based payment transactions for acquiring goods and services from employees.

 
	  	January 1, 2019	  	Under assessment
	  2018-13	  	August 2018	  	 Disclosure requirements on fair value measurements in ASC 820 are modified to improve the effectiveness of
disclosures in financial statement notes.
  
	  	January 1, 2020	  	Under assessment
	  2018-14	  	August 2018	  	 Disclosure requirements related to single-employer defined benefit pension or other post-retirement benefit
plans are added, removed or clarified to improve the effectiveness of disclosures in financial statement notes.
  
	  	January 1, 2021	  	Under assessment
	  2018-15	  	August 2018	  	 The amendment aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement
that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The accounting for the service element of a hosting arrangement is
not affected by the amendment.
  
	  	January 1, 2020	  	Under assessment

  

	4.	 BUSINESS COMBINATIONS 

Avista Corporation Purchase Agreement 
 In July 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. Regulatory authorities in Washington and Oregon have extended the timetable for arriving at a decision in Hydro One’s acquisition of Avista Corporation to
mid-December 2018. In addition, the Idaho Public Utilities Commission rescheduled its hearing from July 23, 2018 to November 26-27, 2018. 

See Note 14 - Debt and Credit Agreements, Note 15 - Convertible Debentures and Note 16 - Fair Value of Financial Instruments and Risk Management for
details of bridge financing, convertible debentures and foreign exchange contract, respectively, related to financing of the Merger. 
 Orillia Power Purchase
Agreement 
 In August 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 and regulatory approval by the OEB. In September 2016, Hydro One filed an application with the OEB to acquire Orillia Power, which was denied by the OEB on April 12, 2018. On September 26, 2018, Hydro One filed a new
application with the OEB for approval to acquire Orillia Power. 
 Peterborough Distribution Purchase Agreement 

On July 31, 2018, Hydro One reached an agreement to acquire the business and distribution assets of Peterborough Distribution Inc. (Peterborough
Distribution), an electricity distribution company located in east central Ontario, from the City of Peterborough. Hydro One will pay the City of Peterborough $105 million for the transaction. The acquisition is conditional upon the
satisfaction of customary closing conditions and approval by the OEB and the Competition Bureau. On October 12, 2018, the Company filed an application with the OEB for approval of the acquisition. 

  

					
		 	7	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

	5.	 DEPRECIATION AND AMORTIZATION 

 

																	
	 	  	 Three months ended
September 30

 
	 	  	 Nine months ended
September 30

 
	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Depreciation of property, plant and equipment
	  	 	163	 	  	 	164	 	  	 	481	 	  	 	473	 
	 Asset removal costs
	  	 	25	 	  	 	22	 	  	 	71	 	  	 	66	 
	 Amortization of intangible assets
	  	 	18	 	  	 	16	 	  	 	51	 	  	 	45	 
	 Amortization of regulatory assets
	  	 	7	 	  	 	7	 	  	 	17	 	  	 	19	 
	 	  	 	213	 	  	 	209	 	  	 	620	 	  	 	603	 

  

	6.	 FINANCING CHARGES 

  

																	
	 	  	 Three months ended
September 30

 
	 	  	 Nine months ended
September 30

 
	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	2018	 	 	2017	 
	 Interest on long-term debt
	  	 	118	 	  	 	115	 	  	 	332	 	 	 	342	 
	 Unrealized loss (gain) on foreign exchange contract (Note 16)
	  	 	24	 	  	 	—	 	  	 	(25	) 	 	 	—	 
	 Interest on convertible debentures
	  	 	15	 	  	 	9	 	  	 	46	 	 	 	9	 
	 Interest on short-term notes
	  	 	2	 	  	 	1	 	  	 	9	 	 	 	3	 
	 Other
	  	 	4	 	  	 	3	 	  	 	14	 	 	 	8	 
	 Less: Interest capitalized on construction and development in
progress
	  	 	(14)	 	  	 	(14)	 	  	 	(40	) 	 	 	(42	) 
	 	  	 	149	 	  	 	114	 	  	 	336	 	 	 	320	 

  

	7.	 INCOME TAXES 

As a rate regulated utility company, the Company’s effective tax rate excludes temporary differences that are recoverable in future rates charged to
customers. 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: 
  

									
	 	 	 Nine months ended September 30

 
	 
	  (millions of dollars)	 	2018	 	 	2017	 
	 Income before income taxes
	 	 	748	 	 	 	593	 
	 Income taxes at statutory rate of 26.5% (2017 - 26.5%)
	 	 	198	 	 	 	157	 
			
	 Increase (decrease) resulting from:
	 				 			
	 Net temporary differences recoverable in future rates charged to customers:
	 				 			
	 Capital cost allowance in excess of depreciation and amortization
	 	 	(40	) 	 	 	(38	) 
	 Overheads capitalized for accounting but deducted for tax purposes
	 	 	(12	) 	 	 	(12	) 
	 Interest capitalized for accounting but deducted for tax purposes
	 	 	(11	) 	 	 	(13	) 
	 Pension contributions in excess of pension expense
	 	 	(6	) 	 	 	(11	) 
	 Environmental expenditures
	 	 	(5	) 	 	 	(6	) 
	 Other
	 	 	(9	) 	 	 	(7	) 
	 Net temporary differences
	 	 	(83	) 	 	 	(87	) 
	 Net permanent differences
	 	 	—	 	 	 	3	 
	 Total income taxes
	 	 	115	 	 	 	73	 
			
	 Effective income tax rate
	 	 	15.4%	 	 	 	12.3%	 
	  
  

8.   ACCOUNTS RECEIVABLE

 
	 
 

    

	 	 	September 30,	 	 	December 31,	 
	  (millions of dollars)	 	2018	 	 	2017	 
	 Accounts receivable – billed
	 	 	318	 	 	 	298	 
	 Accounts receivable – unbilled
	 	 	297	 	 	 	367	 
	 Accounts receivable, gross
	 	 	615	 	 	 	665	 
	 Allowance for doubtful accounts
	 	 	(25	) 	 	 	(29	) 
	 Accounts receivable, net
	 	 	590	 	 	 	636	 

  

					
		 	8	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 The following table shows the movements in the allowance for doubtful accounts for the nine months ended
September 30, 2018 and the year ended December 31, 2017: 
  

									
	 	  	Nine months ended
September 30,	 	 	Year ended
December 31,	 
	  (millions of dollars)	  	2018	 	 	2017	 
	 Allowance for doubtful accounts – beginning
	  	 	(29	) 	 	 	(35	) 
	 Write-offs
	  	 	16	 	 	 	25	 
	 Additions to allowance for doubtful accounts
	  	 	(12	) 	 	 	(19	) 
	 Allowance for doubtful accounts – ending
	  	 	(25	) 	 	 	(29	) 
			
	 9.   OTHER CURRENT ASSETS
	  				 			
			
	 	  	September 30,	 	 	December 31,	 
	  (millions of dollars)	  	2018	 	 	2017	 
	 Regulatory assets (Note 11)
	  	 	47	 	 	 	46	 
	 Materials and supplies
	  	 	20	 	 	 	18	 
	 Prepaid expenses and other assets
	  	 	40	 	 	 	41	 
	 Derivative instrument - foreign exchange contract (Note
16)
	  	 	22	 	 	 	—	 
	 	  	 	129	 	 	 	105	 
			
	 10.  PROPERTY, PLANT AND EQUIPMENT
	  				 			
			
	 	  	September 30,	 	 	December 31,	 
	  (millions of dollars)	  	2018	 	 	2017	 
	 Property, plant and equipment
	  	 	29,683	 	 	 	29,025	 
	 Less: accumulated depreciation
	  	 	(10,791	) 	 	 	(10,455	) 
		  	 	18,892	 	 	 	18,570	 
	 Construction in progress
	  	 	1,424	 	 	 	1,215	 
	 Future use land, components and spares
	  	 	159	 	 	 	162	 
	 	  	 	20,475	 	 	 	19,947	 

  

					
		 	9	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

	11.	 REGULATORY ASSETS AND LIABILITIES 

 

									
	 	  	September 30,	 	  	December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Regulatory assets:
	  				  			
	 Deferred income tax regulatory asset
	  	 	1,872	 	  	 	1,762	 
	 Pension benefit regulatory asset
	  	 	1,001	 	  	 	981	 
	 Environmental
	  	 	184	 	  	 	196	 
	 Post-retirement and post-employment benefits
	  	 	59	 	  	 	36	 
	 Foregone revenue deferral
	  	 	56	 	  	 	23	 
	 Share-based compensation
	  	 	40	 	  	 	40	 
	 Debt premium
	  	 	23	 	  	 	27	 
	 Distribution system code exemption
	  	 	10	 	  	 	10	 
	 B2M LP start-up costs
	  	 	2	 	  	 	4	 
	 Other
	  	 	27	 	  	 	16	 
	 Total regulatory assets
	  	 	3,274	 	  	 	3,095	 
	 Less: current portion
	  	 	47	 	  	 	46	 
	 	  	 	3,227	 	  	 	3,049	 
			
	 Regulatory liabilities:
	  				  			
	 Pension cost variance
	  	 	56	 	  	 	23	 
	 Green Energy expenditure variance
	  	 	54	 	  	 	60	 
	 External revenue variance
	  	 	29	 	  	 	46	 
	 Retail settlement variance account
	  	 	20	 	  	 	—	 
	 Conservation and Demand Management deferral variance
	  	 	8	 	  	 	28	 
	 2015-2017 rate rider
	  	 	6	 	  	 	6	 
	 Deferred income tax regulatory liability
	  	 	5	 	  	 	5	 
	 Other
	  	 	17	 	  	 	17	 
	 Total regulatory liabilities
	  	 	195	 	  	 	185	 
	 Less: current portion
	  	 	21	 	  	 	57	 
	 	  	 	174	 	  	 	128	 

 Deferred Income Tax Regulatory Asset 

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. The exposure from the potential impairments would be a one-time decrease in net income and the deferred income tax regulatory assets of up to approximately $885 million. 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). 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. On December 19, 2017, the OEB granted a hearing of the merits of the Motion which was held on February 12, 2018. On August 31, 2018, the OEB
granted the Motion and returned the portion of the Decision relating to the deferred tax asset to an OEB panel for reconsideration. 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 aforementioned tax savings will be allocated to the benefit of Hydro One shareholders. 

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 are being returned to or recovered from ratepayers, respectively, over a one-year
period ending December 31, 2018. As part of its May 2018 decision, the OEB also directed B2M LP to record in this account any revenue collected in 2018 in excess of the final approved 2018 B2M LP revenue requirement. The draft rate order
submitted by Hydro One Networks relating to the transmission 

  

					
		 	10	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 rate application for 2017 and 2018 rates 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 ratepayers. Therefore, the Company has also reflected the impact of
this position in the Foregone Revenue Deferral account. As the OEB granted the Motion and returned the portion of the Decision relating to the deferred tax asset to an OEB panel for reconsideration, the timing for recovery of this impact will be
determined as part of the reconsideration by the panel. 
 Post-Retirement and Post-Employment Benefits Non-Service Cost
Regulatory Asset 
 Hydro One applied to the OEB for a regulatory asset to record the components other than service costs relating to its
post-retirement and post-employment benefits that would have previously been capitalized to property, plant and equipment and intangible assets prior to adoption of ASU 2017-07. In May 2018, the OEB approved
the regulatory asset for Hydro One Networks’ Transmission Business. It is expected that the regulatory asset application for Hydro One Networks’ Distribution business will be considered as part of Hydro One Networks’ application for
2018-2022 distribution rates, OEB approval of which is currently pending. Hydro One has recorded the components other than service costs relating to its post-retirement and post-employment benefits that would have been capitalized to property, plant
and equipment and intangible assets, in the Post-Retirement and Post-Employment Benefits Non-Service Cost Regulatory Asset. 
  

	12.	 ACCOUNTS PAYABLE AND OTHER CURRENT LIABILITIES 

 

									
			
	 	  	September 30,	 	  	December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Accounts payable
	  	 	159	 	  	 	177	 
	 Accrued liabilities
	  	 	650	 	  	 	572	 
	 Accrued interest
	  	 	130	 	  	 	99	 
	 Regulatory liabilities (Note 11)
	  	 	21	 	  	 	57	 
	 	  	 	960	 	  	 	905	 
			
	 13.  OTHER LONG-TERM LIABILITIES    
	  				  			
			
	 	  	September 30,	 	  	December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Post-retirement and post-employment benefit liability
	  	 	1,561	 	  	 	1,519	 
	 Pension benefit liability
	  	 	1,001	 	  	 	981	 
	 Environmental liabilities (Note 18)
	  	 	152	 	  	 	168	 
	 Asset retirement obligations
	  	 	9	 	  	 	9	 
	 Long-term accounts payable and other liabilities
	  	 	32	 	  	 	30	 
	 	  	 	2,755	 	  	 	2,707	 

  

	14.	 DEBT AND CREDIT AGREEMENTS 

Short-Term Notes and Operating 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 September 30, 2018, Hydro One’s consolidated committed, unsecured and undrawn credit facilities (Operating Credit Facilities) totalling
$2,550 million included Hydro One’s credit facilities of $250 million and Hydro One Inc.’s credit facilities of $2.3 billion. At September 30, 2018, no amounts have been drawn on the Operating Credit Facilities. 

Acquisition Credit Facilities 
 For the purpose of bridge
financing for the pending acquisition of Avista Corporation, the Company secured a $1.0 billion non-revolving equity bridge credit facility, and a US$2.6 billion
non-revolving debt bridge credit facility (Acquisition Credit Facilities) in June 2018. The equity bridge credit facility matures 90 days after the drawdown date and in any event not later than June 30,
2019. The debt bridge credit facility is available until March 31, 2019, and matures one year after the drawdown date. At September 30, 2018, no amounts have been drawn on the Acquisition Credit Facilities. 

Hydro One is required to make prepayments of the Acquisition Credit Facilities in an amount equal to the net cash proceeds from any common equity,
preferred equity, bond or other debt offerings, including the net proceeds from the final instalment of Convertible Debentures issued in August 2017, and any non-ordinary course asset sales by Hydro One and
its subsidiaries, subject to certain exceptions. Any prepayment under the Acquisition Credit Facilities may not be re-borrowed. The Acquisition Credit Facilities agreements contain customary representations
and warranties and affirmative and negative covenants of Hydro One that are consistent with those of Hydro One’s Operating Credit Facilities. If the Merger does not close, then these agreements will be cancelled. 

  

					
		 	11	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 Long-Term Debt 

The following table presents long-term debt outstanding at September 30, 2018 and December 31, 2017: 

 

									
			
	 	  	September 30,	 	 	December 31,	 
	  (millions of dollars)	  	2018	 	 	2017	 
	 Hydro One Inc. long-term debt (a)
	  	 	11,323	 	 	 	9,923	 
	 HOSSM long-term debt (b)
	  	 	172	 	 	 	176	 
		  	 	11,495	 	 	 	10,099	 
	 Add: Net unamortized debt premiums
	  	 	13	 	 	 	14	 
	 Add: Unrealized
mark-to-market gain1
	  	 	(11	) 	 	 	(9	) 
	 Less: Unamortized deferred debt issuance costs
	  	 	(41	) 	 	 	(37	) 
	 Total long-term debt
	  	 	11,456	 	 	 	10,067	 
			
	 Less: Long-term debt payable within one year
	  	 	(981	) 	 	 	(752	) 
	 	  	 	10,475	 	 	 	9,315	 

  

	1 	 The unrealized mark-to-market net gain
relates to $50 million of the Series 33 notes due 2020, $500 million Series 37 notes due 2019 and $300 million Series 39 notes due 2021. The unrealized
mark-to-market net gain is offset by an $11 million (December 31, 2017 - $9 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 September 30, 2018, long-term debt of $11,323 million (December 31, 2017 - $9,923 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 March 2018 is $4.0 billion. At September 30, 2018,
$2.6 billion remained available for issuance until April 2020. 
 During the nine months ended September 30, 2018, Hydro One
Inc. issued long-term debt totalling $1.4 billion (2017 - $nil) under its MTN Program as follows: 
  

	 	•	 	 $300 million notes (MTN Series 39 notes) with a maturity date of June 25, 2021 and a coupon rate of 2.57%;

	 	•	 	 $350 million notes (MTN Series 40 notes) with a maturity date of June 26, 2025 and a coupon rate of 2.97%; and

	 	•	 	 $750 million notes (MTN Series 41 notes) with a maturity date of June 25, 2049 and a coupon rate of 3.63%.

 No long-term debt was repaid during the nine months ended September 30, 2018 or 2017. 

 

	(b)	 Hydro One Sault Ste. Marie LP (HOSSM) long-term debt 

At September 30, 2018, long-term debt of $172 million (December 31, 2017 - $176 million), with a principal amount of
$145 million (December 31, 2017 - $146 million) was held by HOSSM. During the three and nine months ended September 30, 2018 and 2017, no long-term debt was issued, and $1 million (2017 - $1 million) of long-term debt was repaid, all
in the second quarter. 
 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
Principal Repayments	 	  	Weighted-average
Interest Rate	 
	  Years to Maturity	  	(millions of dollars)	 	  	(%)	 
	 1 year
	  	 	981	 	  	 	2.7	 
	 2 years
	  	 	1,153	 	  	 	2.3	 
	 3 years
	  	 	803	 	  	 	2.1	 
	 4 years
	  	 	603	 	  	 	3.2	 
	 5 years
	  	 	133	 	  	 	6.1	 
		  	 	3,673	 	  	 	2.7	 
	 6 – 10 years
	  	 	850	 	  	 	2.9	 
	 Over 10 years
	  	 	6,945	 	  	 	5.1	 
	 	  	 	11,468	 	  	 	4.1	 

  

					
		 	12	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

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

  

					
	 	  	Interest Payments	 
	  Year	  	(millions of dollars)	 
	 Remainder of 2018
	  	 	148	 
	 2019
	  	 	448	 
	 2020
	  	 	429	 
	 2021
	  	 	411	 
	 2022
	  	 	393	 
		  	 	1,829	 
	 2023-2027
	  	 	1,834	 
	 2028+
	  	 	4,666	 
	 	  	 	8,329	 

  

	15.	 CONVERTIBLE DEBENTURES 

 

									
	 	  	Nine months ended
September 30,	 	  	Year ended
December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Carrying value - beginning
	  	 	487	 	  	 	—	 
	 Receipt of Initial Instalment, net of deferred financing costs
	  	 	—	 	  	 	486	 
	 Amortization of deferred financing costs
	  	 	2	 	  	 	1	 
	 Carrying value - ending
	  	 	489	 	  	 	487	 
			
	 Face value - ending
	  	 	513	 	  	 	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 $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 during the
three and nine months ended September 30, 2018 was $15 million and $46 million (2017 - $9 million and $9 million), respectively. 

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 

  

					
		 	13	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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. 
  

	16.	 FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT 

Non-Derivative Financial Assets and Liabilities 

At September 30, 2018 and December 31, 2017, 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. 

Fair Value Measurements of Long-Term Debt 
 The fair values and
carrying values of the Company’s long-term debt at September 30, 2018 and December 31, 2017 are as follows: 
  

																	
	 	  	September 30, 2018	 	  	December 31, 2017	 
	  (millions of dollars)	  	Carrying Value	 	  	Fair Value	 	  	Carrying Value	 	  	Fair Value	 
	 Long-term debt measured at fair value:
	  				  				  				  			
	 $50 million of MTN Series 33 notes
	  	 	49	 	  	 	49	 	  	 	49	 	  	 	49	 
	 $500 million MTN Series 37 notes
	  	 	493	 	  	 	493	 	  	 	492	 	  	 	492	 
	 $300 million MTN Series 39 notes
	  	 	297	 	  	 	297	 	  	 	—	 	  	 	—	 
	 Other notes and debentures
	  	 	10,617	 	  	 	11,586	 	  	 	9,526	 	  	 	11,027	 
	 Long-term debt, including current portion
	  	 	11,456	 	  	 	12,425	 	  	 	10,067	 	  	 	11,568	 

 Fair Value Measurements of Derivative Instruments 

At September 30, 2018, Hydro One Inc. had interest-rate swaps with a total notional amount of $850 million (December 31, 2017 – $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 8% (December 31, 2017 – 6%) of its total long-term
debt. At September 30, 2018, 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; 

	•	 	 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;
and 

	•	 	 a $300 million fixed-to-floating
interest-rate swap agreement to convert the $300 million MTN Series 39 notes maturing June 25, 2021 into three-month variable rate debt. 

At September 30, 2018 and December 31, 2017, 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 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. 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 with changes in fair value being recorded in earnings as they occur. 

  

					
		 	14	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 Fair Value Hierarchy 

The fair value hierarchy of financial assets and liabilities at September 30, 2018 and December 31, 2017 is as follows: 

 

																					
	  September 30, 2018 (millions of dollars)	  	Carrying
Value	 	  	Fair
  Value	 	  	    Level 1	 	  	    Level 2	 	  	    Level 3	 
	 Assets:
	  				  				  				  				  			
	 Cash and cash equivalents
	  	 	613	 	  	 	613	 	  	 	613	 	  	 	—	 	  	 	—	 
	 Derivative instrument
	  				  				  				  				  			
	 Foreign exchange contract
	  	 	22	 	  	 	22	 	  	 	—	 	  	 	—	 	  	 	22	 
	 	  	 	635	 	  	 	635	 	  	 	613	 	  	 	—	 	  	 	22	 
						
	 Liabilities:
	  				  				  				  				  			
	 Short-term notes payable
	  	 	444	 	  	 	444	 	  	 	444	 	  	 	—	 	  	 	—	 
	 Long-term debt, including current portion
	  	 	11,456	 	  	 	12,425	 	  	 	—	 	  	 	12,425	 	  	 	—	 
	 Convertible debentures
	  	 	489	 	  	 	398	 	  	 	398	 	  	 	—	 	  	 	—	 
	 Derivative instruments
	  				  				  				  				  			
	 Fair value hedges – interest-rate swaps
	  	 	11	 	  	 	11	 	  	 	—	 	  	 	11	 	  	 	—	 
	 	  	 	12,400	 	  	 	13,278	 	  	 	842	 	  	 	12,436	 	  	 	—	 
						
	  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	 	  	 	1,500	 	  	 	11,577	 	  	 	3	 

 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
September 28, 2018 (last business day in September 2018), 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 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 probability of
closing the Avista Corporation acquisition and the contract settlement date. 

  

					
		 	15	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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 nine months ended September 30,
2018 and the year ended December 31, 2017: 
  

									
	  (millions of dollars)	 	Nine months ended
September 30,
2018	 	 	Year ended
December 31,
2017	 
	 Fair value of asset (liability) - beginning
	 	 	(3	) 	 	 	—	 
	 Unrealized gain (loss) on foreign exchange contract included in financing charges
	 	 	25	 	 	 	(3	) 
	 Fair value of asset (liability) -
ending
	 	 	22	 	 	 	(3	) 

 There were no transfers between any of the fair value levels during the nine months ended September 30, 2018 and the
year ended December 31, 2017. 
 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 three and nine months ended September 30, 2018 and 2017. 
 The Company is exposed to foreign exchange fluctuations
as a result of entering into a deal-contingent foreign exchange forward agreement. 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. 
 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 three and nine months ended September 30, 2018 and 2017 was not material. 
 Credit Risk 

Financial assets create a risk that a counterparty will fail to discharge an obligation, causing a financial loss. At September 30, 2018 and
December 31, 2017, 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 September 30, 2018 and December 31, 2017, there was no material accounts receivable balance due from any single customer. 

At September 30, 2018, the Company’s allowance for doubtful accounts was $25 million (December 31, 2017 – $29 million). Adjustments
and write-offs are determined on the basis of a review of overdue accounts, taking into consideration historical experience. At September 30, 2018, approximately 6% (December 31, 2017 – 5%) of the Company’s net accounts receivable
were outstanding for more than 60 days. 
 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 September 30, 2018 and December 31, 2017, the counterparty credit risk exposure on the fair value of these interest-rate swap
contracts was not material. At September 30, 2018, 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. 

  

					
		 	16	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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 operating liquidity
requirements using cash and cash equivalents on hand, funds from operations, the issuance of commercial paper, and the Operating Credit Facilities. The short-term liquidity under the Commercial Paper Program, Operating Credit Facilities, and
anticipated levels of funds from operations are expected to be sufficient to fund normal operating requirements. 
 On June 18, 2018, Hydro One
filed a short form base shelf prospectus (Universal Base Shelf Prospectus) with securities regulatory authorities in Canada to replace the universal base shelf prospectus that expired on April 30, 2018. The Universal Base Shelf Prospectus
allows Hydro One to offer, from time to time in one or more public offerings, up to $4.0 billion of debt, equity or other securities, or any combination thereof, during the 25-month period ending on
July 18, 2020. 
  

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

Estimated annual defined benefit pension plan contributions for 2018, 2019 and 2020 are approximately $50 million, $70 million, and
$70 million, respectively, based on an actuarial valuation as at December 31, 2017 and projected levels of pensionable earnings. Employer contributions made during the nine months ended September 30, 2018 were $37 million (2017
– $67 million). 
 The following tables provide the components of the net periodic benefit costs for the three and nine months ended
September 30, 2018 and 2017: 
  

																	
	 	  	 	 	 	 	 	 	Post-Retirement and	 
	 	  	 Pension Benefits
  
	 	 	 Post-Employment Benefits

 
	 
	  Three months ended September 30 (millions of dollars)	  	2018	 	 	2017	 	 	2018	 	  	2017	 
	 Current service cost
	  	 	44	 	 	 	36	 	 	 	12	 	  	 	12	 
	 Interest cost
	  	 	71	 	 	 	76	 	 	 	14	 	  	 	17	 
	 Expected return on plan assets, net of
expenses1
	  	 	(117	) 	 	 	(110	) 	 	 	—	 	  	 	—	 
	 Amortization of actuarial losses
	  	 	21	 	 	 	20	 	 	 	1	 	  	 	2	 
	 Net periodic benefit
costs
	  	 	19	 	 	 	22	 	 	 	27	 	  	 	31	 
					
	 Charged to results of operations2
	  	 	6	 	 	 	10	 	 	 	12	 	  	 	14	 
				
	 	  	 	 	 	 	 	 	Post-Retirement and	 
	 	  	 Pension Benefits
  
	 	 	 Post-Employment Benefits

 
	 
	  Nine months ended September 30 (millions of dollars)	  	2018	 	 	2017	 	 	2018	 	  	2017	 
	 Current service cost
	  	 	132	 	 	 	109	 	 	 	36	 	  	 	36	 
	 Interest cost
	  	 	212	 	 	 	228	 	 	 	42	 	  	 	51	 
	 Expected return on plan assets, net of
expenses1
	  	 	(350	) 	 	 	(331	) 	 	 	—	 	  	 	—	 
	 Amortization of actuarial losses
	  	 	63	 	 	 	60	 	 	 	2	 	  	 	6	 
	 Net periodic benefit
costs
	  	 	57	 	 	 	66	 	 	 	80	 	  	 	93	 
					
	 Charged to results of operations2
	  	 	17	 	 	 	31	 	 	 	33	 	  	 	41	 

  

	1 	 The expected long-term rate of return on pension plan assets for the year ending December 31, 2018 is 6.5% (2017 -
6.5%). 

  

	2 	 The Company accounts for pension costs consistent with their inclusion in
OEB-approved rates. During the three and nine months ended September 30, 2018, pension costs of $14 million (2017 - $22 million) and $39 million (2017 - $68 million), respectively, were
attributed to labour, of which $6 million (2017 - $10 million) and $17 million (2017 - $31 million), respectively, were charged to operations, and $8 million (2017 - $12 million) and $22 million (2017 - $37 million) respectively,
were capitalized as part of the cost of property, plant and equipment and intangible assets. 

  

	18.	 ENVIRONMENTAL LIABILITIES 

The following table shows the movements in environmental liabilities for the nine months ended September 30, 2018 and the year ended
December 31, 2017: 
  

									
	  (millions of dollars)	  	Nine months ended
September 30,
2018	 	 	Year ended
December 31,
2017	 
	 Environmental liabilities – beginning
	  	 	196	 	 	 	204	 
	 Interest accretion
	  	 	5	 	 	 	8	 
	 Expenditures
	  	 	(17	) 	 	 	(24	) 
	 Revaluation adjustment
	  	 	—	 	 	 	8	 
	 Environmental liabilities – ending
	  	 	184	 	 	 	196	 
	 Less: current portion
	  	 	(32	) 	 	 	(28	) 
	 	  	 	152	 	 	 	168	 

  

					
		 	17	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

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

									
	  (millions of dollars)	 	September 30,
2018	 	 	December 31,
2017	 
	 Undiscounted environmental liabilities
	 	 	188	 	 	 	206	 
	 Less: discounting environmental liabilities to present value
	 	 	(4	) 	 	 	(10	) 
	 Discounted environmental
liabilities
	 	 	184	 	 	 	196	 

 At September 30, 2018, the estimated future environmental expenditures were as follows: 

 

					
	  (millions of dollars)	  	  	 
	 Remainder of 2018
	  	 	8	 
	 2019
	  	 	29	 
	 2020
	  	 	32	 
	 2021
	  	 	34	 
	 2022
	  	 	31	 
	 Thereafter
	  	 	54	 
	 	  	 	188	 

  

	19.	 SHARE CAPITAL 

Common Shares 
 The Company is authorized to issue an unlimited
number of common shares. At September 30, 2018, the Company had 595,882,438 common shares issued and outstanding (December 31, 2017 - 595,386,711). 

The following table presents the changes to common shares during the nine months ended September 30, 2018. 

 

					
	  (number of shares)	  	  	 
	 Common shares – December 31, 2017
	  	 	595,386,711	 
	 Common shares issued – share grants1
	  	 	481,227	 
	 Common shares issued – share grants2
	  	 	119	 
	 Common shares issued – LTIP3
	  	 	14,381	 
	 Common shares – September 30, 2018
	  	 	595,882,438	 

  

	1 	 On April 1, 2018, Hydro One issued from treasury 481,227 common shares in accordance with provisions of the Power
Workers’ Union (PWU) and the Society of United Professionals (Society) Share Grant Plans. 

	2 	 On May 14, 2018, Hydro One issued from treasury 119 common shares in accordance with provisions of the PWU Share
Grant Plan. 

	3 	 On May 31, 2018, Hydro One issued from treasury 14,381 common shares in accordance with provisions of the LTIP.

 Preferred Shares 
 The Company is
authorized to issue an unlimited number of preferred shares, issuable in series. At September 30, 2018 and December 31, 2017, two series of preferred shares are authorized for issuance: the Series 1 preferred shares and the Series 2
preferred shares. At September 30, 2018 and December 31, 2017, the Company had 16,720,000 Series 1 preferred shares and no Series 2 preferred shares issued and outstanding. 

 

	20.	 DIVIDENDS 

During the three months ended September 30, 2018, preferred share dividends in the amount of $4 million (2017 - $4 million) and common share
dividends in the amount of $137 million (2017 - $131 million) were declared and paid. 
 During the nine months ended September 30, 2018,
preferred share dividends in the amount of $13 million (2017 - $13 million) and common share dividends in the amount of $405 million (2017 - $387 million) were declared and paid. 

 

	21.	 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. 

  

					
		 	18	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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 Long-term Incentive Plan (LTIP), which are calculated using the treasury
stock method. 
  

																	
	 	 	 Three months ended September 30

 
	 	 	 Nine months ended September 30

 
	 
	  	 	2018	 	 	2017	 	 	2018	 	 	2017	 
					
	 Net income attributable to common shareholders (millions of dollars)
	 	 	194	 	 	 	219	 	 	 	616	 	 	 	503	 
					
	 Weighted-average number of shares
	 				 				 				 			
	 Basic
	 	 	595,882,438	 	 	 	595,386,308	 	 	 	595,714,016	 	 	 	595,254,201	 
	 Effect of dilutive stock-based compensation plans
	 	 	1,968,856	 	 	 	2,130,453	 	 	 	2,128,211	 	 	 	2,172,635	 
	 Diluted
	 	 	597,851,294	 	 	 	597,516,761	 	 	 	597,842,227	 	 	 	597,426,836	 
					
	 EPS
	 				 				 				 			
	 Basic
	 	 	$0.33	 	 	 	$0.37	 	 	 	$1.03	 	 	 	$0.85	 
	 Diluted
	 	 	$0.32	 	 	 	$0.37	 	 	 	$1.03	 	 	 	$0.84	 

 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 (see Note 4 - Business Combinations for details of the acquisition). 
  

	22.	 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 Power Workers’ Union (the PWU Share Grant Plan) and one for the benefit of certain members of The Society of United Professionals (formerly The Society of Energy Professionals) (the
Society Share Grant Plan). A summary of share grant activity under the Share Grant Plans during the three and nine months ended September 30, 2018 and 2017 is presented below: 

 

																	
	 	  	Three months ended	 	  	Nine months ended	 
	 	  	 	 	  	 September 30
  
	 	  	 	 	 	 September 30
  
	 
	  (number of share grants)	  	2018	 	  	2017	 	  	2018	 	 	2017	 
	 Share grants outstanding – beginning
	  	 	4,344,386	 	  	 	4,962,804	 	  	 	4,825,732	 	 	 	5,334,415	 
	 Vested and
issued1,2
	  	 	—	 	  	 	—	 	  	 	(481,346	) 	 	 	(371,611	) 
	 Share grants outstanding – ending
	  	 	4,344,386	 	  	 	4,962,804	 	  	 	4,344,386	 	 	 	4,962,804	 

	1 	 On April 1, 2018, Hydro One issued from treasury 481,227 common shares to eligible employees in accordance with
provisions of the PWU and the Society Share Grant Plans. 

	2 	 On May 14, 2018, Hydro One issued from treasury 119 common shares to an eligible employee in accordance with
provisions of the PWU Share Grant Plan. 

 Directors’ Deferred Share Unit (DSU) Plan 

A summary of DSUs activity under the Directors’ DSU Plan during the three and nine months ended September 30, 2018 and 2017 is presented below:

  

																	
	 	  	Three months ended	 	  	Nine months ended	 
	 	  	 	 	  	 September 30
  
	 	  	 	 	  	 September 30
  
	 
	  (number of DSUs)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 DSUs outstanding - beginning
	  	 	243,660	 	  	 	141,553	 	  	 	187,090	 	  	 	99,083	 
	 Granted
	  	 	10,764	 	  	 	22,504	 	  	 	67,334	 	  	 	64,974	 
	 DSUs outstanding - ending
	  	 	254,424	 	  	 	164,057	 	  	 	254,424	 	  	 	164,057	 

 At September 30, 2018, a liability of $5 million (December 31, 2017 - $4 million) related to previously awarded
Directors’ DSUs to the Company’s former Board of Directors (Board) has been recorded at the June 29, 2018 (last business day in June 2018) closing price of the Company’s common shares of $20.04 (December 31, 2017 - $22.40) and is
included in accounts payable and other current liabilities (December 31, 2017 - included in long-term accounts payable and other liabilities) on the Consolidated Balance Sheets. 

The liability related to the Company’s new Board is not significant and has been recorded at the September 28, 2018 (last business day in
September 2018) closing price of the Company’s common shares of $19.64. This liability is included in long-term accounts payable and other liabilities on the Consolidated Balance Sheets. 

  

					
		 	19	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 Management DSU Plan 

A summary of DSUs activity under the Management DSU Plan during the three and nine months ended September 30, 2018 and 2017 is presented below: 

 

																	
	 	  	Three months ended	 	  	Nine months ended	 
	 	  	 	 	  	 September 30
  
	 	  	 	 	  	 September 30
  
	 
	  (number of DSUs)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 DSUs outstanding - beginning
	  	 	105,870	 	  	 	67,583	 	  	 	67,829	 	  	 	—	 
	 Granted
	  	 	1,242	 	  	 	657	 	  	 	39,283	 	  	 	68,240	 
	 DSUs outstanding - ending
	  	 	107,112	 	  	 	68,240	 	  	 	107,112	 	  	 	68,240	 

 At September 30, 2018, a liability of $1 million (December 31, 2017 - $1 million) related to previously awarded
Management DSUs to the Company’s former President and Chief Executive Officer (CEO) has been recorded at the June 29, 2018 (last business day in June 2018) closing price of the Company’s common shares of $20.04 (December 31, 2017 -
$22.40) and is included in accounts payable and other current liabilities (December 31, 2017 - included in long-term accounts payable and other liabilities) on the Consolidated Balance Sheets. 

A liability of $1 million (December 31, 2017 - not significant) related to other Management DSUs has been recorded at the September 28, 2018
(last business day in September 2018) closing price of the Company’s common shares of $19.64 (December 31, 2017—$22.40) and is included in long-term accounts payable and other liabilities on the Consolidated Balance Sheets. 

LTIP 
 Performance Share Units (PSU) and Restricted Share
Units (RSU) 
 A summary of PSU and RSU awards activity under the LTIP during the three and nine months ended September 30, 2018 and 2017 is
presented below: 
  

																	
	 	  	 PSUs
  
	 	 	 RSUs
  
	 
	  Three months ended September 30 (number of units)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Units outstanding - beginning
	  	 	846,520	 	 	 	443,095	 	 	 	700,070	 	 	 	409,645	 
	 Granted
	  	 	4,320	 	 	 	35,790	 	 	 	3,160	 	 	 	21,040	 
	 Vested
	  	 	—	 	 	 	(609	) 	 	 	—	 	 	 	(609	) 
	 Forfeited
	  	 	(1,630	) 	 	 	(9,036	) 	 	 	(5,160	) 	 	 	(7,676	) 
	 Settled
	  	 	(238,030	) 	 	 	—	 	 	 	(158,310	) 	 	 	—	 
	 Units outstanding -
ending
	  	 	611,180	 	 	 	469,240	 	 	 	539,760	 	 	 	422,400	 

  

																	
	 	  	 PSUs
  
	 	 	 RSUs
  
	 
	  Nine months ended September 30 (number of units)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Units outstanding - beginning
	  	 	429,980	 	 	 	230,600	 	 	 	393,430	 	 	 	254,150	 
	 Granted
	  	 	445,120	 	 	 	303,240	 	 	 	345,790	 	 	 	239,990	 
	 Vested
	  	 	—	 	 	 	(609	) 	 	 	(13,470	) 	 	 	(14,079	) 
	 Forfeited
	  	 	(25,890	) 	 	 	(63,991	) 	 	 	(27,680	) 	 	 	(57,661	) 
	 Settled
	  	 	(238,030	) 	 	 	—	 	 	 	(158,310	) 	 	 	—	 
	 Units outstanding -
ending
	  	 	611,180	 	 	 	469,240	 	 	 	539,760	 	 	 	422,400	 

 The grant date total fair value of the awards granted during the three and nine months ended September 30, 2018 was
$nil and $16 million (2017 - $1 million and $13 million), respectively. The compensation expense related to these awards recognized by the Company during the three and nine months ended September 30, 2018 was $7 million and
$12 million (2017 - $2 million and $5 million), respectively. The expense recognized in the third quarter of 2018 included $5 million related to previously awarded PSUs and RSUs to the Company’s former President and CEO for which
costs had not previously been recognized. These awards, consisting of 238,030 PSUs and 158,310 RSUs, were settled in the third quarter of 2018 through a one-time cash settlement arrangement. 

Stock Options 
 The Company is authorized to
grant stock options under its LTIP to certain eligible employees. During the nine months ended September 30, 2018, the Company granted 1,450,880 stock options (2017 - nil), all in the first quarter of 2018. The stock options granted are
exercisable for a period not to exceed seven years from the date of grant and vest evenly over a three-year period on each anniversary of the date of grant. 

The fair value based method is used to measure compensation expense related to stock options and the expense is recognized over the vesting period on a
straight-line basis. The fair value of the stock option awards granted was estimated on the date of grant using a Black-Scholes valuation model. 

  

					
		 	20	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 Stock options granted and the weighted-average assumptions used in the valuation model for options
granted during the nine months ended September 30, 2018 are as follows: 
  

					
	 Exercise price1

	  	$	20.70	 
	 Grant date fair value per option
	  	$	1.66	 
	 Valuation assumptions:
	  			
	 Expected dividend yield2 
	  	 	3.78	% 
	 Expected volatility3 
	  	 	15.01	% 
	 Risk-free interest rate4 
	  	 	2.00	% 
	 Expected option term5 
	  	 	4.5 years	 

  

	1 	 Hydro One common share price on the date of the grant. 

	2 	 Based on dividend and Hydro One common share price on the date of the grant. 

	3 	 Based on average daily volatility of peer entities for a 4.5-year term.

	4 	 Based on bond yield for an equivalent Canadian government bond. 

	5 	 Determined using the option term and the vesting period. 

A summary of stock options activity during the three and nine months ended September 30, 2018 and 2017 is presented below: 

 

																	
	 	  	 Three months ended

September 30
	 	  	 Nine months ended

September 30
	 
	  (number of stock options)	  	2018	 	 	2017	 	  	2018	 	 	2017	 
	 Stock options outstanding - beginning
	  	 	1,450,880	 	 	 	—	 	  	 	—	 	 	 	—	 
	 Granted1 
	  	 	—	 	 	 	—	 	  	 	1,450,880	 	 	 	—	 
	 Cancelled2 
	  	 	(500,970	) 	 	 	—	 	  	 	(500,970	) 	 	 	—	 
	 Stock options outstanding - ending1 
	  	 	949,910	 	 	 	—	 	  	 	949,910	 	 	 	—	 

  

	1 	 All stock options granted and outstanding at September 30, 2018 are
non-vested. 

  

	2 	 During the three months ended June 30, 2018, 500,970 stock options previously awarded to the Company’s former
President and CEO were cancelled. The unrecognized compensation expense related to the cancelled stock options was $1 million. 

The compensation expense related to stock options recognized by the Company during the three and nine months ended September 30, 2018 was not
significant. At September 30, 2018, there was $1 million of unrecognized compensation expense related to stock options not yet vested, which is expected to be recognized over a weighted-average period of approximately three years. 

 

	23.	 RELATED PARTY TRANSACTIONS 

The Province is a shareholder of Hydro One with approximately 47.4% ownership at September 30, 2018. 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. 
  

																			
	 	  	 	 	Three months ended	 	 	Nine months ended	 
	
   (millions of dollars)

 
	  	 	 	 	 	 	 September 30
  
	 	 	 	 	 	 September 30
  
	 
	Related Party	  	Transaction	 	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Province
	  	Dividends paid	 	 	69	 	 	 	69	 	 	 	205	 	 	 	231	 
	 IESO
	  	Power purchased	 	 	321	 	 	 	276	 	 	 	1,079	 	 	 	1,169	 
		  	Revenues for transmission services	 	 	474	 	 	 	390	 	 	 	1,293	 	 	 	1,124	 
		  	Amounts related to electricity rebates	 	 	113	 	 	 	181	 	 	 	353	 	 	 	321	 
		  	Distribution revenues related to rural rate protection	 	 	59	 	 	 	61	 	 	 	177	 	 	 	185	 
		  	Distribution revenues related to the supply of electricity to remote northern communities	 	 	8	 	 	 	8	 	 	 	24	 	 	 	24	 
	 	  	Funding received related to Conservation and Demand Management programs	 	 	11	 	 	 	18	 	 	 	33	 	 	 	44	 
	 OPG
	  	Power purchased	 	 	2	 	 	 	2	 	 	 	8	 	 	 	7	 
		  	Revenues related to provision of construction and equipment maintenance services	 	 	2	 	 	 	2	 	 	 	6	 	 	 	6	 
	 	  	Costs related to the purchase of services	 	 	—	 	 	 	—	 	 	 	—	 	 	 	1	 
	 OEFC
	  	Power purchased from power contracts administered by the OEFC	 	 	1	 	 	 	—	 	 	 	2	 	 	 	1	 
	 OEB
	  	OEB fees	 	 	2	 	 	 	2	 	 	 	6	 	 	 	6	 

 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. 

  

					
		 	21	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

	24.	 CONSOLIDATED STATEMENTS OF CASH FLOWS 

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

 

																	
	 	 	Three months ended	 	 	Nine months ended	 
	 	 	 	 	 	September 30	 	 	 	 	 	September 30	 
	  (millions of dollars)	 	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Accounts receivable
	 	 	(7	) 	 	 	50	 	 	 	46	 	 	 	241	 
	 Due from related parties
	 	 	27	 	 	 	(38	) 	 	 	(57	) 	 	 	(136	) 
	 Materials and supplies
	 	 	—	 	 	 	—	 	 	 	(2	) 	 	 	—	 
	 Prepaid expenses and other assets
	 	 	5	 	 	 	9	 	 	 	2	 	 	 	6	 
	 Accounts payable
	 	 	22	 	 	 	(10	) 	 	 	(14	) 	 	 	(9	) 
	 Accrued liabilities
	 	 	3	 	 	 	(16	) 	 	 	78	 	 	 	(57	) 
	 Due to related parties
	 	 	1	 	 	 	2	 	 	 	(151	) 	 	 	(141	) 
	 Accrued interest
	 	 	32	 	 	 	37	 	 	 	31	 	 	 	35	 
	 Long-term accounts payable and other liabilities
	 	 	(5	) 	 	 	(3	) 	 	 	(6	) 	 	 	(1	) 
	 Post-retirement and post-employment benefit liability
	 	 	7	 	 	 	21	 	 	 	19	 	 	 	61	 
	 	 	 	85	 	 	 	52	 	 	 	(54	) 	 	 	(1	) 

 Capital Expenditures 
 The
following tables reconcile investments in property, plant and equipment and intangible assets and the amounts presented in the Consolidated Statements of Cash Flows for the three and nine months ended September 30, 2018 and 2017. The
reconciling items include net change in accruals and capitalized depreciation. 
  

																									
	 	  	 Three months ended September 30, 2018

 
	 	 	 Nine months ended September 30, 2018

 
	 
	 	  	Property,	 	 	 	 	 	 	 	 	Property,	 	 	 	 	 	 	 
	 	  	Plant and	 	 	Intangible	 	 	 	 	 	Plant and	 	 	Intangible	 	 	 	 
	  (millions of dollars)	  	Equipment	 	 	Assets	 	 	Total	 	 	Equipment	 	 	Assets	 	 	Total	 
	 Capital investments
	  	 	(374	) 	 	 	(28	) 	 	 	(402	) 	 	 	(1,047	) 	 	 	(61	) 	 	 	(1,108	) 
	 Reconciling items
	  	 	4	 	 	 	3	 	 	 	7	 	 	 	25	 	 	 	—	 	 	 	25	 
	 Cash outflow for capital expenditures
	  	 	(370	) 	 	 	(25	) 	 	 	(395	) 	 	 	(1,022	) 	 	 	(61	) 	 	 	(1,083	) 
			
	 	  	 Three months ended September 30, 2017

 
	 	 	 Nine months ended September 30, 2017

 
	 
	 	  	Property,	 	 	 	 	 	 	 	 	Property,	 	 	 	 	 	 	 
	 	  	Plant and	 	 	Intangible	 	 	 	 	 	Plant and	 	 	Intangible	 	 	 	 
	  (millions of dollars)	  	Equipment	 	 	Assets	 	 	Total	 	 	Equipment	 	 	Assets	 	 	Total	 
	 Capital investments
	  	 	(359	) 	 	 	(21	) 	 	 	(380	) 	 	 	(1,087	) 	 	 	(49	) 	 	 	(1,136	) 
	 Reconciling items
	  	 	1	 	 	 	(3	) 	 	 	(2	) 	 	 	16	 	 	 	(8	) 	 	 	8	 
	 Cash outflow for capital expenditures
	  	 	(358	) 	 	 	(24	) 	 	 	(382	) 	 	 	(1,071	) 	 	 	(57	) 	 	 	(1,128	) 

 Supplementary Information 
  

																	
	 	  	Three months ended	 	  	Nine months ended	 
	 	  	 	 	  	September 30	 	  	 	 	  	September 30	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Net interest paid
	  	 	106	 	  	 	89	 	  	 	356	 	  	 	308	 
	 Income taxes paid
	  	 	1	 	  	 	3	 	  	 	13	 	  	 	11	 

  

	25.	 CONTINGENCIES 

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 Inc., 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. The appeal was heard on October 16, 2018, and it is likely that the court
will render its decision before the end of 2018. 
 To date, four putative class action lawsuits were 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 

  

					
		 	22	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 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. 
  

	26.	 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: 
  

																									
	  September 30, 2018 (millions of dollars) 	  	Year 1	 	  	Year 2	 	  	Year 3	 	  	Year 4	 	  	Year 5	 	  	Thereafter	 
	 Outsourcing agreements
	  	 	124	 	  	 	99	 	  	 	39	 	  	 	3	 	  	 	2	 	  	 	4	 
	 Long-term software/meter agreement
	  	 	14	 	  	 	17	 	  	 	6	 	  	 	1	 	  	 	2	 	  	 	1	 
	 Operating lease commitments
	  	 	9	 	  	 	10	 	  	 	6	 	  	 	2	 	  	 	1	 	  	 	3	 
	
	 The following table presents a summary of Hydro One’s other commercial commitments by year of expiry in the next 5
years and thereafter:
  
	  
 

	  September 30, 2018 (millions of dollars) 	  	Year 1	 	  	Year 2	 	  	Year 3	 	  	Year 4	 	  	Year 5	 	  	Thereafter	 
	 Operating Credit Facilities1 
	  	 	—	 	  	 	—	 	  	 	—	 	  	 	2,550	 	  	 	—	 	  	 	—	 
	 Letters of credit2 
	  	 	162	 	  	 	5	 	  	 	—	 	  	 	—	 	  	 	—	 	  	 	—	 
	 Guarantees3

	  	 	325	 	  	 	—	 	  	 	—	 	  	 	—	 	  	 	—	 	  	 	—	 

  

	1 	 For repayment and expiry details of the Acquisition Credit Facilities, please see Note 14 - Debt and Credit Agreements.

  

	2 	 Letters of credit consist of a $154 million letter of credit related to retirement compensation arrangements, a
$7 million letter of credit provided to the IESO for prudential support, $5 million in letters of credit to satisfy debt service reserve requirements, and $1 million in letters of credit for various operating purposes.

  

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

 27. 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). 
  

																	
	  Three months ended September 30, 2018 (millions of dollars) 	  	Transmission	 	  	Distribution	 	  	Other	 	 	Consolidated	 
	 Revenues
	  	 	493	 	  	 	1,103	 	  	 	10	 	 	 	1,606	 
	 Purchased power
	  	 	—	 	  	 	733	 	  	 	—	 	 	 	733	 
	 Operation, maintenance and administration
	  	 	95	 	  	 	150	 	  	 	26	 	 	 	271	 
	 Depreciation and amortization
	  	 	111	 	  	 	100	 	  	 	2	 	 	 	213	 
	 Income (loss) before financing charges and income
taxes
	  	 	287	 	  	 	120	 	  	 	(18	) 	 	 	389	 
					
	 Capital investments
	  	 	261	 	  	 	138	 	  	 	3	 	 	 	402	 

  

					
		 	23	 	

 HYDRO ONE LIMITED 

NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS (unaudited) (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

																	
	  Three months ended September 30, 2017 (millions of dollars) 	  	Transmission	 	  	Distribution	 	  	Other	 	 	Consolidated	 
	 Revenues
	  	 	471	 	  	 	1,040	 	  	 	11	 	 	 	1,522	 
	 Purchased power
	  	 	—	 	  	 	675	 	  	 	—	 	 	 	675	 
	 Operation, maintenance and administration
	  	 	95	 	  	 	149	 	  	 	33	 	 	 	277	 
	 Depreciation and amortization
	  	 	105	 	  	 	102	 	  	 	2	 	 	 	209	 
	 Income (loss) before financing charges and income taxes
	  	 	271	 	  	 	114	 	  	 	(24	) 	 	 	361	 
					
	 Capital investments
	  	 	240	 	  	 	138	 	  	 	2	 	 	 	380	 
					
	  Nine months ended September 30, 2018 (millions of dollars) 	  	Transmission	 	  	Distribution	 	  	Other	 	 	Consolidated	 
	 Revenues
	  	 	1,344	 	  	 	3,284	 	  	 	31	 	 	 	4,659	 
	 Purchased power
	  	 	—	 	  	 	2,158	 	  	 	—	 	 	 	2,158	 
	 Operation, maintenance and administration
	  	 	295	 	  	 	435	 	  	 	67	 	 	 	797	 
	 Depreciation and amortization
	  	 	321	 	  	 	294	 	  	 	5	 	 	 	620	 
	 Income (loss) before financing charges and income taxes
	  	 	728	 	  	 	397	 	  	 	(41	) 	 	 	1,084	 
					
	 Capital investments
	  	 	693	 	  	 	409	 	  	 	6	 	 	 	1,108	 
					
	  Nine months ended September 30, 2017 (millions of dollars) 	  	Transmission	 	  	Distribution	 	  	Other	 	 	Consolidated	 
	 Revenues
	  	 	1,199	 	  	 	3,317	 	  	 	35	 	 	 	4,551	 
	 Purchased power
	  	 	—	 	  	 	2,213	 	  	 	—	 	 	 	2,213	 
	 Operation, maintenance and administration
	  	 	296	 	  	 	447	 	  	 	79	 	 	 	822	 
	 Depreciation and amortization
	  	 	309	 	  	 	288	 	  	 	6	 	 	 	603	 
	 Income (loss) before financing charges and income taxes
	  	 	594	 	  	 	369	 	  	 	(50	) 	 	 	913	 
					
	 Capital investments
	  	 	701	 	  	 	427	 	  	 	8	 	 	 	1,136	 

 Total Assets by Segment: 
  

									
	 	  	September 30,	 	  	December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Transmission
	  	 	14,013	 	  	 	13,608	 
	 Distribution
	  	 	9,426	 	  	 	9,259	 
	 Other
	  	 	3,398	 	  	 	2,834	 
	 Total assets
	  	 	26,837	 	  	 	25,701	 

 Total Goodwill by Segment:

  

									
	 	  	September 30,	 	  	December 31,	 
	  (millions of dollars)	  	2018	 	  	2017	 
	 Transmission
	  	 	157	 	  	 	157	 
	 Distribution
	  	 	168	 	  	 	168	 
	 Total goodwill
	  	 	325	 	  	 	325	 

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

 

	28.	 SUBSEQUENT EVENTS 

Dividends 
 On November 7, 2018, preferred share dividends
in the amount of $5 million and common share dividends in the amount of $137 million ($0.23 per common share) were declared. 
 Repayment of Long-term Debt

 On October 9, 2018, Hydro One Inc. repaid $750 million of maturing long-term debt notes (MTN Series 28 notes) under its MTN Program.

 Directors’ DSUs 
 In October 2018, $4 million
related to previously awarded Directors’ DSUs to the Company’s former Board was paid. 
  

  

					
		 	24EX-4.5

 Exhibit 4.5 

HYDRO ONE LIMITED 
 MANAGEMENT’S DISCUSSION AND ANALYSIS 

For the three and nine months ended September 30, 2018 and 2017 

The following Management’s Discussion and Analysis (MD&A) of the financial condition and results of operations should be read together with the
condensed interim unaudited consolidated financial statements and accompanying notes thereto (Consolidated Financial Statements) of Hydro One Limited (Hydro One or the Company) for the three and nine months ended September 30, 2018, as well as
the Company’s audited consolidated financial statements and MD&A for the year ended December 31, 2017. The Consolidated Financial Statements are presented in Canadian dollars and have been prepared in accordance with United States (US)
Generally Accepted Accounting Principles (GAAP). All financial information in this MD&A is presented in Canadian dollars, unless otherwise indicated. 

The Company has prepared this MD&A in accordance with National Instrument 51-102 – Continuous Disclosure
Obligations of the Canadian Securities Administrators. This MD&A provides information for the three and nine months ended September 30, 2018, based on information available to management as of November 7, 2018. 

CONSOLIDATED FINANCIAL HIGHLIGHTS AND STATISTICS 
  

																									
	 	  	 Three months ended September 30

 
	 	 	 Nine months ended September 30

 
	 
	  (millions of dollars, except as otherwise noted)	  	2018	 	  	2017	 	  	Change	 	 	2018	 	  	2017	 	 	Change	 
	 Revenues
	  	 	1,606	 	  	 	1,522	 	  	 	5.5	% 	 	 	4,659	 	  	 	4,551	 	 	 	2.4	% 
	 Purchased power
	  	 	733	 	  	 	675	 	  	 	8.6	% 	 	 	2,158	 	  	 	2,213	 	 	 	(2.5	%) 
	 Revenues, net of purchased power1 
	  	 	873	 	  	 	847	 	  	 	3.1	% 	 	 	2,501	 	  	 	2,338	 	 	 	7.0	% 
	 Operation, maintenance and administration costs (OM&A)
	  	 	271	 	  	 	277	 	  	 	(2.2	%) 	 	 	797	 	  	 	822	 	 	 	(3.0	%) 
	 Depreciation and amortization
	  	 	213	 	  	 	209	 	  	 	1.9	% 	 	 	620	 	  	 	603	 	 	 	2.8	% 
	 Financing charges
	  	 	149	 	  	 	114	 	  	 	30.7	% 	 	 	336	 	  	 	320	 	 	 	5.0	% 
	 Income tax expense
	  	 	41	 	  	 	23	 	  	 	78.3	% 	 	 	115	 	  	 	73	 	 	 	57.5	% 
	 Net income attributable to common shareholders of Hydro One
	  	 	194	 	  	 	219	 	  	 	(11.4	%) 	 	 	616	 	  	 	503	 	 	 	22.5	% 
							
	 Basic earnings per common share (EPS)
	  	 	$0.33	 	  	 	$0.37	 	  	 	(10.8	%) 	 	 	$1.03	 	  	 	$0.85	 	 	 	21.2	% 
	 Diluted EPS
	  	 	$0.32	 	  	 	$0.37	 	  	 	(13.5	%) 	 	 	$1.03	 	  	 	$0.84	 	 	 	22.6	% 
	 Basic adjusted non-GAAP EPS (Adjusted EPS)1 
	  	 	$0.38	 	  	 	$0.40	 	  	 	(5.0	%) 	 	 	$1.06	 	  	 	$0.88	 	 	 	20.5	% 
	 Diluted Adjusted EPS1 
	  	 	$0.38	 	  	 	$0.40	 	  	 	(5.0	%) 	 	 	$1.06	 	  	 	$0.88	 	 	 	20.5	% 
							
	 Net cash from operating activities
	  	 	508	 	  	 	442	 	  	 	14.9	% 	 	 	1,176	 	  	 	1,193	 	 	 	(1.4	%) 
	 Funds from operations (FFO)1 
	  	 	418	 	  	 	385	 	  	 	8.6	% 	 	 	1,211	 	  	 	1,177	 	 	 	2.9	% 
							
	 Capital investments
	  	 	402	 	  	 	380	 	  	 	5.8	% 	 	 	1,108	 	  	 	1,136	 	 	 	(2.5	%) 
	 Assets placed in-service
	  	 	239	 	  	 	294	 	  	 	(18.7	%) 	 	 	861	 	  	 	859	 	 	 	0.2	% 
							
	 Transmission: Average monthly Ontario 60-minute peak demand (MW)

	  	 	22,759	 	  	 	20,857	 	  	 	9.1	% 	 	 	20,841	 	  	 	19,801	 	 	 	5.3	% 
	 Distribution:     Electricity distributed to
Hydro One customers (GWh) 
	  	 	6,817	 	  	 	6,226	 	  	 	9.5	% 	 	 	20,334	 	  	 	19,046	 	 	 	6.8	% 
							
	  	  	  	 	  	  	 	  	  	 	 	  	 	  	2018	 	 	2017	 
	 Debt to capitalization ratio2 
	  	 	 	 	  	 	 	 	  	 	 	 	 	 	 	 	  	 	53.1	% 	 	 	52.9	% 

  

	1 	 See section “Non-GAAP Measures” for description and reconciliation of
basic and diluted Adjusted EPS, FFO and Revenues, net of purchased power. 

  

	2 	 Debt to capitalization ratio has been presented at September 30, 2018 and December 31, 2017, and has been
calculated as total debt (includes total long-term debt, convertible debentures and short-term borrowings, net of cash and cash equivalents) divided by total debt plus total shareholders’ equity, including preferred shares but excluding any
amounts related to noncontrolling interest. 

 OVERVIEW 

For the nine months ended September 30, 2018, Hydro One’s business segments accounted for the Company’s total revenues, net of purchased
power, as follows: 
  

													
	  	  	Transmission	 	  	Distribution	 	  	Other	 
	 Percentage of Company’s total revenues, net of purchased
power
	  	 	54%	 	  	 	45%	 	  	 	1%	 

 At September 30, 2018, Hydro One’s business segments accounted for the Company’s total assets as
follows:     
  

													
	  	  	Transmission	 	  	Distribution	 	  	Other	 
	 Percentage of Company’s total assets
	  	 	52%	 	  	 	35%	 	  	 	13%	 

  

					
		  	1	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 
 RESULTS OF OPERATIONS 

Net Income 
 Net income attributable to common shareholders for
the quarter ended September 30, 2018 of $194 million is a decrease of $25 million or 11.4% from the prior year. Significant influences on net income included: 
  

	 	•	 	 increase in transmission and distribution revenues due to higher energy consumption resulting from favourable weather;

  

	 	•	 	 lower transmission revenues driven by the timing of Ontario Energy Board (OEB)‘s decision on the 2017-2018
transmission rate filing, which resulted in recognition of year-to-date revenues in the third quarter of 2017, partially offset by increased OEB-approved transmission rates; 

  

	 	•	 	 lower OM&A costs primarily resulting from lower costs related to the acquisition of Avista Corporation (Merger),
savings related to the renewed information technology (IT) outsourced contract, lower customer programs costs; partially offset by higher corporate support costs; 

 

	 	•	 	 higher financing charges primarily due to revaluation losses on the deal-contingent foreign exchange forward contract,
and an increase in interest expense on long-term debt and on the convertible debentures issued in August 2017; and 

  

	 	•	 	 higher income tax expense primarily attributable to a combination of an increase in the estimated annual effective tax
rate (ETR) for 2018 arising from higher forecast earnings coupled with a corresponding decrease in the estimated annual ETR for 2017 arising from lower forecast earnings. 

Net income attributable to common shareholders for the nine months ended September 30, 2018 of $616 million is an increase of $113 million
or 22.5% from the prior year. Significant influences on net income included: 
  

	 	•	 	 increase in transmission and distribution revenues due to higher energy consumption resulting from favourable weather;

  

	 	•	 	 higher transmission revenues driven by increased OEB-approved transmission rates;

  

	 	•	 	 lower OM&A costs primarily resulting from lower costs related to the acquisition of Avista Corporation, savings
related to the renewed IT outsourced contract, lower customer programs costs, lower storm restoration costs and timing of work programs; partially offset by higher project write-offs due to revision of asset replacement strategies and alternatives
not pursued; 

  

	 	•	 	 higher financing charges primarily due to an increase in interest expense incurred on the convertible debentures issued
in August 2017 and on short-term notes payable, partially offset by revaluation gains on the deal-contingent foreign exchange forward contract and a decrease in interest expense on long-term debt; and 

 

	 	•	 	 higher income tax expense primarily attributable to a combination of an increase in the estimated annual ETR for 2018
arising from higher forecast earnings coupled with a corresponding decrease in the estimated annual ETR for 2017 arising from lower forecast earnings. 

EPS and Adjusted EPS 
 EPS was $0.33 and $1.03 in the three and
nine months ended September 30, 2018, respectively, compared to EPS of $0.37 and $0.85 in the comparable periods last year. The changes in EPS were driven by changes in net income for the three and nine months ended September 30, 2018, as
discussed above. Adjusted EPS, which adjusts for income and costs related to Avista Corporation acquisition, including the gains and losses on the deal-contingent foreign exchange forward contract, was $0.38 and $1.06 in the three and nine months
ended September 30, 2018, compared to $0.40 and $0.88 in the comparable periods last year. The changes in Adjusted EPS were driven by changes in net income for the three and nine months ended September 30, 2018, as discussed above, but
exclude the impact of items related to Avista Corporation acquisition. See section “Non-GAAP Measures” for description of Adjusted EPS. 

  

					
		  	2	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 
 Revenues 
  

																									
	 	  	 Three months ended September 30

 
	 	 	 Nine months ended September 30

 
	 
	  (millions of dollars, except as otherwise noted)	  	2018	 	  	2017	 	  	Change	 	 	2018	 	  	2017	 	  	Change	 
	 Transmission
	  	 	493	 	  	 	471	 	  	 	4.7	% 	 	 	1,344	 	  	 	1,199	 	  	 	12.1	% 
	 Distribution
	  	 	1,103	 	  	 	1,040	 	  	 	6.1	% 	 	 	3,284	 	  	 	3,317	 	  	 	(1.0	%) 
	 Other
	  	 	10	 	  	 	11	 	  	 	(9.1	%) 	 	 	31	 	  	 	35	 	  	 	(11.4	%) 
	 Total revenues
	  	 	1,606	 	  	 	1,522	 	  	 	5.5	% 	 	 	4,659	 	  	 	4,551	 	  	 	2.4	% 
							
	 Transmission
	  	 	493	 	  	 	471	 	  	 	4.7	% 	 	 	1,344	 	  	 	1,199	 	  	 	12.1	% 
	 Distribution, net of purchased power
	  	 	370	 	  	 	365	 	  	 	1.4	% 	 	 	1,126	 	  	 	1,104	 	  	 	2.0	% 
	 Other
	  	 	10	 	  	 	11	 	  	 	(9.1	%) 	 	 	31	 	  	 	35	 	  	 	(11.4	%) 
	 Total revenues, net of purchased power
	  	 	873	 	  	 	847	 	  	 	3.1	% 	 	 	2,501	 	  	 	2,338	 	  	 	7.0	% 
							
	 Transmission: Average monthly Ontario 60-minute peak demand (MW)

	  	 	22,759	 	  	 	20,857	 	  	 	9.1	% 	 	 	20,841	 	  	 	19,801	 	  	 	5.3	% 
	 Distribution:     Electricity distributed to
Hydro One customers (GWh) 
	  	 	6,817	 	  	 	6,226	 	  	 	9.5	% 	 	 	20,334	 	  	 	19,046	 	  	 	6.8	% 

 Transmission Revenues 

Transmission revenues increased by 4.7% for the quarter ended September 30, 2018 primarily due to the following: 

 

	 	•	 	 higher average monthly Ontario 60-minute peak demand primarily driven by
favourable weather in the summer of 2018; and 

  

	 	•	 	 increased 2018 allowed return on equity (ROE) for the transmission business; partially offset by 

 

	 	•	 	 lower revenues driven by the timing of the OEB’s decision on the 2017-2018 transmission rate filing, which resulted
in recognition of year-to-date revenues in the third quarter of 2017; partially offset by increased OEB-approved transmission
rates for 2018; and 

  

	 	•	 	 lower deferred regulatory adjustments. 

The increase of 12.1% in transmission revenues for the nine months ended September 30, 2018 was primarily due to the following: 

 

	 	•	 	 higher average monthly Ontario 60-minute peak demand primarily driven by
favourable weather in May, June and the summer of 2018; 

  

	 	•	 	 higher revenues driven by increased OEB-approved transmission rates for 2018; and

  

	 	•	 	 increased 2018 allowed ROE for the transmission business; partially offset by 

 

	 	•	 	 lower deferred regulatory adjustments. 

Distribution Revenues, Net of Purchased Power 

Distribution revenues, net of purchased power, increased by 1.4% for the quarter ended September 30, 2018 primarily due to the following: 

 

	 	•	 	 higher energy consumption resulting from favourable weather in the summer of 2018; partially offset by

  

	 	•	 	 lower external revenues in 2018 primarily due to revenues received in 2017 for Hurricane Irma restoration assistance
efforts in Florida. These restoration efforts had no impact on the Company’s net income, as related costs were recorded in distribution OM&A during the third quarter of 2017; and 

 

	 	•	 	 lower deferred regulatory adjustments. 

The increase of 2.0% in distribution revenues, net of purchased power, for the nine months ended September 30, 2018 was the result of similar factors
as noted above. 
 OM&A Costs 
  

																									
	 	  	 Three months ended September 30

 
	 	 	 Nine months ended September 30

 
	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	Change	 	 	2018	 	  	2017	 	  	Change	 
	 Transmission
	  	 	95	 	  	 	95	 	  	 	—	% 	 	 	295	 	  	 	296	 	  	 	(0.3	%) 
	 Distribution
	  	 	150	 	  	 	149	 	  	 	0.7	% 	 	 	435	 	  	 	447	 	  	 	(2.7	%) 
	 Other
	  	 	26	 	  	 	33	 	  	 	(21.2	%) 	 	 	67	 	  	 	79	 	  	 	(15.2	%) 
	 	  	 	271	 	  	 	277	 	  	 	(2.2	%) 	 	 	797	 	  	 	822	 	  	 	(3.0	%) 

 Transmission OM&A Costs 

Transmission OM&A costs for the quarter ended September 30, 2018 were comparable to prior year, and were primarily impacted by the following:

  

	 	•	 	 insurance proceeds received for the National Research Council (NRC) transformer station; 

 

	 	•	 	 lower costs related to the renewed IT outsourced contract; 

  

					
		  	3	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 

	 	•	 	 higher volume of work on vegetation management; 

 

	 	•	 	 higher project write-offs due to revision of asset replacement strategies and alternatives not pursued; and

  

	 	•	 	 higher corporate support costs. 

Transmission OM&A costs for the nine months ended September 30, 2018 were comparable to prior year, and were primarily impacted by factor noted
above, as well as lower volume of work on environmental management. 
 Distribution OM&A Costs 

Distribution OM&A costs for the quarter ended September 30, 2018 were comparable to prior year, and were primarily impacted by: 

 

	 	•	 	 lower storm restoration costs in 2018 as a result of Hurricane Irma restoration assistance efforts in Florida in 2017.
These restoration efforts had no impact on the Company’s net income, as related revenues were recorded in distribution revenues during the third quarter of 2017; 

 

	 	•	 	 lower costs associated with customer programs, primarily related to the Call Center and a lower volume of field
collections and investigations as a result of extended winter moratorium; 

  

	 	•	 	 lower costs related to the renewed IT outsourced contract; 

 

	 	•	 	 higher spend on vegetation management; 

 

	 	•	 	 higher volume of emergency calls; and 

 

	 	•	 	 higher corporate support costs. 

The decrease of 2.7% in distribution OM&A costs for the nine months ended September 30, 2018 was primarily due to the following: 

 

	 	•	 	 lower storm restoration costs; 

 

	 	•	 	 lower costs associated with customer programs, primarily related to Call Center, less demand for low income assistance
program and a lower volume of field collections and investigations as a result of extended winter moratorium; 

  

	 	•	 	 lower costs related to the renewed IT outsourced contract; 

 

	 	•	 	 lower bad debt expense; partially offset by 

 

	 	•	 	 project and inventory write-offs due to revision of asset replacement strategies, alternatives not pursued, and obsolete
inventory and technology; and 

  

	 	•	 	 higher volume of emergency calls. 

Other OM&A Costs 
 The decrease in other
OM&A costs for the quarter and nine months ended September 30, 2018 was primarily due to lower consulting and contract costs related to the acquisition of Avista Corporation, partially offset by higher labour costs. 

Financing Charges 
 The increase of $35 million or 30.7% in
financing charges for the quarter ended September 30, 2018 was primarily due to the following: 
  

	 	•	 	 an unrealized loss recorded in the third quarter of 2018 due to revaluation of the deal-contingent foreign exchange
forward contract related to the Avista Corporation merger; 

  

	 	•	 	 an increase in interest expense related to the convertible debentures issued in August 2017; and 

 

	 	•	 	 an increase in interest expense on long-term debt driven by higher long-term debt balance outstanding during the third
quarter of 2018. 

 The increase of $16 million or 5.0% in financing charges for the nine months ended September 30, 2018
was primarily due to the following: 
  

	 	•	 	 an increase in interest expense related to the convertible debentures issued in August 2017; and 

 

	 	•	 	 an increase in interest expense on short-term notes payable driven by higher weighted average interest rates and balance
of short-term notes outstanding in 2018; partially offset by 

  

	 	•	 	 an unrealized gain recorded in 2018 due to revaluation of the deal-contingent foreign exchange forward contract related
to the Avista Corporation merger; and 

  

	 	•	 	 a decrease in interest expense on long-term debt driven by lower long-term debt balance outstanding in 2018.

 Income Tax Expense 
 Income tax expense
was $41 million and $115 million for the three and nine months ended September 30, 2018, respectively, compared to $23 million and $73 million in the same periods of 2017. The Company realized an ETR for the three and nine
months ended September 30, 2018 of approximately 17.1% and 15.4%, respectively, compared to approximately 9.3% and 12.3% in the same periods last year. 

  

					
		  	4	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

As prescribed by the regulators, the Company recovers income taxes and is required to accrue its tax expense based on the tax liability determined without
accounting for temporary differences recoverable in the future from customers. The annual ETR is re-forecast at each interim reporting period and can fluctuate based on the change in forecast annual earnings
at the conclusion of each reporting period. 
 The increase in income tax expense for the three and nine months ended September 30, 2018 was
primarily attributable to a combination of an increase in the estimated annual ETR for 2018 arising from higher forecast earnings coupled with a corresponding decrease in the estimated annual ETR for 2017 arising from lower forecast earnings. 

Common Share Dividends 
 In 2018, the Company declared and paid
cash dividends to common shareholders as follows: 
  

													
	  Date Declared	  	Record Date	  	Payment Date	  	Amount per Share	 	  	 Total Amount  

(millions of dollars)  
	 
	 February 12, 2018
	  	March 13, 2018	  	March 29, 2018	  	 	$0.22	 	  	 	131  	 
	 May 14, 2018
	  	June 12, 2018	  	June 29, 2018	  	 	$0.23	 	  	 	137  	 
	 August 13, 2018
	  	September 11, 2018	  	September 28, 2018	  	 	$0.23	 	  	 	137  	 
	 	  	 	  	 	  	 	 	 	  	 	405  	 

 Following the conclusion of the third quarter of 2018, the Company declared a cash dividend to common shareholders as
follows: 
  

													
	  Date Declared	  	Record Date	  	Payment Date	  	Amount per Share	 	  	 Total Amount  

(millions of dollars)  
	 
	   November 7, 2018
	  	December 11, 2018	  	December 31, 2018	  	 	$0.23	 	  	 	137  	 

 QUARTERLY RESULTS OF OPERATIONS 
  

																																	
	Quarter ended (millions of dollars, except EPS) 	  	Sep 30, 2018	 	  	Jun 30, 2018	 	  	Mar 31, 2018	 	  	Dec 31, 2017	 	  	Sep 30, 2017	 	  	Jun 30, 2017	 	  	Mar 31, 2017	 	  	Dec 31, 2016  	 
	 Revenues
	  	 	1,606	 	  	 	1,477	 	  	 	1,576	 	  	 	1,439	 	  	 	1,522	 	  	 	1,371	 	  	 	1,658	 	  	 	1,614  	 
	 Purchased power
	  	 	733	 	  	 	674	 	  	 	751	 	  	 	662	 	  	 	675	 	  	 	649	 	  	 	889	 	  	 	858  	 
	 Revenues, net of purchased power
	  	 	873	 	  	 	803	 	  	 	825	 	  	 	777	 	  	 	847	 	  	 	722	 	  	 	769	 	  	 	756  	 
	 Net income to common shareholders
	  	 	194	 	  	 	200	 	  	 	222	 	  	 	155	 	  	 	219	 	  	 	117	 	  	 	167	 	  	 	128  	 
									
	 Basic EPS
	  	 	$0.33	 	  	 	$0.34	 	  	 	$0.37	 	  	 	$0.26	 	  	 	$0.37	 	  	 	$0.20	 	  	 	$0.28	 	  	 	$0.22  	 
	 Diluted EPS
	  	 	$0.32	 	  	 	$0.33	 	  	 	$0.37	 	  	 	$0.26	 	  	 	$0.37	 	  	 	$0.20	 	  	 	$0.28	 	  	 	$0.21  	 
	 Basic Adjusted EPS1 
	  	 	$0.38	 	  	 	$0.33	 	  	 	$0.35	 	  	 	$0.29	 	  	 	$0.40	 	  	 	$0.20	 	  	 	$0.28	 	  	 	$0.22  	 
	 Diluted Adjusted EPS1 
	  	 	$0.38	 	  	 	$0.32	 	  	 	$0.35	 	  	 	$0.28	 	  	 	$0.40	 	  	 	$0.20	 	  	 	$0.28	 	  	 	$0.21  	 

  

	1 	 See section “Non-GAAP Measures” for description of Adjusted EPS.

 Variations in revenues and net income over the quarters are primarily due to the impact of seasonal weather conditions on customer
demand and market pricing, as well as timing of regulatory decisions. 
 CAPITAL INVESTMENTS 

The Company makes capital investments to maintain the safety, reliability and integrity of its transmission and distribution system assets and to provide
for the ongoing growth and modernization required to meet the expanding and evolving needs of its customers and the electricity market. This is achieved through a combination of sustaining capital investments, which are required to support the
continued operation of Hydro One’s existing assets, and development capital investments, which involve both additions to existing assets and large scale projects such as new transmission lines and transmission stations. 

Assets Placed In-Service 

The following table presents Hydro One’s assets placed in-service during the three and nine months ended
September 30, 2018 and 2017: 
  

																									
	 	  	 Three months ended September 30

 
	 	  	 Nine months ended September 30 

 
	 
	(millions of dollars)	  	2018	 	  	2017	 	  	Change	 	  	2018	 	  	2017	 	  	Change 	 
	 Transmission
	  	 	112	 	  	 	120	 	  	 	(6.7%)	 	  	 	466	 	  	 	367	 	  	 	27.0%  	 
	 Distribution
	  	 	126	 	  	 	172	 	  	 	(26.7%)	 	  	 	389	 	  	 	482	 	  	 	(19.3%) 	 
	 Other
	  	 	1	 	  	 	2	 	  	 	(50.0%)	 	  	 	6	 	  	 	10	 	  	 	(40.0%) 	 
	 Total assets placed
in-service
	  	 	239	 	  	 	294	 	  	 	(18.7%)	 	  	 	861	 	  	 	859	 	  	 	0.2%  	 

  

					
		  	5	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Transmission Assets Placed In-Service 

Transmission assets placed in-service decreased by $8 million or 6.7% during the third quarter of 2018
primarily due to the following: 
  

	 	•	 	 timing of assets placed in-service for station sustainment investments, including
Richview transmission station, Lakehead transmission station, and Kirkland Lake transmission station, partially offset by Beach transmission station; 

  

	 	•	 	 lower volume of overhead lines and component replacement work placed in-service;

  

	 	•	 	 lower volume of fleet and work equipment purchases; 

 

	 	•	 	 lower volume of wood pole replacements; partially offset by 

 

	 	•	 	 higher volume of spare transformer purchases; and 

 

	 	•	 	 higher volume of replacement work on transmission facilities as a result of the wind storm. 

Transmission assets placed in-service increased by $99 million or 27.0% during the nine months ended
September 30, 2018 primarily due to the factors listed above, as well as the following: 
  

	 	•	 	 substantial completion of major development work at the Clarington transmission station; partially offset by

  

	 	•	 	 timing of assets placed in-service for station sustainment investments, including
Aylmer transmission station, Goderich transmission station, DeCew Falls switching station, Nepean transmission station, and Hinchinbrooke switching station; partially offset by NRC transmission station, and Bruce A transmission station;

  

	 	•	 	 the completion of the Field Workforce Optimization
(Move-to-Mobile) project in June 2017; and 

  

	 	•	 	 cumulative investments for major local area supply projects at the Manby and Hawthorne transmission stations placed
in-service in 2017. 

 Distribution Assets Placed In-Service 

Distribution assets placed in-service decreased by $46 million or 26.7% during the third quarter of 2018
primarily due to the following: 
  

	 	•	 	 the completion of the Outage Response Management System (ORMS) project in the third quarter of 2017;

  

	 	•	 	 lower volume of fleet and work equipment purchases; 

 

	 	•	 	 timing of assets that were placed in-service for system capability reinforcement
projects; 

  

	 	•	 	 lower volume of distribution station refurbishments; 

 

	 	•	 	 lower volume of wood pole replacements; and 

 

	 	•	 	 higher volume of lines large sustainment carryover work in the third quarter of 2017; partially offset by

  

	 	•	 	 higher volume of emergency power and storm restorations work. 

Distribution assets placed in-service decreased by $93 million or 19.3% during the nine months ended
September 30, 2018 primarily due to the factors listed above, as well as the following: 
  

	 	•	 	 the completion of the Move-to-Mobile
project in June 2017; and 

  

	 	•	 	 completion of an operation center in Bolton in February 2017; partially offset by 

 

	 	•	 	 increased investments for meter sustainment work were placed in-service;

  

	 	•	 	 cumulative investments that were placed in-service for the Source-to-Order Transformation project, which aims to modernize the Company’s sourcing and procurement capabilities; and 

 

	 	•	 	 the completion of the Bill Redesign project, which included investments in application enhancements and software
upgrades. 

 Capital Investments 
 The
following table presents Hydro One’s capital investments during the three and nine months ended September 30, 2018 and 
 2017: 

 

																									
	 	  	 Three months ended September 30

 
	 	  	 Nine months ended September 30

 
	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	Change	 	  	2018	 	  	2017	 	  	Change	 
	 Transmission
	  				  				  				  				  				  			
	 Sustaining
	  	 	221	 	  	 	189	 	  	 	16.9% 	 	  	 	587	 	  	 	548	 	  	 	7.1% 	 
	 Development
	  	 	30	 	  	 	32	 	  	 	(6.3%)	 	  	 	77	 	  	 	108	 	  	 	(28.7%)	 
	 Other
	  	 	10	 	  	 	19	 	  	 	(47.4%)	 	  	 	29	 	  	 	45	 	  	 	(35.6%)	 
	 	  	 	261	 	  	 	240	 	  	 	8.8% 	 	  	 	693	 	  	 	701	 	  	 	(1.1%)	 
	 Distribution
	  				  				  				  				  				  			
	 Sustaining
	  	 	72	 	  	 	63	 	  	 	14.3% 	 	  	 	232	 	  	 	215	 	  	 	7.9% 	 
	 Development
	  	 	59	 	  	 	53	 	  	 	11.3% 	 	  	 	153	 	  	 	162	 	  	 	(5.6%)	 
	 Other
	  	 	7	 	  	 	22	 	  	 	(68.2%)	 	  	 	24	 	  	 	50	 	  	 	(52.0%)	 
	 	  	 	138	 	  	 	138	 	  	 	—% 	 	  	 	409	 	  	 	427	 	  	 	(4.2%)	 
							
	 Other
	  	 	3	 	  	 	2	 	  	 	50.0% 	 	  	 	6	 	  	 	8	 	  	 	(25.0%)	 
	 Total capital investments
	  	 	402	 	  	 	380	 	  	 	5.8% 	 	  	 	1,108	 	  	 	1,136	 	  	 	(2.5%)	 

  

					
		  	6	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 
 Transmission Capital Investments 

Transmission capital investments increased by $21 million or 8.8% during the third quarter of 2018. Principal impacts on the levels of capital
investments included: 
  

	 	•	 	 higher volume of demand work associated with equipment failures; 

 

	 	•	 	 higher volume of overhead lines refurbishments and replacements; 

 

	 	•	 	 timing of project activities on major development projects, including the Niagara Reinforcement and Lake Superior Link
projects, as well as work at Brant, Holland, and Clarington transmission stations; 

  

	 	•	 	 higher volume of work required to adhere to the North American Electric Reliability Corporation (NERC) Critical
Infrastructure Protection (Cyber Security) standards; and 

  

	 	•	 	 higher volume of IT upgrades and enhancements primarily related to the Private Cloud Data Center project in support of
the modernization of Hydro One’s IT infrastructure; partially offset by 

  

	 	•	 	 lower volume of transmission station refurbishments and replacements work; 

 

	 	•	 	 lower spend on load customer connections due to the completion of work at Leamington transmission station in 2017;
partially offset by timing of work at Enfield transmission station; and 

  

	 	•	 	 decreased investment in fleet and work equipment purchases as a result of fleet standardization and asset specification
review. 

 Transmission capital investments decreased by $8 million or 1.1% during the nine months ended September 30, 2018,
primarily due to the factors listed above, as well as the following: 
  

	 	•	 	 lower spend on load customer connections attributable to higher capital contribution received from customers;

  

	 	•	 	 timing of work on the Hawthorne transmission station; 

 

	 	•	 	 lower volume of wood pole replacements; and 

 

	 	•	 	 the completion of the Move-to-Mobile
project in second quarter of 2017; partially offset by 

  

	 	•	 	 higher volume of spare transformer purchases. 

Distribution Capital Investments 
 Distribution
capital investments for the quarter ended September 30, 2018 were comparable to prior year, and were primarily impacted by: 
  

	 	•	 	 decreased investments in fleet and work equipment purchases as a result of fleet standardization and asset specification
review; 

  

	 	•	 	 lower volume of wood pole replacements; 

 

	 	•	 	 lower volume of distribution lines and station refurbishments and replacements work; 

 

	 	•	 	 increased volume of emergency power and storm restorations work due to higher storm activity in 2018; and

  

	 	•	 	 higher volume of IT upgrades and enhancements primarily related to the Private Cloud Data Center project in support of
the modernization of Hydro One’s IT infrastructure. 

 Distribution capital investments decreased by $18 million or 4.2%
during the nine months ended September 30, 2018, primarily due to the factors listed above, as well as the following: 
  

	 	•	 	 lower spend on Advanced Distribution System infrastructures; 

 

	 	•	 	 the completion of the Move-to-Mobile
project in second quarter of 2017; and 

  

	 	•	 	 lower spend on new connections and upgrades. 

  

					
		  	7	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Major Transmission Capital Investment Projects 
 The following
table summarizes the status of significant transmission projects as at September 30, 2018: 
  

																	
	  Project Name	  	  Location	  	  Type	  	Anticipated
In-Service Date	 	  	Estimated
Cost	 	 	Capital Cost
To Date	 
	 	  	 	  	 	  	(year)	 	  	(millions of dollars)	 
					
	 Development Projects:
	  		  		  				  			
						
	 Supply to Essex County Transmission Reinforcement
	  	 Windsor-Essex area Southwestern Ontario
	  	 New transmission line and station
	  	 	2018	 	  	 	55	1   	 	 	54	 
						
	 Clarington Transmission Station
	  	 Oshawa area Southwestern Ontario
	  	 New transmission station
	  	 	2018	 	  	 	240	1  	 	 	235	 
						
	 Niagara Reinforcement Project
	  	 Niagara area Southwestern Ontario
	  	 New transmission line
	  	 	2019	 	  	 	130	 	 	 	114	 
						
	 East-West Tie Station Expansion
	  	 Northern Ontario
	  	 New transmission connection and station expansion
	  	 	2021	 	  	 	157	 	 	 	12	 
						
	 Northwest Bulk Transmission Line

 
	  	 Thunder Bay-Atikokan
Northwestern Ontario
  
	  	 New transmission line
	  	 	2024	 	  	 	350	 	 	 	1	 
						
	 Sustainment Projects:
	  		  		  				  				 			
						
	 Richview Transmission Station Circuit Breaker Replacement
	  	 Toronto Southwestern Ontario
	  	 Station sustainment
	  	 	2019	 	  	 	104	 	 	 	96	 
						
	 Bruce A Transmission Station
	  	 Tiverton Southwestern Ontario
	  	 Station sustainment
	  	 	2020	 	  	 	138	 	 	 	119	 
						
	 Beck #2 Transmission Station Circuit Breaker Replacement
	  	 Niagara area Southwestern Ontario
	  	 Station sustainment
	  	 	2022	 	  	 	114	 	 	 	61	 
						
	 Lennox Transmission Station Circuit Breaker Replacement

 
	  	 Napanee Southeastern Ontario
	  	 Station sustainment
	  	 	2023	 	  	 	98	 	 	 	56	 

  

	1	 Major portions of the Supply to Essex County Transmission Reinforcement and Clarington Transmission Station projects
were completed and placed in-service. Work on certain minor portions of the project continues in the second half of 2018. 

Future Capital Investments 
 Following is a summary of estimated
capital investments by Hydro One over the years 2018 to 2022. The Company’s estimates are based on management’s expectations of the amount of capital expenditures that will be required to provide transmission and distribution services that
are efficient, reliable, and provide value for customers, consistent with the OEB’s Renewed Regulatory Framework. The 2019 transmission capital investments estimates differ from the prior year disclosures, representing a decrease of
$158 million to reflect Hydro One’s recent one-year inflation-based application for 2019 transmission rates. The projections and the timing of 2020-2022 expenditures are subject to approval by the
OEB. 
 The following table summarizes Hydro One’s annual projected capital investments for 2018 to 2022, by business segment: 

 

																					
	  (millions of dollars)	  	2018	 	  	2019	 	  	2020	 	  	2021	 	  	2022	 
	 Transmission
	  	 	1,010	 	  	 	1,059	 	  	 	1,278	 	  	 	1,486	 	  	 	1,404	 
	 Distribution
	  	 	641	 	  	 	751	 	  	 	715	 	  	 	719	 	  	 	805	 
	 Other
	  	 	9	 	  	 	8	 	  	 	6	 	  	 	9	 	  	 	8	 
	 Total capital investments
	  	 	1,660	 	  	 	1,818	 	  	 	1,999	 	  	 	2,214	 	  	 	2,217	 

 The following table summarizes Hydro One’s annual projected capital investments for 2018 to 2022, by
category:     
  

																					
	  (millions of dollars)	  	2018	 	  	2019	 	  	2020	 	  	2021	 	  	2022	 
	 Sustainment
	  	 	1,103	 	  	 	1,040	 	  	 	1,328	 	  	 	1,547	 	  	 	1,608	 
	 Development
	  	 	340	 	  	 	523	 	  	 	487	 	  	 	490	 	  	 	430	 
	 Other1

	  	 	217	 	  	 	255	 	  	 	184	 	  	 	177	 	  	 	179	 
	 Total capital investments
	  	 	1,660	 	  	 	1,818	 	  	 	1,999	 	  	 	2,214	 	  	 	2,217	 

  

	1	 “Other” capital expenditures consist of special projects, such as those relating to
IT.     

  

					
		  	8	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 
 SUMMARY OF SOURCES AND USES OF CASH 

Hydro One’s primary sources of cash flows are funds generated from operations, capital market debt issuances and bank credit facilities that are used
to satisfy Hydro One’s capital resource requirements, including the Company’s capital expenditures, servicing and repayment of debt, and dividend payments. 
  

																	
	 	  	Three months ended
September 30	 	 	Nine months ended
September 30	 
	  (millions of dollars)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Cash provided by operating activities
	  	 	508	 	 	 	442	 	 	 	1,176	 	 	 	1,193	 
	 Cash provided by (used in) financing activities
	  	 	(746	) 	 	 	529	 	 	 	487	 	 	 	506	 
	 Cash used in investing activities
	  	 	(394	) 	 	 	(382	) 	 	 	(1,075	) 	 	 	(1,127	) 
	 Increase (decrease) in cash and cash equivalents
	  	 	(632	) 	 	 	589	 	 	 	588	 	 	 	572	 

 Cash provided by operating activities 

Cash from operating activities for the third quarter of 2018 increased by $66 million compared to the third quarter of 2017, were impacted by various
factors, including higher cash earnings, and favourable changes in non-cash balances related to operations. Cash from operating activities for the nine months ended September 30, 2018 decreased by
$17 million compared to the same period in 2017, were impacted by various factors, including improved collection of accounts receivables in 2017 that reached a stabilized level in 2018, and disposition of certain regulatory variance and
deferral accounts in 2018, partially offset by higher cash earnings in 2018. 
 Cash provided by financing activities 

Sources of cash 
  

	 	•	 	 During the nine months ended September 30, 2018, the Company issued $1,400 million of long-term debt, all in
the second quarter, compared to no long-term debt issued in the prior year. 

  

	 	•	 	 The Company received proceeds of $445 million and $2,987 million from the issuance of short-term notes in the
three and nine months ended September 30, 2018, respectively, compared to $1,232 million and $2,810 million received in the same periods last year. 

 

	 	•	 	 During the three and nine months ended September 30, 2017, the Company issued $513 million of convertible
debentures, gross of $27 million financing costs, compared to no convertible debenture issuances in 2018. 

 Uses of cash

  

	 	•	 	 Dividends paid in the three and nine months ended September 30, 2018 were $141 million and $418 million,
respectively, compared to dividends of $135 million and $400 million paid in the same periods last year. 

  

	 	•	 	 The Company repaid $1,049 million and $3,469 million of short-term notes in the three and nine months ended
September 30, 2018, respectively, compared to $1,053 million and $2,385 million repaid in the same periods last year. 

 Cash used
in investing activities 
 Uses of cash 
  

	 	•	 	 Capital expenditures were $13 million higher in the third quarter of 2018 and $45 million lower year-to-date 2018, primarily due to volume and timing of capital investment work. 

LIQUIDITY AND FINANCING STRATEGY 
 Short-term liquidity is
provided through funds from operations, Hydro One Inc.’s commercial paper program, and the Company’s consolidated bank credit facilities. Under the commercial paper program, Hydro One Inc. is authorized to issue up to $1.5 billion in
short-term notes with a term to maturity of up to 365 days. At September 30, 2018, Hydro One Inc. had $444 million in commercial paper borrowings outstanding, compared to $926 million outstanding at December 31, 2017. In
addition, the Company has revolving bank credit facilities (Operating Credit Facilities) with total availability of $2,550 million maturing in 2021 and 2022, with no amounts used at September 30, 2018 or December 31, 2017. The Company
may use these credit facilities for working capital and general corporate purposes. The short-term liquidity under the commercial paper program, the Operating Credit Facilities and anticipated levels of funds from operations are expected to be
sufficient to fund the Company’s normal operating requirements. 
 At September 30, 2018, the Company had long-term debt outstanding in the
principal amount of $11,468 million which included $11,323 million of long-term debt issued by Hydro One Inc. and long-term debt in the principal amount of $145 million held by Hydro One Sault Ste. Marie LP (HOSSM). The majority of
long-term debt issued by Hydro One Inc. has been issued under its Medium Term Note (MTN) Program. The maximum authorized principal amount of notes issuable under the current MTN Program prospectus filed in March 2018 is $4.0 billion. At
September 30, 2018, $2.6 billion remained available for issuance until April 2020. The long-term debt consists of notes and debentures that mature between 2018 and 2064, and at September 30, 2018, had a weighted-average term to
maturity of approximately 15.5 years and a weighted-average coupon rate of 4.1%. 

  

					
		  	9	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

On June 18, 2018, Hydro One filed a short form base shelf prospectus (Universal Base Shelf Prospectus) with securities regulatory authorities in
Canada to replace the universal base shelf prospectus that expired on April 30, 2018. The Universal Base Shelf Prospectus allows Hydro One to offer, from time to time in one or more public offerings, up to $4.0 billion of debt, equity or
other securities, or any combination thereof, during the 25-month period ending on July 18, 2020. Hydro One filed the Universal Base Shelf Prospectus to provide the Company with financing flexibility
going forward. Hydro One Holdings Limited, an indirect wholly-owned subsidiary of Hydro One, expects to file in the future a short form base shelf prospectus with securities regulatory authorities in Canada and the US for the purposes of funding a
portion of the cash purchase price of the Merger. 
 Acquisition Credit Facilities 

For the purpose of bridge financing for the pending acquisition of Avista Corporation, the Company secured a $1.0 billion non-revolving equity bridge credit facility, and a US$2.6 billion non-revolving debt bridge credit facility (Acquisition Credit Facilities) in June 2018. The equity
bridge credit facility matures 90 days after the drawdown date and in any event not later than June 30, 2019. The debt bridge credit facility is available until March 31, 2019, and matures one year after the drawdown date. At
September 30, 2018, no amounts have been drawn on the Acquisition Credit Facilities. 
 Hydro One is required to make prepayments of the
Acquisition Credit Facilities in an amount equal to the net cash proceeds from any common equity, preferred equity, bond or other debt offerings, including the net proceeds from the final instalment of convertible debentures issued in August 2017,
and any non-ordinary course asset sales by Hydro One and its subsidiaries, subject to certain exceptions. Any prepayment under the Acquisition Credit Facilities may not be
re-borrowed. The Acquisition Credit Facilities agreements contain customary representations and warranties and affirmative and negative covenants of Hydro One that are consistent with those of Hydro One’s
Operating Credit Facilities. If the Merger does not close, then these agreements will be cancelled. 
 To mitigate the foreign currency risk related to
the portion of the Avista Corporation acquisition purchase price financed by the issuance of convertible debentures, in October 2017, the Company entered into a deal-contingent foreign exchange forward contract to convert $1.4 billion Canadian
to US dollars. For the nine months ended September 30, 2018, an unrealized fair value gain of $25 million was recorded related to this contract, compared to an unrealized fair value loss of $3 million recorded for the year ended
December 31, 2017. At September 30, 2018, the corresponding derivative asset was $22 million, compared to a derivative liability of $3 million at December 31, 2017. 

The cash purchase price of the Merger and the Merger-related costs are expected to be financed at the closing of the Merger with a combination of some or
all of the following sources: (i) net proceeds of the first instalment from the sale in August 2017 of $1.54 billion aggregate principal amount of 4.00% convertible debentures of the Company represented by instalment receipts;
(ii) net proceeds of any subsequent bond or other offering; (iii) amounts drawn under the existing $250 million operating credit facility of the Company; (iv) amounts drawn under the $1 billion
non-revolving equity bridge credit facility; (v) amounts drawn under the US $2.6 billion non-revolving debt bridge credit facility; (vi) net proceeds of
any offering of securities from the Company’s Universal Base Shelf Prospectus; and (vii) existing cash on hand and other sources available to the Company. 

Compliance 
 At September 30, 2018, the Company was in
compliance with all financial covenants and limitations associated with the outstanding borrowings and credit facilities. 
 Credit Ratings 

Following the announcement of the Avista Corporation transaction on July 19, 2017, various ratings organizations undertook a review of the
Company’s and Hydro One Inc.’s debt ratings. These ratings organizations may take various actions, positive or negative. The Company cannot predict what actions rating agencies may take in the future. The failure to maintain the
Company’s current credit ratings could adversely affect the Company’s financial condition and results of operations, and a downgrade in the Company’s credit ratings could restrict the Company’s ability to access debt capital
markets and increase the Company’s cost of debt. 
 On June 20, 2018, Moody’s Investors Service (Moody’s) downgraded the long-term
debt rating for Hydro One Inc. to “Baa1” from “A3”, and revised its outlook on Hydro One Inc. to stable from negative. In addition, Moody’s affirmed the existing “Prime-2”
short-term debt rating for Hydro One Inc. Moody’s no longer assigns any probability of extraordinary support from the Province of Ontario (Province) in Hydro One Inc.’s credit analysis which has led to the downgrade. 

On June 15, 2018, S&P Global Ratings (S&P) placed its ratings on the Company and Hydro One Inc. on CreditWatch negative reflecting the
likelihood of a one-notch downgrade to both companies due to the Avista Corporation transaction. On July 18, 2018, S&P released an update maintaining the CreditWatch negative placement, which
continued to reflect the likelihood of a one-notch downgrade in the Company and Hydro One Inc.‘s issuer credit rating of “A” due to the Avista Corporation transaction, and also incorporated the
possibility that the Company’s governance structure could result in an additional one-notch downgrade if S&P concludes that recent developments related to the retirement of the Company’s Chief
Executive Officer (CEO) and the replacement of the Company’s Board of Directors (Board) adversely impact management decision making and fails to promote the interests of all stakeholders. See section “Hydro One Board of Directors and
Executive Officers” for more information. 

  

					
		  	10	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

On September 13, 2018, S&P lowered its issuer credit ratings on the Company to “A-” from
“A”. At the same time, S&P lowered the issue-level rating on Hydro One Inc.‘s senior unsecured debt by one notch to “A-” from “A” and lowered the rating on Hydro One
Inc.‘s commercial paper program by one notch to “A-1(low)” from “A-1(mid)” on the Canadian National Scale. All ratings remain on CreditWatch
where S&P placed them with negative implications on June 15, 2018. The one-notch downgrade reflects S&P’s reassessment of Hydro One’s management and governance structure, which has
weakened following the Province’s decision to exert its influence on the Company’s compensation structure through legislation, potentially promoting the interests and priorities of one owner above those of other stakeholders. 

The following tables present the Company’s and Hydro One Inc.‘s credit ratings at September 30, 2018: 

Hydro One 
  

					
	  Rating Agency	  	Corporate Credit
Rating	  	  
	 S&P
	  	A-	  	
	  

 Hydro One Inc. 
  

							
	 Rating Agency	  	Short-term Debt
Rating	 	Long-term Debt
Rating	 	  
	 DBRS Limited	  	R-1 (low)	 	A (high)	 	
	 Moody’s	  	Prime-2	 	Baa1	 	
	 S&P	  	A-1 (low)	 	A-	 	
	  

 OTHER OBLIGATIONS 
 Off-Balance Sheet Arrangements 
 There are no off-balance sheet
arrangements that have, or are reasonably likely to have, a material current or future effect on the Company’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or
capital resources. 

  

					
		  	11	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Summary of Contractual Obligations and Other Commercial Commitments 

The following table presents a summary of Hydro One’s debt and other major contractual obligations and commercial commitments: 

 

																					
	  September 30, 2018 (millions of dollars) 	  	Total	 	  	Less than
1 year	 	  	1-3 years	 	  	3-5 years	 	  	More than
5 years	 
	 Contractual obligations (due by year) 
	  				  				  				  				  			
	 Long-term debt – principal repayments
	  	 	11,468	 	  	 	981	 	  	 	1,956	 	  	 	736	 	  	 	7,795	 
	 Long-term debt – interest payments
	  	 	8,329	 	  	 	459	 	  	 	858	 	  	 	776	 	  	 	6,236	 
	 Convertible debentures - principal repayments1

	  	 	513	 	  	 	—	 	  	 	—	 	  	 	—	 	  	 	513	 
	 Convertible debentures - interest payments
	  	 	554	 	  	 	62	 	  	 	123	 	  	 	123	 	  	 	246	 
	 Short-term notes payable
	  	 	444	 	  	 	444	 	  	 	—	 	  	 	—	 	  	 	—	 
	 Pension contributions2 
	  	 	159	 	  	 	66	 	  	 	93	 	  	 	—	 	  	 	—	 
	 Environmental and asset retirement obligations
	  	 	197	 	  	 	30	 	  	 	64	 	  	 	61	 	  	 	42	 
	 Outsourcing agreements
	  	 	271	 	  	 	124	 	  	 	138	 	  	 	5	 	  	 	4	 
	 Operating lease commitments
	  	 	31	 	  	 	9	 	  	 	16	 	  	 	3	 	  	 	3	 
	 Long-term software/meter agreement
	  	 	41	 	  	 	14	 	  	 	23	 	  	 	3	 	  	 	1	 
	 Total contractual obligations
	  	 	22,007	 	  	 	2,189	 	  	 	3,271	 	  	 	1,707	 	  	 	14,840	 
	  
	 
						
	 Other commercial commitments (by year of expiry) 
	  				  				  				  				  			
	 Operating Credit Facilities3 
	  	 	2,550	 	  	 	—	 	  	 	—	 	  	 	2,550	 	  	 	—	 
	 Letters of credit4 
	  	 	167	 	  	 	162	 	  	 	5	 	  	 	—	 	  	 	—	 
	 Guarantees5 
	  	 	325	 	  	 	325	 	  	 	—	 	  	 	—	 	  	 	—	 
	  
	 
	 Total other commercial commitments
	  	 	3,042	 	  	 	487	 	  	 	5	 	  	 	2,550	 	  	 	—	 
	  
	 

  

	1 	 The Company expects that the convertible debentures will be converted to common shares upon closing of the Avista
Corporation acquisition. 

  

	2 	 Contributions to the Hydro One Pension Fund are generally made one month in arrears. The 2018, 2019 and 2020 minimum
pension contributions are based on an actuarial valuation as at December 31, 2017 and projected levels of pensionable earnings. 

  

	3 	 For repayment and expiry details of the Acquisition Credit Facilities, please see section Liquidity and Financing
Strategy. 

  

	4 	 Letters of credit consist of a $154 million letter of credit related to retirement compensation arrangements, a
$7 million letter of credit provided to the Independent Electricity System Operator (IESO) for prudential support, $5 million in letters of credit to satisfy debt service reserve requirements, and $1 million in letters of credit for
various operating purposes. 

  

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

 SHARE CAPITAL 
 The common shares of
Hydro One are publicly traded on the Toronto Stock Exchange (TSX) under the trading symbol “H”. Hydro One is authorized to issue an unlimited number of common shares. The amount and timing of any dividends payable by Hydro One is at the
discretion of the Hydro One Board 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 may consider relevant. At November 7, 2018, Hydro One had 595,882,438 issued and outstanding common shares. 

The Company is authorized to issue an unlimited number of preferred shares, issuable in series. At November 7, 2018, two series of preferred shares
are authorized for issuance: the Series 1 preferred shares and the Series 2 preferred shares. At November 7, 2018, the Company had 16,720,000 Series 1 preferred shares and no Series 2 preferred shares issued and outstanding. 

The number of common shares of Hydro One that would be issued if all outstanding stock options and convertible debentures were converted as at
November 7, 2018 is 949,910 and 71,962,660, respectively. 
 REGULATION 

The OEB approves both the revenue requirements of and the rates charged by Hydro One’s regulated transmission and distribution businesses. The rates
are designed to permit the Company’s transmission and distribution businesses to recover the allowed costs and to earn a formula-based annual rate of return on its deemed 40% equity level invested in the regulated businesses. This is done by
applying a specified equity risk premium to forecast interest rates on long-term bonds. In addition, the OEB approves rate riders to allow for the recovery or disposition of specific regulatory deferral and variance accounts over specified time
frames. 

  

					
		  	12	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

The following table summarizes the status of Hydro One’s major regulatory proceedings: 

 

							
	  Application	  	Years	  	Type	  	Status
	 Electricity Rates
	  		  		  	
	 Hydro One Networks
	  	2017-2018	  	Transmission – Cost-of-service	  	OEB decision received1 
	 Hydro One Networks
	  	2019	  	Transmission – Revenue Cap	  	OEB decision pending
	 Hydro One Networks
	  	2018-2022	  	Distribution – Custom	  	OEB decision pending
	 B2M LP
	  	2015-2019	  	Transmission – Cost-of-service	  	OEB decision received
	 HOSSM
	  	2017-2026	  	Transmission – Revenue Cap	  	OEB decision received2 
	 NRLP
	  	2019	  	Transmission – Interim Revenue	  	OEB decision pending
	  

		
	 Mergers Acquisitions Amalgamations and Divestitures (MAAD)
	  	
	 Orillia Power
	  	n/a	  	Acquisition	  	OEB decision pending3 
	 Peterborough Distribution
	  	n/a	  	Acquisition	  	OEB decision pending
	  

				
	 Leave to Construct
	  		  		  	
	 East-West Tie Station Expansion
	  	n/a	  	Section 92	  	OEB decision pending
	 Lake Superior Link Project
	  	n/a	  	Section 92	  	OEB decision pending
	  

  

	1 	 In August 2018, the OEB returned the portion of the Decision relating to the deferred tax asset to an OEB panel for
reconsideration. 

  

	2 	 In October 2016, the OEB approved the 2017-2026 revenue requirements. In July 2018, HOSSM filed an application for an
inflationary increase (Price Cap Escalator factor) to its 2019 revenue requirement. 

  

	3 	 In September 2018, Hydro One filed a new MAAD application with the OEB to acquire Orillia Power. 

The following table summarizes the key elements and status of Hydro One’s electricity rate applications: 

 

													
	  Application	 	Year	 	 	ROE
Allowed (A)
or Forecast (F)	 	 Rate Base

Allowed (A)
 or Forecast (F)
	 	Rate Application Status	 	Rate Order Status
						
	 Transmission
	 				 		 		 		 	
	 Hydro One Networks
	 	 	2018	 	 	9.00% (A)	 	$11,148 million (A)	 	Approved in September 2017	 	Approved in December 2017
		 	 	2019	 	 	  n/a1 	 	n/a1 	 	Filed in October 2018	 	To be filed
	  

	 B2M LP
	 	 	2018	 	 	9.00% (A)	 	$502 million (A)	 	Approved in December 2015	 	OEB decision received
		 	 	2019	 	 	9.00% (F)	 	$496 million (A)	 	Approved in December 2015	 	To be filed in 2018 Q4
	  

	 HOSSM
	 	 	2017-2026	 	 	9.19% (A)	 	$218 million (A)	 	Approved in October 2016	 	OEB decision received2 
	  

	 NRLP
	 	 	2019	 	 	9.00% (F)	 	$123 million (F)	 	Filed in October 2018	 	To be filed
	  

	 Distribution
	 				 		 		 		 	
	 Hydro One Networks
	 	 	2018	 	 	9.00% (A)	 	$7,650 million (F)	 	Filed in March 20173 	 	To be filed in 2018 Q4
		 	 	2019	 	 	9.00% (F)	 	$8,009 million (F)	 	Filed in March 20173 	 	To be filed in 2018 Q4
		 	 	2020	 	 	9.00% (F)	 	$8,412 million (F)	 	Filed in March 20173 	 	To be filed in 2019 Q4
		 	 	2021	 	 	9.00% (F)	 	$8,941 million (F)	 	Filed in March 20173 	 	To be filed in 2020 Q4
		 	 	2022	 	 	9.00% (F)	 	$9,306 million (F)	 	Filed in March 20173 	 	To be filed in 2021 Q4
	  

  

	1 	 The Revenue Cap application is a formulaic adjustment to the approved revenue requirement and does not consider ROE or
rate base. 

  

	2 	 In October 2016, the OEB approved the 2017-2026 revenue requirements. In July 2018, HOSSM filed an application for an
inflationary increase (Price Cap Escalator factor) to its 2019 revenue requirement. 

  

	3 	 In June 2018, Hydro One Networks filed an undertaking with the OEB which included updated rate base amounts.

 Electricity Rates Applications 
 Hydro One Networks -
Transmission 
 On September 28, 2017, the OEB issued its Decision and Order on Hydro One Networks’ 2017 and 2018 transmission rates
revenue requirements (Decision), with 2017 rates effective January 1, 2017. Key changes to the application as filed included reductions in planned capital expenditures of $126 million and $122 million for 2017 and 2018, respectively,
in OM&A expenses related to compensation by $15 million for each year, and in estimated tax savings from the Initial Public Offering (IPO) by $24 million and $26 million for 2017 and 2018, respectively. On October 10, 2017,
Hydro One Networks filed a Draft Rate Order reflecting the changes outlined in the 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 

  

					
		  	13	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

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. The exposure from the potential impairments would be a one-time decrease in net income of up to approximately $885 million, resulting in
an annual decrease to FFO in the range of $50 million to $60 million. 
 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). 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. An OEB hearing of the merits of the Motion was held on February 12, 2018. On August 31, 2018, the OEB granted the Motion and returned the portion of the Decision relating to the deferred tax asset to an OEB
panel for reconsideration. 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 aforementioned tax savings will be allocated to the benefit of Hydro One shareholders. 
 In
October 2017, the intervenor Anwaatin Inc. also filed a Motion to Review and Vary the OEB Decision (Anwaatin Motion) alleging that the OEB breached its duty of procedural fairness, failed to respond to certain evidence, and failed to provide reasons
on the capital budget as it related to reliability issues impacting Anwaatin Inc.’s constituents. The Anwaatin Motion was heard by the OEB on February 13, 2018. Hydro One reached a settlement agreement with Anwaatin Inc. regarding the
Anwaatin Motion. On June 15, 2018, the settlement agreement was filed with the OEB for approval. 
 On November 23, 2017, the OEB approved the
2017 rates revenue requirement of $1,438 million. On December 20, 2017, the OEB approved the 2018 rates revenue requirement of $1,511 million, which included a $25 million increase from the approved amount, as a result of the OEB-updated cost of capital parameters. Uniform Transmission Rates (UTRs), reflecting these approved amounts, were approved by the OEB on February 1, 2018 to be effective as of January 1, 2018. 

In March 2017, the Financial Accounting Standards Board (FASB) issued an Accounting Standards Update (ASU)
2017-07, which limits capitalization of post-employment benefit related costs to the service cost component. Hydro One filed an application requesting the OEB to approve a regulatory asset, to record the
amounts no longer permitted for capitalization under the new standard, effective January 1, 2018. In May 2018, the OEB approved the regulatory asset. 

On March 16, 2018, the OEB issued a letter requesting Hydro One to file the transmission revenue requirement application for a four-year test period
from 2019 to 2022, rather than the minimum 5-year period allowed under existing OEB policy. The OEB indicated that it is more appropriate to consider rates for Hydro One’s distribution and transmission
businesses in a single application, and stated that it expected Hydro One to file a single application for distribution rates (including Hydro One Remote Communities Inc.) and transmission revenue requirement for the period from 2023 to 2027. 

A one-year inflation-based application for 2019 transmission rates was filed with the OEB on October 26,
2018. 
 Hydro One Networks - Distribution 
 The OEB
oral hearing related to Hydro One Networks’ application for 2018-2022 distribution rates was held on June 11-28, 2018. On July 20, 2018, Hydro One submitted its Argument-in-Chief. Intervenors had until August 10, 2018 to respond. On August 31, 2018, Hydro One filed its reply argument with the OEB. This concludes the evidentiary process with the exception of
pole attachment charges, and matters relating to recovery of certain amounts paid for executive compensation, as per the Hydro One Accountability Act (Act). See section “Hydro One Board of Directors and Executive Officers” for more
information. For both of these matters, the OEB issued a procedural order on October 12, 2018 outlining the next steps in the process throughout the fourth quarter of 2018. As part of these steps, on October 26, 2018, Hydro One filed a
submission with the OEB on how the Act impacts its distribution rate application. On November 2, 2018, Hydro One filed a submission with the OEB on the pole attachment charges. 

On June 27, 2018, the OEB issued a letter deferring Hydro One’s request for the OEB to approve an alternative method to calculate amounts
related to the post-employment benefit costs for Hydro One Networks’ distribution business until the next re-basing application is filed, as the OEB noted that the issue is relevant to both the
distribution and transmission businesses of Hydro One Networks. In the 2019 transmission rates application filed with the OEB on October 26, 2018, Hydro One requested this decision be made as part of its next transmission re-basing application. 
 B2M LP 

On May 10, 2018, the OEB issued its Decision and Rate Order on B2M LP’s 2018 transmission application reflecting revenue requirement of
$36 million, effective January 1, 2018. 
 Hydro One Remote Communities Inc. 

On March 19, 2018, the OEB approved the settlement agreement related to the 2018 rates application reached by Hydro One Remote Communities Inc. and
the intervenors in the rate proceeding. On March 26, 2018, a draft rate order was filed with the OEB for 2018 rates. The OEB approved the draft rate order on April 12, 2018, and the new rates were implemented effective May 1, 2018.

  

					
		  	14	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

HOSSM 
 HOSSM is under a
10-year deferred rebasing period for years 2017-2026, as approved in the OEB MAAD decision dated October 13, 2016. On July 26, 2018, HOSSM filed a 2019 application to allow for inflationary increase
(Price Cap Escalator factor) to its previously approved revenue requirement. The Price Cap Escalator factor is designed to add inflationary increases to the revenue requirement on an annual basis. 

Niagara Reinforcement Limited Partnership (NRLP) 
 On
September 19, 2018, NRLP was formed to own and operate a new 230 kV transmission line, the Niagara Reinforcement Project, built to connect generators in the Niagara area and the load centres of the Greater Toronto and Hamilton areas. 

On September 27, 2018, Hydro One filed a transmission licence application with the OEB for NRLP. On October 25, 2018, Hydro One filed two other
applications with the OEB relating to NRLP requesting approval for Hydro One Networks to sell the applicable assets to NRLP and approval of interim rates to include in the 2019 UTRs. 

MAAD Applications 
 Orillia Power MAAD Application 

In 2016, Hydro One filed a MAAD application (2016 Application) with the OEB to acquire Orillia Power Distribution Corporation (Orillia Power) from the
City of Orillia, Ontario. On April 12, 2018, the OEB issued a decision denying Hydro One’s proposed acquisition of Orillia Power. The decision indicated that with the exception to pricing, the transaction met the no harm test.
Additionally, the OEB indicated that it required additional evidence on the overall cost structure following the deferral period and the impact on Orillia Power’s customers. On May 2, 2018, Hydro One and Orillia Power both filed a Motion
to Review and Vary the OEB’s decision, and on August 23, 2018, the OEB issued a decision upholding its April 12, 2018 decision to deny Hydro One’s proposed acquisition of Orillia Power. 

On September 26, 2018, Hydro One filed a new MAAD application (2018 Application) with the OEB to acquire Orillia Power. The evidence in the 2018
Application is similar to that provided in the 2016 Application, with the exception of updates to reflect current variables to costs and other metrics, as well as future cost structures. 

Peterborough Distribution MAAD Application 
 On October 12,
2018, the Company filed an application with the OEB for approval of the acquisition of business and distribution assets of Peterborough Distribution Inc. (Peterborough Distribution). On October 25, 2018, an advance ruling certification
application was filed with the Competition Bureau. See section “Other Developments - Peterborough Distribution Purchase Agreement” for more information on the acquisition. 

Other Applications 
 Lake Superior Link Project 

On February 15, 2018, Hydro One filed a Leave to Construct application with the OEB to construct the east-west tie line (EWT Line) in northwestern
Ontario (Lake Superior Link Project), which will compete with an application filed by NextBridge Infrastructure (NextBridge) to construct the EWT Line. Pursuant to the OEB’s direction, on July 26, 2018, the IESO issued its analysis of the
impacts of a delay to the in-service date for the construction of the EWT Line. In its analysis, the IESO recommends an in-service date of 2020 for the completion of the
EWT Line and does not support a delay beyond 2022, due to increased risks to system reliability and the associated cost uncertainties. 
 A combined OEB
oral hearing for the Hydro One EWT Line application, the Hydro One East-West Tie Station Expansion application, and the NextBridge EWT Line application was held on October 2-12, 2018. The OEB’s decision
is expected by the end of 2018. 
 OTHER DEVELOPMENTS 
 Collective
Agreements 
 On March 1, 2018, Hydro One insourced its customer service operations, which had been previously outsourced to Inergi LP and
Vertex Customer Management (Canada) Limited since 2002. The insourcing was facilitated through labour agreements reached with the Power Workers’ Union (PWU) and The Society of United Professionals (formerly The Society of Energy Professionals)
in 2017. 
 The current collective agreement with the PWU expired on March 31, 2018. On March 26, 2018, Hydro One and the PWU reached a
tentative agreement, and on June 27, 2018, the agreement has been ratified by the PWU. The term of the agreement is for two years ending on March 31, 2020. 

US GAAP - Exemptive Relief 
 On March 27,
2018, Hydro One was granted exemptive relief by securities regulators in each province and territory of Canada which allows Hydro One to continue to report its financial results in accordance with US GAAP (Exemptive Relief). The Exemptive
Relief 

  

					
		  	15	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

will remain in effect until the earlier of: (i) January 1, 2024; (ii) the first day of Hydro One’s financial year that commences after
Hydro One ceases to have activities subject to rate regulation; and (iii) the effective date prescribed by the International Accounting Standards Board for the mandatory application of a standard within International Financial Reporting
Standards specific to entities with activities subject to rate regulation. 
 Avista Corporation Merger 

In July 2017, Hydro One reached an agreement to acquire Avista Corporation. The following table summarizes the status of the Merger approval process: 

 

			
	Approval Required	  	Status
	 Alaska1 
	  	 Approval received on June 4, 201810 

	 Washington1 
	  	 Settlement agreement filed on March 27, 20184 

	 Idaho1 
	  	 Settlement agreement filed on April 13, 20186 

	 Oregon1 
	  	 Settlement agreement filed on May 25, 20189 

	 Montana1 
	  	 Approval received on July 10, 201811 

	 Federal Communications Commission
	  	 Consent received on May 4, 20187 

	 Committee on Foreign Investment in the United States
	  	 Clearance received on May 18, 20188 

	 Hart-Scott-Rodino Antitrust
	  	 Clearance received on April 5, 20185 

	 Federal Energy Regulatory Commission
	  	 Approval received on January 16, 20183 

	 Avista Corporation shareholders
	  	 Approval received on November 21, 20172

  

	1 	 On September 14, 2017, Hydro One and Avista Corporation filed applications with the state utility commissions in
Alaska, Washington, Idaho, Oregon, and Montana, requesting regulatory approval of the Merger on or before August 14, 2018. 

  

	2 	 On November 21, 2017, the Merger was approved by the shareholders of Avista Corporation. 

 

	3 	 On January 16, 2018, the Federal Energy Regulatory Commission approved the Merger application.

  

	4 	 On March 27, 2018, an all-parties,
all-issues settlement agreement was filed with the Washington Utilities and Transportation Commission. On July 12, 2018, the Washington Utilities and Transportation Commission gave notice of its intent to
conduct additional process, and on July 20, 2018, it gave notice that it is extending the deadline for a decision to December 14, 2018. On October 4, 2018, all parties to the settlement filed testimony in support of the settlement and
additional and modified commitments offered by Avista Corporation and Hydro One. A hearing on this matter was held on October 23, 2018. 

  

	5 	 On April 5, 2018, the 30-day waiting period under the Hart-Scott-Rodino
Antitrust Improvements Act of 1976, as amended, for the Merger expired. This expiration of the waiting period means that the parties have received antitrust clearance for the Merger and satisfies one of the closing conditions of the transaction.

  

	6 	 On April 13, 2018, a multi-party settlement agreement was filed with the Idaho Public Utilities Commission. On
July 20, 2018, the Idaho Public Utilities Commission ordered that a hearing initially scheduled for July 23, 2018 was vacated in response to the leadership changes at Hydro One announced in July 2018. A new hearing date has been set for
November 26-27, 2018. 

  

	7 	 On May 4, 2018, consent for the transfer of control of the wireless licences held by Avista Corporation and one of
its subsidiaries to Hydro One as a result of the Merger was received from the Federal Communications Commission. On October 3, 2018, the Federal Communications Commission granted an extension to consummate the transfer of control of the
wireless licenses to April 13, 2019. 

  

	8 	 On May 18, 2018, the Committee on Foreign Investment in the United States has completed its review of the proposed
merger, and has concluded that there are no unresolved national security concerns with respect to the Merger. 

  

	9 	 On May 25, 2018, an all-parties,
all-issues settlement agreement was filed with the Oregon Public Utility Commission. In response to the leadership changes at Hydro One announced in July 2018, one party no longer supports Hydro One’s
acquisition of Avista Corporation. On July 25, 2018, a new procedural schedule was adopted for the proceedings, setting a hearing for November 15-16, 2018, and a target date of December 14, 2018 for
a decision by the Oregon Public Utility Commission. 

  

	10 	 On June 4, 2018, the Merger was approved by the Regulatory Commission of Alaska, subject to certain conditions.

  

	11 	 On July 10, 2018, the Merger was approved by the Montana Public Service Commission, subject to certain conditions.

 Following the announcement on July 11, 2018 of the resignation of Hydro One’s Board and the immediate retirement of its
President and CEO (see section “Hydro One Board of Directors and Executive Officers” for more information), regulatory authorities in Washington and Oregon extended the timetable for arriving at a decision in Hydro One’s acquisition
of Avista Corporation to mid-December 2018. In addition, the Idaho Public Utilities Commission rescheduled its hearing from July 23, 2018 to November 26-27, 2018.
Applications for regulatory approval of the Merger are pending with utility commissions in Washington, Idaho, and Oregon. The settlement agreements remain subject to approval by the respective commissions. Also required is the satisfaction of
customary closing conditions. 
 The closing of the Merger is subject to the normal commercial risks that the Merger will not close on the terms
negotiated or at all. The completion of the Merger is subject to receipt of certain regulatory and governmental approvals, including the expiration or termination of any applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements
Act of 1976, clearance of the Merger by the Committee on Foreign Investment in the United States, the approval by each of the Idaho Public Utilities Commission, the Public Service Commission of the State of Montana, the Public Utility Commission
of Oregon, the Regulatory Commission of Alaska, the Washington Utilities and Transportation Commission, the United States Federal Energy Regulatory Commission and the United States Federal Communications Commission (the status of which are noted
above), and the satisfaction or waiver of certain closing conditions contained in the Merger Agreement. The failure to obtain the required approvals or satisfy or waive the conditions contained in the Merger Agreement may result in the termination
of the Merger Agreement. There is no assurance that such closing conditions will be satisfied or waived. Accordingly, there can be no assurance that Hydro One will complete the Merger in the timeframe or on the basis described herein, if at all.
Failure to complete the Merger could expose Hydro One to litigation and resulting damages. The termination of the Merger Agreement may have an effect (which may be material and/or negative) on the price of the convertible debentures’ instalment
receipts and the Hydro One common shares, and will result in the redemption of the 

  

					
		  	16	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

convertible debentures. If the closing of the Merger does not take place as contemplated, the Company could suffer adverse consequences, including the
loss of investor confidence, and may incur significant costs or losses, including an obligation to pay or cause to be paid to Avista Corporation a termination fee of US$103 million or other damages, which could be material. In addition, the
redemption of the convertible debentures would result in the related deferred financing costs being expensed immediately ($24 million at September 30, 2018), and the deal-contingent foreign exchange forward contract would be revalued to
$nil, which would result in a reversal of any previously recorded unrealized gains ($22 million at September 30, 2018). 
 Litigation 

Class Action Lawsuit 
 Hydro One Inc., Hydro One Networks,
Hydro One Remote Communities Inc., 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. The appeal was heard on October 16, 2018, and it is likely that the court will render
its decision before the end of 2018. 
 Litigation Relating to the Merger 

To date, four putative class action lawsuits were 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. 
 Peterborough Distribution Purchase Agreement 

On July 31, 2018, Hydro One reached an agreement to acquire the business and distribution assets of Peterborough Distribution, an electricity
distribution company located in east central Ontario, from the City of Peterborough. Hydro One will pay the City of Peterborough $105 million for the transaction. The acquisition is conditional upon the satisfaction of customary closing
conditions and approval by the OEB and the Competition Bureau. On October 12, 2018, the Company filed an application with the OEB for approval of the acquisition. 

HYDRO ONE BOARD OF DIRECTORS AND EXECUTIVE OFFICERS 
 Directors and Executive
Officers 
 On July 11, 2018, Hydro One, on behalf of itself and its wholly-owned subsidiary, Hydro One Inc., announced that it had entered
into an agreement (Letter Agreement) with the Province for the purpose of the orderly replacement of the Board of Hydro One and Hydro One Inc. and the retirement of Mayo Schmidt as the CEO effective July 11, 2018. Hydro One also announced the
appointment of Paul Dobson as Acting President and CEO of Hydro One and Hydro One Inc. effective July 11, 2018. 
 On August 14, 2018, Hydro
One announced a new Board. Six directors were identified and nominated by Hydro One’s ad hoc nominating committee, comprised of three of the five largest shareholders of Hydro One excluding the Province, and four directors were identified and
nominated by the Province, Hydro One’s largest shareholder. Each of the directors are independent of both Hydro One and the Province in accordance with the Governance Agreement dated as of November 5, 2015 between Hydro One and the
Province (Governance Agreement). 
 The directors of Hydro One and Hydro One Inc. are the same in accordance with the provisions of the Governance
Agreement. 
 On September 7, 2018, Hydro One announced the appointment of Chris Lopez as Acting Chief Financial Officer of Hydro One and Hydro One
Inc., effective September 6, 2018. On September 7, 2018, Hydro One announced the appointment of Tom Woods as Chair of the Board of Hydro One and Hydro One Inc., effective September 6, 2018. 

The following table sets forth information regarding the current directors and executive officers of Hydro One and Hydro One Inc. as at November 1,
2018. Each of the directors was first appointed effective August 13, 2018. Each director is elected annually to serve for one year or until his or her successor is elected or appointed. 

  

					
		  	17	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 

											
	  Name, Province or State and
  Country of Residence	  	Age	  	Position/Title	  	 Independent

Board Member
	  	Principal Occupation	  	Committees
	 Paul Dobson
	  	52	  	Acting President	  		  	Acting President	  	
	 Texas, USA
	  		  	and CEO	  		  	and CEO	  	
						
	 Jason Fitzsimmons
	  	48	  	Chief Corporate Affairs	  		  	Chief Corporate Affairs	  	
	 Ontario, Canada
	  		  	and Customer Care Officer	  		  	and Customer Care Officer	  	
						
	 Gregory Kiraly
	  	54	  	Chief Operating Officer	  		  	Chief Operating Officer	  	
	 Arizona, USA
	  		  		  		  		  	
						
	 Chris Lopez
	  	44	  	Acting Chief Financial	  		  	Acting Chief Financial	  	
	 Alberta, Canada
	  		  	Officer	  		  	Officer	  	
						
	 Judy McKellar
	  	62	  	 Executive Vice President,

Chief Human Resources
	  		  	Executive Vice President,	  	
	 Ontario, Canada
	  		  	Officer	  		  	Chief Human Resources	  	
		  		  		  		  	Officer	  	
						
	 Patrick Meneley
	  	54	  	Executive Vice President	  		  	Executive Vice President	  	
	 Ontario, Canada
	  		  	and Chief Corporate	  		  	and Chief Corporate	  	
		  		  	Development Officer	  		  	Development Officer	  	
						
	 James Scarlett
	  	65	  	Executive Vice President	  		  	Executive Vice President	  	
	 Ontario, Canada
	  		  	and Chief Legal Officer	  		  	and Chief Legal Officer	  	
						
	 Tom Woods1 
	  	66	  	Director and Chair	  	Yes	  	Director	  	
	 Ontario, Canada
	  		  	of the Board	  		  		  	
						
	 Cherie Brant1 
	  	43	  	Director	  	Yes	  	Partner,	  	Governance Committee;
	 Ontario, Canada
	  		  		  		  	Dickinson Wright LLP	  	Health, Safety, Environment and Indigenous
		  		  		  		  		  	Peoples Committee
						
	 Blair Cowper-Smith1 
	  	70	  	Director	  	Yes	  	Director	  	Governance Committee (Chair);
	 Ontario, Canada
	  		  		  		  		  	Human Resources Committee
						
	 Anne Giardini
	  	59	  	Director	  	Yes	  	Director	  	Audit Committee; Health, Safety, Environment
	 British Columbia, Canada
	  		  		  		  		  	and Indigenous Peoples Committee (Chair)
						
	 David Hay
	  	63	  	Director	  	Yes	  	Managing Partner,	  	Audit Committee; Health, Safety, Environment
	 Ontario, Canada
	  		  		  		  	Delgatie Incorporated	  	and Indigenous Peoples Committee
						
	 Timothy Hodgson
	  	57	  	Director	  	Yes	  	Managing Partner and	  	Governance Committee;
	 Ontario, Canada
	  		  		  		  	Director, Alignvest	  	Human Resources Committee
		  		  		  		  	Management Corporation	  	
						
	 Jessica McDonald
	  	49	  	Director	  	Yes	  	Interim President and	  	Audit Committee;
	 British Columbia, Canada
	  		  		  		  	CEO, Canada Post	  	Human Resources Committee
		  		  		  		  	Corporation	  	
						
	 Russel Robertson1 
	  	71	  	Director	  	Yes	  	Director	  	Audit Committee;
	 Ontario, Canada
	  		  		  		  		  	Human Resources Committee
						
	 William Sheffield
	  	70	  	Director	  	Yes	  	Director	  	Audit Committee (Chair);
	 Ontario, Canada
	  		  		  		  		  	Health, Safety, Environment and Indigenous
		  		  		  		  		  	Peoples Committee
						
	 Melissa Sonberg
	  	58	  	Director	  	Yes	  	Adjunct Professor,	  	Governance Committee;
	 Québec, Canada
	  	 	  	 	  	 	  	McGill University	  	Human Resources Committee (Chair)

 1 These directors have been designated as the Province’s nominees to the Board
of Hydro One for the purpose of the Governance Agreement. 
 The following includes a brief profile of each of the executive officers and directors of
Hydro One and Hydro One Inc., which includes a description of their present occupation and their principal occupations for the past five years: 

Paul Dobson - Acting President and CEO 

Effective July 11, 2018, Paul Dobson was appointed to the role of Acting President and CEO of Hydro One. Mr. Dobson joined the Company as Chief
Financial Officer on March 1, 2018 responsible for finance, treasury, controller, internal audit, technology and regulation. Prior to joining Hydro One in 2018, Mr. Dobson served as Chief Financial Officer for Direct Energy Ltd. (Direct
Energy), Houston, Texas, where he was responsible for overall financial leadership of a $15 billion revenue business with three million customers in Canada and the US. Since 2003, Mr. Dobson has held senior leadership positions in finance,
operations, information technology and customer service across the Centrica Group, the parent company of Direct Energy. Prior to Direct Energy, Mr. Dobson worked at CIBC for 10 years in finance, strategy and business development roles in both
Canada and the US. Mr. Dobson also brings considerable experience in mergers and acquisitions and integrating acquired companies across North America and in the United Kingdom. Mr. Dobson is a dual
Canadian-US citizen who holds an honours bachelor’s degree from the University of Waterloo as well as a Masters of Business Administration (MBA) from the University of Western Ontario and is a CPA, CMA.

 Jason Fitzsimmons - Chief Corporate Affairs and Customer Care Officer 

Jason Fitzsimmons was promoted to Chief Corporate Affairs and Customer Care Officer in August 2018, with oversight of the customer service, corporate
affairs, marketing and Indigenous relations functions. With more than 25 years of experience in the electricity sector, Mr. Fitzsimmons is a highly-regarded leader with a proven track record for successfully executing large-scale
transformations and building strong relationships with key stakeholders. In his previous role as Vice President, Labour Relations at Hydro One, Mr. Fitzsimmons played an instrumental role in bringing the company’s 400-employee Customer Contact Centre in-house as the Company continuously strives to deliver
best-in-class customer service. Prior to joining the Company in 2016, Mr. Fitzsimmons was the Chief Negotiations Officer at the Ontario Hospital Association and
also held a number of executive roles at 

  

					
		  	18	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Ontario Power Generation, including Vice President of Human Resources for the Nuclear division. He is a Certified Human Resource Executive known for his
broad experience in labour management as well as his passion for health and safety in the workplace. He was a prior member of the Advisory Board for Ryerson University’s Centre for Labour Management Relations and has served on the Board for the
Electrical Power Sector Construction Association. 
 Gregory Kiraly - Chief Operating Officer 

Effective September 12, 2016, Gregory Kiraly was appointed to the role of Chief Operating Officer (COO) of Hydro One. As COO, Mr. Kiraly
oversees the complete transmission and distribution value chain including planning, engineering, construction, operations, maintenance, and forestry; shared services functions including facilities, real estate, fleet, and procurement; and the Hydro
One Telecom and Hydro One Remote Communities subsidiaries. Prior to joining Hydro One in 2016, Mr. Kiraly served as Senior Vice President of Electric Transmission and Distribution at Pacific Gas and Electric Company (PG&E) in San Francisco,
which delivers safe and reliable energy to more than 16 million customers in northern and central California. Since joining PG&E in 2008, Mr. Kiraly led efforts that achieved the lowest employee injury rates ever, seven straight years
of record electric reliability, and over $500 million in productivity improvements and efficiency savings. Before PG&E, Mr. Kiraly held executive-level positions in energy delivery at Commonwealth Edison (Exelon) in Chicago and
leadership positions in both gas and electric distribution at Public Service Electric and Gas Company in Newark, New Jersey. Mr. Kiraly holds a bachelor’s degree in industrial engineering from New Jersey Institute of Technology and an MBA
in finance from Seton Hall University. He is also a graduate of Harvard University’s Advanced Management Program. 
 Chris Lopez - Acting Chief Financial
Officer 
 Effective September 6, 2018, Chris Lopez was appointed as Acting Chief Financial Officer of Hydro One. Prior to joining Hydro One,
Mr. Lopez was the Vice President, Corporate Planning and Mergers & Acquisitions at TransAlta Corporation from 2011 to 2015. Prior to that, Mr. Lopez was Director of Operations Finance at TransAlta in Calgary from 2007 to 2011, and
he held senior financial roles up to and including Country Financial Controller for TransAlta in Australia, from 1999 to 2007. Mr. Lopez worked as a Senior Financial Accountant with Rio Tinto Iron Ore, in Australia from 1997 to 1999.
Mr. Lopez received a Bachelor of Business degree from Edith Cowan University in 1996, and a Chartered Accountant designation in Australia in 1999. He received a graduate diploma in corporate governance and directorships from the Australian
Institute of Company Directors in 2007. Mr. Lopez was accountable for leading the management of financial governance and reporting, treasury management taxation and planning and analysis before stepping up into the acting role of Chief
Financial Officer for the second half of 2017 following the departure of Michael Vels, until the appointment of Mr. Dobson as Chief Financial Officer on March 1, 2018. 

Judy McKellar - Executive Vice President, Chief Human Resources Officer 

Judy McKellar is the Executive Vice President, Chief Human Resources Officer of Hydro One. She was appointed to this position on November 11, 2016.
Ms. McKellar has held various roles of increasing responsibility at Hydro One Networks, an indirect subsidiary of Hydro One, in the Human Resources department over her 30+ year career and was appointed Vice President of Human Resources in 2010.
In 2014, she assumed the additional responsibility of Senior Vice President of People and Culture/Health, Safety and Environment and serves as the accountable executive for the Human Resources Committee of the Board. Ms. McKellar earned a
Bachelor of Arts degree from Victoria College, University of Toronto, and was recently named as one of 2015’s 100 Most Powerful Women in Canada by PricewaterhouseCoopers in the “Public Sector” category. 

Patrick Meneley - Executive Vice President and Chief Corporate Development Officer 

Effective March 1, 2018, Patrick Meneley was appointed to the role of Executive Vice President and Chief Corporate Development Officer of Hydro One.
In this capacity, Mr. Meneley is responsible for leading strategy, innovation and mergers and acquisitions. Prior to joining Hydro One in 2018, Mr. Meneley served as Executive Vice President, Wholesale Banking at TD Bank Group and Vice
Chair and Head of Global Corporate and Investment Banking for TD Securities. Mr. Meneley spent 15 years leading and building one of the leading corporate and investment banking businesses in Canada, along with a profitable and growing franchise
in the US. Mr. Meneley holds an MBA (with distinction) from the University of Western Ontario and a Bachelor of Commerce (with honours) from the University of British Columbia. 

James Scarlett - Executive Vice President and Chief Legal Officer 

Effective September 1, 2016, James Scarlett was appointed as Executive Vice President and Chief Legal Officer of Hydro One. Prior to joining Hydro
One, Mr. Scarlett was a Senior Partner at Torys LLP. He joined Torys LLP in March 2000 and held a number of leadership roles at the firm, including head of Torys LLP’s Capital Markets Group, Mining Group and International Business
Development Strategy. Mr. Scarlett was also a member of the firm’s Executive Committee from 2009-2015. Prior to joining Torys LLP, Mr. Scarlett was a Partner at another major Canadian law firm. While at that firm Mr. Scarlett
held leadership roles as head of its Corporate Group, Securities Group and as a member of its Board. Mr. Scarlett was also seconded to the Ontario Securities Commission in 1987 and was appointed as the first Director of Capital Markets in 1988,
a position he held until his return to private law practice in 1990. Mr. Scarlett earned his law degree (J.D.) from the University of Toronto in 1981 and his Bachelor of Commerce Degree from the University of McGill in 1975. In 2015,
Mr. Scarlett earned his ICD.D (Institute of Corporate Directors) designation. 

  

					
		  	19	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Tom Woods (provincial nominee) - Board Chair 
 Public
Directorships (other than Hydro One and Hydro One Inc.): Bank of America Corporation 
 Public Board Interlocks: None 

Mr. Woods is a corporate director. He previously had a 37-year career with CIBC, a major Canadian bank, and
Wood Gundy, the predecessor firm of CIBC World Markets. He started in Investment Banking, advising companies raising financing in the equity and debt capital markets as well as mergers and acquisitions, and later was Head of Canadian Corporate
Banking, Chief Financial Officer, Chief Risk Officer and Vice Chairman. 
 Mr. Woods also serves on the boards of Bank of America Corporation,
Alberta Investment Management Corporation, Providence St. Joseph’s St. Michael’s Health Care (Board Chair), University of Toronto Mechanical & Industrial Engineering and CIBC Children’s Foundation. Previous directorships
include TMX Group Inc., DBRS Limited, Jarislowsky Fraser Limited and Covenant House (Board Chair). Mr. Woods has a Bachelor of Applied Science in Industrial Engineering from University of Toronto, and an MBA from Harvard Business School. 

Cherie Brant (provincial nominee) 
 Public
Directorships (other than Hydro One and Hydro One Inc.): None 
 Public Board Interlocks: None 

Ms. Brant is a Partner at Dickinson Wright’s Toronto law office where she has an Indigenous law practice with a focus on commercial real estate,
energy and transmission and First Nations economic development. Ms. Brant provides strategic counsel to several First Nations and industry clients seeking to develop projects with First Nations and to understand and address Indigenous rights
and interests. As lead counsel, Ms. Brant was instrumental in forming one of the largest First Nations-led limited partnerships in Canada resulting in the Ontario First Nations Sovereign Wealth LP’s
share purchase of approximately 2.4% of Hydro One. Prior to being a Partner at Dickinson Wright LLP, she was a Partner at Willms & Shier LLP. 

Ms. Brant is both Mohawk and Ojibway from the Mohawks of the Bay of Quinte and Wikwemikong Unceded Indian Territory. She also serves on the board of
the Anishnawbe Health Foundation and is a member of the Canadian Council for Aboriginal Business, Research Advisory Board and the Aboriginal Energy Working Group of the IESO. Previous directorships include Women’s College Hospital and Trillium
Gift of Life. 
 Ms. Brant has a Bachelor of Environmental Studies, Urban and Regional Planning Program from the University of Waterloo and a Juris
Doctor from the University of Toronto. She is a member of the Ontario Bar Association and the Law Society of Ontario. 
 Blair Cowper-Smith
(provincial nominee) 
 Public Directorships (other than Hydro One and Hydro One Inc.): None 

Public Board Interlocks: None 
 Mr. Cowper-Smith is
the principal and founder of Erin Park Business Solutions, a Canadian advisory and consulting firm. Previously, he was Chief Corporate Affairs Officer of Ontario Municipal Employees Retirement System (OMERS), one of Canada’s largest public
pension plans, and a member of the Senior Executive Team where his responsibilities included regulatory affairs, law and governance. Prior to joining OMERS he was a Senior Partner at McCarthy Tetrault LLP where his practice focused on mergers and
acquisitions, infrastructure, governance and private equity. 
 Board experience includes numerous advisory assignments, including governance advisory
assignments, with boards of directors including OMERS, Stelco, Hammerson, and includes existing or prior director appointments and board committee leadership roles with companies like Porter Airlines, 407 ETR, the Financial Services Regulatory
Authority and Face the Future Foundation. He served until recently on the Public Policy Committee of the Canadian Coalition for Good Governance and on the Securities Advisory Committee of the Ontario Securities Commission. He co-founded The Canadian Council for Public and Private Partnerships which led to a long-term interest in infrastructure policy and delivery of infrastructure based services to Canadians. 

Mr. Cowper Smith has a Bachelor of Laws (LLB) and Master of Laws (LLM) from Osgoode Hall Law School at York University. He is a member of the Law
Society of Ontario and holds the director designation through the Institute of Corporate Directors and is a regular faculty presenter for the Directors College. 

Anne Giardini, O.C., O.B.C., Q.C. 
 Public
Directorships (other than Hydro One and Hydro One Inc.): Nevsun Resources Ltd. 
 Public Board Interlocks: None 

Ms. Giardini is a corporate director and Chancellor of Simon Fraser University, a public research university in British Columbia, Canada. She
previously had a 20-year career with Weyerhaeuser Company Limited, a forestry and wood product manufacturing company, including as Canadian President. Before her tenure as President, she was Vice President and
General Counsel at Weyerhaeuser where she worked on corporate, legal, policy and strategic matters. Ms. Giardini has been a newspaper columnist and is the author of two novels. 

Ms. Giardini also serves on the boards of Nevsun Resources Ltd., Canada Mortgage & Housing Corporation, World Wildlife Fund (Canada),
British Columbia Achievement Foundation, TransLink and the Greater Vancouver Board of Trade. Previous directorships include Thompson Creek Metals Company, Inc. and Weyerhaeuser Company Limited. 

  

					
		  	20	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Ms. Giardini has a Bachelor of Arts (Economics) from Simon Fraser University, a Bachelor of Laws from the University of British Columbia and a Master
of Law from the University of Cambridge (Trinity Hall). She is licensed to practice law in British Columbia (and formerly in Ontario and Washington State). In 2016, Ms. Giardini was appointed an Officer of the Order of Canada, and in 2018, she
was appointed to the Order of British Columbia. 
 David Hay 

Public Directorships (other than Hydro One and Hydro One Inc.): EPCOR Utilities Inc. 

Public Board Interlocks: None 
 Mr. Hay is a
corporate director and the Managing Director at Delgatie Incorporated, a strategic advisory firm. He is the former Vice-Chair and Managing Director of CIBC World Markets Inc., the investment banking subsidiary of CIBC, with power, utilities and
infrastructure as a major focus. Formerly, he was President and CEO of New Brunswick Power Corporation, and held senior investment banking roles, including Senior Vice President and Director responsible for mergers and acquisitions with Merrill
Lynch Canada and Managing Director of European mergers and acquisitions with Merrill Lynch International. He spent the early part of his career as a practicing lawyer and taught part-time at both the University of Toronto and University of New
Brunswick. 
 Mr. Hay also serves on the boards of EPCOR Utilities Inc., SHAD (Chair), the Council of Clean and Reliable Energy and as Chair
of the Acquisition Committee of the Beaverbrook Art Gallery. Prior directorships include Toronto Hydro-Electric System Limited (Vice Chair). 

Mr. Hay has a Bachelor of Laws from Osgoode Hall Law School, York University and a Bachelor of Arts from the University of Toronto. He also holds a
professional director designation from the Institute of Corporate Directors (ICD.D). 
 Timothy Hodgson 

Public Directorships (other than Hydro One and Hydro One Inc.): Alignvest Acquisition II Corporation and MEG Energy Corp. 

Public Board Interlocks: None 
 Mr. Hodgson is a
Managing Partner and Director of Alignvest Capital Management, an investment management firm. Prior to that, Mr. Hodgson was Special Advisor to Governor Mark Carney at Bank of Canada. Mr. Hodgson also held various positions in New York,
London, Silicon Valley and Toronto with Goldman Sachs and served as CEO of Goldman Sachs Canada. Mr. Hodgson has held roles with Salomon Brothers, Price Waterhouse & Co. and Merrill Lynch Canada. 

Mr. Hodgson also serves on the boards of Alignvest Acquisition II Corporation (Chair), PSP Investments and MEG Energy Corp. Previous directorships
included Alignvest Acquisition Corporation, KGS-Alpha Capital Markets L.P., The Global Risk Institute, The Ivey School of Business, The Next36, Bridgeport Health and CanWest Media Works Income
Fund. 
 Mr. Hodgson has a Bachelor of Commerce from the University of Manitoba and a MBA from The Richard Ivey School of Business at Western
University. He is a Chartered Accountant, a Chartered Professional Accountant and a member of the Institute of Corporate Directors. 
 Jessica McDonald 

Public Directorships (other than Hydro One and Hydro One Inc.): Coeur Mining Inc. and Trevali Mining Corporation 

Public Board Interlocks: None 
 Ms. McDonald is
Interim President and CEO of Canada Post Corporation, a Crown corporation which functions as the primary postal operator in Canada. Previous roles include President and CEO of British Columbia Hydro & Power Authority, a Canadian electric
utility in the province of British Columbia, and Executive Vice President of HB Global Advisors Corp., as well as a successful practice in mediation and negotiation on major commercial and industrial projects. In addition, Ms. McDonald has held
many positions with the British Columbia government, including the most senior public service position in the provincial government as Deputy Minister to the Premier, Cabinet Secretary and Head of the BC Public Service, responsible for overseeing
all aspects of government operations. 
 Ms. McDonald also serves on the boards of Canada Post Corporation, Coeur Mining Inc. and Trevali Mining
Corporation, and is on the Member Council of Sustainable Development Technology Canada. Previous directorships include Powertech Labs (Chair) and Powerex Corp. 

Ms. McDonald has a Bachelor of Arts (Political Science) from the University of British Columbia. She is also a member of the Institute of Corporate
Directors of Canada. 
 Russel Robertson (provincial nominee) 

Public Directorships (other than Hydro One and Hydro One Inc.): Bausch Health Companies Inc. and Turquoise Hill Resources Ltd. 

Public Board Interlocks: None 
 Mr. Robertson is a
corporate director and former Executive Vice President and Head, Anti-Money Laundering, BMO Financial Group, a major Canadian bank. Mr. Robertson has served as Chief Financial Officer, BMO Financial Group and Executive Vice President, Business
Integration where he oversaw the integration of Harris Bank and M&I Bank forming BMO Harris Bank. Before joining BMO, he spent over 35 years as a Chartered Professional Accountant holding various senior positions including the positions of
Vice-Chair, Deloitte & Touche LLP (Canada) and Canadian Managing Partner, Arthur Andersen LLP (Canada). 

  

					
		  	21	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Mr. Robertson also serves on the boards of Bausch Health Companies Inc. and Turquoise Hill Resources Ltd. Previous directorships include Virtus
Investment Partners, Inc. 
 Mr. Robertson has a Bachelor of Arts (Honours) in Business Administration from the Ivey School of Business at the
University of Western Ontario. He is a Chartered Professional Accountant (FCPA, FCA) and a Fellow of the Institute of Chartered Accountants (Ontario). He is also a member of the Institute of Corporate Directors. 

William Sheffield 
 Public Directorships (other than Hydro One
and Hydro One Inc.): Houston Wire & Cable Company, Velan Inc. 
 Public Board Interlocks: None 

Mr. Sheffield is a corporate director. He is the former CEO of Sappi Fine Papers, headquartered in South Africa. Previously, he held senior roles
with Abitibi-Consolidated, Inc. and Abitibi-Price, Inc. He began his career in the steel industry and held General Manager, Industrial Engineering and Cold Mill Operating roles at Stelco Inc. 

Mr. Sheffield also serves on the boards of Houston Wire & Cable Company, Velan, Inc., Burnbrae Farms Ltd., Longview Aviation Capital and
Family Enterprise Xchange. Previous directorships include Canada Post Corporation, Ontario Power Generation, Corby Distilleries, Royal Group Technologies and SHAD. 

Mr. Sheffield has a Bachelor of Science (Chemistry) from Carleton University and an MBA from McMaster University. He holds a professional director
certification from the Institute of Corporate Directors (ICD.D) and a similar designation from the National Association of Corporate Directors in the US. He also completed the Family Enterprise Advisors Program (FEA) at the University of British
Columbia. 
 Melissa Sonberg 
 Public Directorships (other than
Hydro One and Hydro One Inc.): Exchange Income Corporation 
 Public Board Interlocks: None 

Ms. Sonberg is a corporate director and Adjunct Professor and
Executive-in-Residence at McGill University’s Desautel Faculty of Management, a public research university in Montreal, Quebec. She spent the early part of her
career in the healthcare industry before joining Air Canada, where she held leadership positions in a range of customer facing, operational and corporate functions. Ms. Sonberg was part of the founding executive team of Aeroplan, now part of
AIMIA, a marketing and loyalty analytics company. Ms. Sonberg held positions of Senior Vice President, Human Resources & Corporate Affairs and Senior Vice President, Global Brands, Communications and External Affairs at AIMIA. 

Ms. Sonberg also serves on the boards of Exchange Income Corporation, MD Financial Holdings, Inc., Canadian Professional Sales
Association, Groupe Touchette, Women in Capital Markets and Equitas - International Centre for Human Rights. Previous directorships include Rideau, Inc., Via Rail Canada, University of Ottawa, International Advisory Board
and the McGill University Health Centre. 
 Ms. Sonberg has a Bachelor of Science (Psychology) from McGill University and a Masters of Health
Administration from the University of Ottawa. She is a Certified Human Resource Executive and holds a professional director certification from the Institute of Corporate Directors (ICD.D). 

Information Regarding Certain Directors and Executive Officers 

As at November 1, 2018, the directors and executive officers of Hydro One and its subsidiaries beneficially owned, controlled or directed, directly
or indirectly, as a group, 15,905 common shares, which represented approximately 0.003% of the outstanding common shares. 
 As at November 1,
2018, approximately 36.4% of the executives (those who hold a vice president role and above or equivalent) (12 out of 33) across Hydro One and its major subsidiaries, including 1 of 5 executive officers, are women. 

Corporate Cease Trade Orders and Bankruptcies 
 Except as
described below: 
  

	•	 none of the directors or executive officers of Hydro One or Hydro One Inc. nor any shareholder holding shares
sufficient to materially affect control of Hydro One or Hydro One Inc. is, or within the last 10 years has served as, a director or executive officer of any company that, during such service or within a year after the end of such service, became
bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its
assets; 

  

	•	 none of the directors or executive officers of Hydro One or Hydro One Inc. is, or within the last 10 years has served
as, a director, CEO, or chief financial officer of any company that, during such service or as a result of an event that occurred during such service, was subject to an order (including a cease trade order, or similar order or an order that denied
access to any exemption under securities legislation), for a period of more than 30 consecutive days; or 

  

	•	 none of the directors or executive officers of Hydro One or Hydro One Inc. nor any shareholder holding shares
sufficient to materially affect control of Hydro One or Hydro One Inc., within the last 10 years has become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings,
arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the director. 

  

					
		  	22	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Blair Cowper-Smith was serving as the Corporate Secretary of Stelco Inc. (Stelco) in 2004. On January 29, 2004, Stelco filed for and was granted
Court bankruptcy protection under the Companies’ Creditors Arrangement Act (CCAA). Stelco emerged from Court protection under the CCAA on March 31, 2006. Blair also served as a Director of Golfsmith International Holdings GP Inc.
and Golf Town Canada Inc. (Golf Town) from 2016 to 2018. On September 14, 2016, Golf Town filed for and was granted Court bankruptcy protection under the CCAA. Golf Town emerged from Court protection after being sold to Fairfax Financial
Holdings Limited and CI Investments Inc. in October 2016. 
 Penalties or Sanctions 

None of the directors or executive officers of Hydro One or Hydro One Inc., nor any shareholder holding shares sufficient to materially affect control of
Hydro One or Hydro One Inc., has been subject to any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory
authority or been subject to any other penalties or sanctions imposed by a court or regulatory body that would likely be considered important to a reasonable investor making an investment decision. 

Conflicts of Interest 
 To the best of Hydro One’s and Hydro
One Inc.’s knowledge, there are no existing material potential conflicts of interest among Hydro One or any of its subsidiaries and the directors or executive officers of Hydro One or any of its subsidiaries as a result of their outside
business interests as at the date hereof. Certain of the directors and executive officers serve as directors and executive officers of other public companies. Accordingly, conflicts of interest may arise which could influence these persons in
evaluating possible acquisitions or in generally acting on behalf of Hydro One or Hydro One Inc. Where conflicts arise, they are managed through a variety of measures, including declaration of the conflict, recusal from meetings and/or portions of
meetings, and the creation of separate board materials for the affected directors. 
 Interest of Management and Others in Material Transactions 

There are no material interests, direct or indirect, of any director or executive officer of Hydro One and its subsidiaries, or any associate or affiliate
of any of the foregoing persons, in any transaction within the three years before the date hereof that has materially affected or is reasonably expected to materially affect Hydro One or Hydro One Inc. 

Indebtedness of Directors and Executive Officers 
 No director,
executive officer, employee, former director, former executive officer or former employee or associate of any director or executive officer of Hydro One or any of its subsidiaries had any outstanding indebtedness to Hydro One or any of its
subsidiaries except routine indebtedness or had any indebtedness that was the subject of a guarantee, support agreement, letter of credit or other similar arrangement or understanding provided by Hydro One or any of its subsidiaries. 

Independence Matters 
 The Board of Hydro One and Hydro One Inc.
currently consists of 10 directors, all of whom are independent of Hydro One and Hydro One Inc. and independent of the Province within the meaning of the Governance Agreement. 

For Hydro One’s purposes, an independent director is one who is independent of Hydro One and independent of the Province. Directors will be
independent of Hydro One if they are independent within the meaning of all Canadian securities laws governing the disclosure of corporate governance practices and stock exchange requirements imposing a number or percentage of independent directors.
Pursuant to Canadian securities laws, a director who is “independent” within the meaning of applicable securities laws is one who is free from any direct or indirect relationship which could, in the view of the board, be reasonably
expected to interfere with a director’s independent judgement, with certain specified relationships deemed to be non-independent. A director will be “independent of the Province” if he or she is
independent of Hydro One under Ontario securities laws governing the disclosure of corporate governance practices, where the Province and certain specified provincial entities are treated as Hydro One’s parent under that definition, but
excluding current directors where the relationship ended before August 31, 2015. The Governance Agreement requires each of the directors, other than the CEO, to be both independent of Hydro One and independent of the Province. The Chair of
Hydro One is independent of Hydro One and the Province. 

  

					
		  	23	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

The following table summarizes the committee memberships and independence status of Board members: 

 

													
	  	  	  	  	Committees	  	  	  	  	  	Independence
	 	  	 	  	 	  	 	  	Health, Safety,	  	 	  	 
	 	  	 	  	 	  	Human	  	Environment and	  	Independent	  	Independent
	 	  	Audit	  	Governance	  	Resources	  	  Indigenous Peoples  	  	of	  	of
	  Director	  	Committee	  	Committee	  	Committee	  	Committee	  	Hydro One	  	the Province
	 Cherie Brant
	  		  	v	  		  	v	  	v	  	v
	 Blair Cowper-Smith
	  		  	v	  	v	  	 	  	v	  	v
	 Anne Giardini
	  	v	  		  		  	v	  	v	  	v
	 David Hay
	  	v	  		  		  	v	  	v	  	v
	 Timothy Hodgson
	  		  	v	  	v	  	 	  	v	  	v
	 Jessica McDonald
	  	v	  		  	v	  	 	  	v	  	v
	 Russel Robertson
	  	v	  		  	v	  	 	  	v	  	v
	 William Sheffield
	  	v	  		  		  	v	  	v	  	v
	 Melissa Sonberg
	  		  	v	  	v	  	 	  	v	  	v
	 Tom Woods
	  	 	  	 	  	 	  	 	  	v	  	v

 Diversity Policy 
 The Board has
adopted a board diversity policy which formalizes the company’s commitment to diversity and its desire to maintain a board comprising talented and dedicated directors whose skills, experience, knowledge and backgrounds reflect the diverse
nature of the business environment in which it operates, including an appropriate number of female directors. The Board aspires towards a board composition in which each gender comprises at least 40% of the directors on the Board. Currently, the
Board includes four female directors (40%). 
 Director Attendance 

Directors are expected to attend board meetings, meetings of the committees on which they serve and the annual meeting of shareholders. 

Number of Board and Committee Meetings (August 13, 2018 to November 1, 2018)1: 

 

							
	  	  	Regular	  	Non-Regular	  	In Camera Sessions
	 Board
	  	1	  	5	  	5
	 Audit Committee
	  	1	  	2	  	3
	 Health, Safety, Environment and Indigenous Peoples Committee
	  	1	  	—	  	1
	 Human Resources Committee
	  	1	  	2	  	3
	 Governance Committee
	  	1	  	—	  	1

  

	1	 All of the current directors were appointed directors of Hydro One effective August 13, 2018. The directors of
Hydro One are also directors of Hydro One Inc. and the two boards and each committee thereof hold joint meetings. 

 Audit Committee 

The Audit Committee must consist of at least three directors, all of whom are persons determined by Hydro One to be both “independent” (within
the meaning of all Canadian securities laws and stock exchange requirements and the Governance Agreement) and “financially literate” (within the meaning of other applicable requirements or guidelines for audit committee service under
securities laws or the rules of any applicable stock exchange, including National Instrument 52-110 - Audit Committees). At least one member of the Audit Committee will qualify as an “audit
committee financial expert” as defined by the applicable rules of the US Securities and Exchange Commission. The Audit Committee comprises William Sheffield (Chair), Anne Giardini, David Hay, Jessica McDonald and Russel Robertson. Each of the
Audit Committee members is independent and financially literate and each has an understanding of the accounting principles used to prepare Hydro One’s financial statements and varied experience as to the general application of such accounting
principles, as well as an understanding of the internal controls and procedures necessary for financial reporting. Russel Robertson and David Hay each qualify as an audit committee financial expert.  

Please refer to the biographies of our Audit Committee members described under “- Directors and Executive Officers” above for details of their
additional invaluable skills and experience. 
 Human Resource Committee 

Hydro One’s management team, the Human Resources Committee and the company’s compensation advisors all play a key role in determining executive
compensation for the company’s directors and executives and in managing compensation risk on behalf of the Board of Hydro One. The Human Resources Committee is responsible for assisting the Board in fulfilling its oversight responsibilities
relating to the attraction and retention of key senior management. 

  

					
		  	24	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

All of the members of the Human Resources Committee are independent. The Human Resources Committee comprises Melissa Sonberg (Chair), Blair Cowper-Smith,
Timothy Hodgson, Jessica McDonald and Russel Robertson. All of the members of the Human Resources Committee have gained the following relevant experience in human resources and compensation by serving as an executive officer (or equivalent) of a
major organization and/or through prior service on the compensation committee of a stock exchange listed company or otherwise: 
  

	•	 human resources experience (experience with benefit, pension and compensation programs (in particular, executive
compensation)); 

  

	•	 risk management experience (knowledge and experience with internal risk controls, risk assessments and reporting as it
pertains to executive compensation); and 

  

	•	 executive leadership experience (experience as a senior executive/officer of a public company or major organization).
Please refer to the biographies of our Human Resources Committee members described under “- Directors and Executive Officers” above for details of their additional invaluable skills and experience. 

CEO Selection Committee 
 The Board has also formed an Ad-hoc CEO Selection Committee to identify and select a President and CEO. 
 Compensation Policies and Practices 

Other than as set forth in Hydro One’s management information circular dated March 19, 2018 prepared in connection with the annual meeting of
shareholders held on May 15, 2018 or as otherwise described below, there have been no material changes to the policies and practices adopted by the Board of Hydro One or Hydro One Inc. to determine compensation for Hydro One’s or Hydro One
Inc.’s directors and executive officers since January 1, 2018. 
 Changes to Hydro One’s Board and CEO Compensation 

As disclosed under “- Directors and Executive Officers” above, on July 11, 2018, Hydro One, on behalf of itself and Hydro One Inc.,
announced that it had entered into the Letter Agreement for the purpose of the orderly replacement of the Board of Hydro One and Hydro One Inc. and the retirement of Mayo Schmidt as the CEO effective July 11, 2018. In accordance with the Letter
Agreement, Hydro One has agreed to consult with the Province in respect of future matters of executive compensation. In addition, the then-existing Hydro One and Hydro One Inc. Board volunteered and agreed to immediately reduce board compensation to
the levels contemplated by the pre-January 1, 2018 director compensation policy. The then-existing Hydro One and Hydro One Inc. Board also volunteered and agreed to forego any compensation for their service
after June 30, 2018. 
 In connection with Mr. Schmidt’s retirement, he received amounts consistent with Hydro One’s retirement
policies applicable to his outstanding equity awards and his employment agreement as previously disclosed and was not entitled to severance. Mr. Schmidt received a $0.4 million lump sum payment in lieu of all post-retirement benefits and
allowances. 
 Bill 2 
 On July 16, 2018, the Legislative
Assembly of Ontario introduced Bill 2 (Bill 2) titled the Urgent Priorities Act, 2018. As an omnibus bill, among other matters, Bill 2, as proposed, would amend the Ontario Energy Board Act, 1998 (OEB Act) and enact the Hydro One
Accountability Act (Act), and would require the Board of Hydro One to establish a new compensation framework for the Board and certain executives of Hydro One and its subsidiaries (excluding subsidiaries incorporated outside Canada) in
consultation with the Province and the other five largest shareholders of Hydro One, which compensation framework is subject to approval by the Management Board of Cabinet. The Act provides the Management Board of Cabinet with the authority to issue
directives governing the compensation of directors and certain executives of Hydro One and its subsidiaries (excluding subsidiaries incorporated outside Canada). The introduction of Bill 2 may adversely impact Hydro One and Hydro One
Inc.’s ability to continue to attract and retain executives. 
 The Act also requires Hydro One to annually provide public disclosure concerning
compensation paid to certain executives, and provides that the OEB Act will be amended so that the rates charged by Hydro One and its subsidiaries shall not reflect amounts paid for compensation of the CEO and certain executives of Hydro One and its
subsidiaries. The impact of this amendment is expected to restrict Hydro One’s ability to recover certain amounts paid for executive compensation through separate rate mechanisms, which is estimated to result in a reduction in Hydro One’s
net income for the year ending December 31, 2018 of up to $9 million, and is subject to a final determination by the OEB. The reduction may be materially lower, depending on the determination by the OEB of the executives whose compensation
is to be excluded. Bill 2 expressly provides that certain causes of action and proceedings are not available or will be barred against the Province, Hydro One or any of its subsidiaries, or any of its current or former officers, directors, employees
or agents in respect of the Act, the Province’s involvement in compensation matters or other aspects of the corporate governance of Hydro One or any of its subsidiaries or any alleged misrepresentation in any prospectus, document or other
public statement related to the involvement of the Province in compensation matters at Hydro One or any of its subsidiaries. Bill 2 received Royal Assent on July 25, 2018. 

  

					
		  	25	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Province of Ontario 
 Notwithstanding the Governance Agreement,
and in light of actions taken by the Province following the provincial election in June 2018 including the passage of Bill 2, the Province may elect to make further decisions relevant to Hydro One that could be detrimental to the interests of
shareholders. 
 NON-GAAP MEASURES 

FFO 
 FFO is defined as net cash from operating activities,
adjusted for (i) changes in non-cash balances related to operations, (ii) dividends paid on preferred shares, and (iii) distributions to noncontrolling interest. Management believes that FFO is
helpful as a supplemental measure of the Company’s operating cash flows as it excludes timing-related fluctuations in non-cash operating working capital and cash flows not attributable to common
shareholders. As such, FFO provides a consistent measure of the cash generating performance of the Company’s assets. 
  

																	
	 	  	Three months ended	 	 	Nine months ended	 
	 	  	September 30	 	 	September 30	 
	  (millions of dollars)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Net cash from operating activities
	  	 	508	 	 	 	442	 	 	 	1,176	 	 	 	1,193	 
	 Changes in non-cash balances related to operations
	  	 	(85	) 	 	 	(52	) 	 	 	54	 	 	 	1	 
	 Preferred share dividends
	  	 	(4	) 	 	 	(4	) 	 	 	(13	) 	 	 	(13	) 
	 Distributions to noncontrolling interest
	  	 	(1	) 	 	 	(1	) 	 	 	(6	) 	 	 	(4	) 
	 FFO
	  	 	418	 	 	 	385	 	 	 	1,211	 	 	 	1,177	 

 Adjusted Net Income and Adjusted EPS 

The following basic and diluted Adjusted EPS has been calculated by management on a supplementary basis which excludes income related to the Avista
Corporation acquisition from net income. Adjusted EPS is used internally by management to assess the Company’s performance and is considered useful because it excludes the impact of acquisition-related costs and loss or gain on the
deal-contingent foreign exchange forward contract. It provides users with a comparative basis to evaluate the current ongoing operations of the Company compared to prior year. 
  

																	
	 	  	Three months ended September 30	 	 	Nine months ended September 30	 
	  (millions of dollars, except number of shares and EPS)	  	2018	 	 	2017	 	 	2018	 	 	2017	 
	 Net income attributable to common shareholders
	  	 	194	 	 	 	219	 	 	 	616	 	 	 	503	 
					
	 Impacts related to Avista Corporation acquisition:
	  				 				 				 			
	 Avista Corporation-related costs (before tax)
	  	 	40	 	 	 	24	 	 	 	24	 	 	 	27	 
	 Tax impact
	  	 	(7	) 	 	 	(6	) 	 	 	(9	) 	 	 	(6	) 
	 Avista Corporation-related costs (after tax)
	  	 	33	 	 	 	18	 	 	 	15	 	 	 	21	 
	     
	  	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 Adjusted net income attributable to common shareholders
	  	 	227	 	 	 	237	 	 	 	631	 	 	 	524	 
					
	 Weighted average number of shares
	  				 				 				 			
	 Basic
	  	 	595,882,438	 	 	 	595,386,308	 	 	 	595,714,016	 	 	 	595,254,201	 
	 Effect of dilutive stock-based compensation plans
	  	 	1,968,856	 	 	 	2,130,453	 	 	 	2,128,211	 	 	 	2,172,635	 
	 Diluted
	  	 	597,851,294	 	 	 	597,516,761	 	 	 	597,842,227	 	 	 	597,426,836	 
					
	 Adjusted EPS
	  				 				 				 			
	 Basic
	  	 	$0.38	 	 	 	$0.40	 	 	 	$1.06	 	 	 	$0.88	 
	 Diluted
	  	 	$0.38	 	 	 	$0.40	 	 	 	$1.06	 	 	 	$0.88	 

  

					
		  	26	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

Revenues, Net of Purchased Power 
 Revenues, net of purchased
power is defined as revenues less the cost of purchased power. Management believes that revenue, net of purchased power is helpful as a measure of net revenues for the Distribution segment, as purchased power is fully recovered through revenues.

  

																	
	 	  	 Three months ended

September 30
	 	  	 Nine months ended

September 30
	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Revenues
	  	 	1,606	 	  	 	1,522	 	  	 	4,659	 	  	 	4,551	 
	 Less: Purchased power
	  	 	733	 	  	 	675	 	  	 	2,158	 	  	 	2,213	 
	 Revenues, net of purchased power
	  	 	873	 	  	 	847	 	  	 	2,501	 	  	 	2,338	 
			
	 	  	Three months ended
September 30	 	  	Nine months ended
September 30	 
	  (millions of dollars)	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Distribution revenues
	  	 	1,103	 	  	 	1,040	 	  	 	3,284	 	  	 	3,317	 
	 Less: Purchased power
	  	 	733	 	  	 	675	 	  	 	2,158	 	  	 	2,213	 
	 Distribution revenues, net of purchased power
	  	 	370	 	  	 	365	 	  	 	1,126	 	  	 	1,104	 

 FFO, basic and diluted Adjusted EPS, Adjusted Net Income, Revenues, Net of Purchased Power, and Distribution Revenues, Net
of Purchased Power are not recognized measures under US GAAP and do not have a standardized meaning prescribed by US GAAP. They are therefore unlikely to be directly comparable to similar measures presented by other companies. They should
not be considered in isolation nor as a substitute for analysis of the Company’s financial information reported under US GAAP. 
 RELATED PARTY
TRANSACTIONS 
 The Province is a shareholder of Hydro One with approximately 47.4% ownership at September 30, 2018. 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. The following is a summary of the Company’s related
party transactions during the three and nine months ended September 30, 2018 and 2017: 
  

																			
	 (millions of dollars)

 
	  	 	  	Three months ended
September 30	 	  	Nine months ended
September 30	 
	  Related Party	  	Transaction	  	2018	 	  	2017	 	  	2018	 	  	2017	 
	 Province
	  	Dividends paid	  	 	69	 	  	 	69	 	  	 	205	 	  	 	231	 
	 IESO
	  	Power purchased	  	 	321	 	  	 	276	 	  	 	1,079	 	  	 	1,169	 
		  	Revenues for transmission services	  	 	474	 	  	 	390	 	  	 	1,293	 	  	 	1,124	 
		  	Amounts related to electricity rebates	  	 	113	 	  	 	181	 	  	 	353	 	  	 	321	 
		  	Distribution revenues related to rural rate protection	  	 	59	 	  	 	61	 	  	 	177	 	  	 	185	 
		  	Distribution revenues related to the supply of electricity to remote northern communities	  	 	8	 	  	 	8	 	  	 	24	 	  	 	24	 
	 	  	Funding received related to Conservation and Demand Management programs	  	 	11	 	  	 	18	 	  	 	33	 	  	 	44	 
	 OPG
	  	Power purchased	  	 	2	 	  	 	2	 	  	 	8	 	  	 	7	 
		  	Revenues related to provision of construction and equipment maintenance services	  	 	2	 	  	 	2	 	  	 	6	 	  	 	6	 
	 	  	Costs related to the purchase of services	  	 	—	 	  	 	—	 	  	 	—	 	  	 	1	 
	 OEFC
	  	Power purchased from power contracts administered by the OEFC	  	 	1	 	  	 	—	 	  	 	2	 	  	 	1	 
	 OEB
	  	OEB fees	  	 	2	 	  	 	2	 	  	 	6	 	  	 	6	 

 DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROL OVER FINANCIAL REPORTING 

Management is responsible for establishing and maintaining adequate disclosure controls and procedures and internal control over financial reporting as
defined in National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings. Internal control, no matter how well designed and operated, can provide only reasonable assurance
of achieving the desired control objectives and due to its inherent limitations, may not prevent or detect all misrepresentations. 
 There were no
changes in the Company’s internal control over financial reporting during the three months ended September 30, 2018 that materially affected, or are reasonably likely to materially affect, the Company’s disclosure controls and
procedures and internal control over financial reporting. 

  

					
		  	27	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

NEW ACCOUNTING PRONOUNCEMENTS 
 The following tables present
Accounting Standards Codification (ASC) guidance issued by the FASB that are applicable to Hydro One: 
 Recently Adopted Accounting Guidance 

 

									
	Guidance	  	Date issued	  	Description	  	Effective date	  	Impact on Hydro One
	ASC 606	  	May 2014 – November 2017	  	ASC 606 Revenue from Contracts with Customers replaced ASC 605 Revenue Recognition. ASC 606 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.	  	January 1, 2018	  	Hydro One adopted ASC 606 on January 1, 2018 using the retrospective method, without the election of any practical expedients and there was no material impact to the Company’s
revenue recognition policy upon adoption. The Company has included the disclosure requirements of ASC 606 for interim periods in the year of adoption.
	ASU 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 applied for a regulatory asset to maintain the capitalization of post-employment benefit related costs and as such, there is no material impact upon adoption. See Note 2 -
Significant Accounting Policies and Note 11 - Regulatory Assets and Liabilities in the Hydro One financial statements for the three and nine months ended September 30, 2018.
			
	Recently Issued Accounting Guidance Not Yet Adopted	  		  	
					
	Guidance	  	Date issued	  	Description	  	Effective date	  	Anticipated impact on Hydro One
	2016-02 2018-01 2018-10
2018-11	  	February 2016 – July 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 ASC 842 land easements that exist or expired before the
entity’s adoption of ASC 842 and that were not previously accounted for as leases under ASC 840. ASU 2018-10 amends narrow aspects of ASC 842. ASU 2018-11 provides
entities with an additional and option transition method in adopting ASC 842. ASU 2018-11 also permits lessors to elect an optional practical expedient to not separate
non-lease components from the associated lease component by underlying asset classes.	  	January 1, 2019	  	The Company has reviewed a substantial number of existing leases and relevant contracts and continues its assessment activities. No quantitative determination has been made at this time. The
Company is on track for implementation of this standard by the effective date.
	2018-07	  	June 2018	  	Expansion in the scope of ASC 718 to include share-based payment transactions for acquiring goods and services from non-employees. Previously, ASC 718
was only applicable to share-based payment transactions for acquiring goods and services from employees.	  	January 1, 2019	  	Under assessment
	2018-13	  	August 2018	  	Disclosure requirements on fair value measurements in ASC 820 are modified to improve the effectiveness of disclosures in financial statement notes.	  	January 1, 2020	  	Under assessment
	2018-14	  	August 2018	  	Disclosure requirements related to single-employer defined benefit pension or other post-retirement benefit plans are added, removed or clarified to improve the effectiveness of disclosures in
financial statement notes.	  	January 1, 2021	  	Under assessment
	2018-15	  	August 2018	  	The amendment aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing
implementation costs incurred to develop or obtain internal-use software. The accounting for the service element of a hosting arrangement is not affected by the amendment.	  	January 1, 2020	  	Under assessment

  

					
		  	28	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

FORWARD-LOOKING STATEMENTS AND INFORMATION 
 The Company’s
oral and written public communications, including this document, often contain forward-looking statements that are based on current expectations, estimates, forecasts and projections about the Company’s business and the industry, regulatory and
economic environments in which it operates, and include beliefs and assumptions made by the management of the Company. Such statements include, but are not limited to, statements regarding: the Company’s transmission and distribution rate
applications, including resulting decisions, rates and expected impacts and timing; the Company’s liquidity and capital resources and operational requirements; expectations regarding credit ratings; the Operating Credit Facilities; the
Acquisition Credit Facilities; expectations regarding the Company’s financing activities; the Company’s maturing debt; ongoing and planned projects, including expected results, costs and completion dates; expected future capital
investments, including expected timing and investment plans; contractual obligations and other commercial commitments; the OEB and applications before the OEB; the Company’s share capital and conversion of outstanding stock options and
convertible debentures; NRLP and the Niagara Reinforcement Project, the Lake Superior Link Project, and related regulatory applications; collective agreements; the pension plan, future pension contributions, valuations and expected impacts; impacts
of OEB treatment of post-employment benefit costs; dividends; estimated ETR; non-GAAP measures; internal control over financial reporting; recent accounting-related guidance; the Universal Base Shelf Prospectus; expectations relating to filing of a
future base shelf prospectus by Hydro One Holdings Limited; the convertible debentures; the Exemptive Relief; the status of the Company’s acquisitions and mergers, including Orillia Power, Peterborough Distribution and Avista Corporation; the
Company’s financing strategy and foreign currency hedging relating to the acquisition of Avista Corporation; class action litigation, including litigation relating to the Merger; the risk that the Company may fail to complete the Merger; the
Agreement with the Province; changes to Hydro One’s Board and CEO, and Bill 2 and its anticipated impacts, including expectations relating to executive compensation; and the potential of government intervention in Hydro One’s business.
Words such as “expect”, “anticipate”, “intend”, “attempt”, “may”, “plan”, “will”, “believe”, “seek”, “estimate”, “goal”, “aim”,
“target”, and variations of such words and similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and involve assumptions and risks and uncertainties that are
difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed, implied or forecasted in such forward-looking statements. Hydro One does not intend, and it disclaims any obligation, to update any
forward-looking statements, except as required by law. 
 These forward-looking statements are based on a variety of factors and assumptions including,
but not limited to, the following: no unforeseen changes in the legislative and operating framework for Ontario’s electricity market or for Hydro One specifically; favourable decisions from the OEB and other regulatory bodies concerning
outstanding and future rate and other applications; no unexpected delays in obtaining the required approvals; no unforeseen changes in rate orders or rate setting methodologies for the Company’s distribution and transmission businesses;
continued use of US GAAP; a stable regulatory environment; no unfavourable changes in environmental regulation; no significant changes to the Company’s current credit ratings; no unforeseen impacts of new accounting pronouncements; and no
significant event occurring outside the ordinary course of business. These assumptions are based on information currently available to the Company, including information obtained from third party sources. Actual results may differ materially from
those predicted by such forward-looking statements. While Hydro One does not know what impact any of these differences may have, the Company’s business, results of operations, financial condition and credit stability may be materially adversely
affected. Factors that could cause actual results or outcomes to differ materially from the results expressed or implied by forward-looking statements include, among other things: 

Risks Related to the Avista Corporation Merger: 
  

	•	 risks relating to the Merger, including (i) the risk that Hydro One may fail to complete the Merger, (ii) uncertainty
regarding the length of time required to complete the Merger, (iii) the risk that the purchase price for Avista Corporation could increase, (iv) the risk that the anticipated benefits of the Merger may not materialize or may not occur within the
time periods contemplated by Hydro One; 

  

	•	 risks related to the financing of the Merger; and 

 

	•	 risks associated with the Province’s share ownership of Hydro One and other relationships with the Province,
including potential conflicts of interest that may arise between Hydro One, the Province and related parties. 

  

	Risks	 Related to the Business: 

 

	•	 risks associated with the Province’s share ownership of Hydro One and other relationships with the Province,
including potential conflicts of interest that may arise between Hydro One, the Province and related parties; 

  

	•	 risks associated with the Province exercising further legislative and regulatory powers in the implementation of Bill
2; 

  

	•	 regulatory risks and risks relating to Hydro One’s revenues, including risks relating to rate orders, actual
performance against forecasts and capital expenditures, or denials of applications; 

  

	•	 the risk that the Company may be unable to comply with regulatory and legislative requirements or that the Company may
incur additional costs for compliance that are not recoverable through rates; 

  

	•	 the risk of exposure of the Company’s facilities to the effects of severe weather conditions, natural disasters or
other unexpected occurrences for which the Company is uninsured or for which the Company could be subject to claims for damage; 

  

	•	 public opposition to and delays or denials of the requisite approvals and accommodations for the Company’s planned
projects; 

  

					
		  	29	  	 

 HYDRO ONE LIMITED 

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued) 

For the three and nine months ended September 30, 2018 and 2017 
  

 

	•	 the risk that Hydro One may incur significant costs associated with transferring assets located on reserves (as defined
in the Indian Act (Canada)); 

  

	•	 the risks associated with information system security and maintaining a complex IT system infrastructure;

  

	•	 the risks related to the Company’s work force demographic and its potential inability to attract and retain
qualified personnel; 

  

	•	 the risk of labour disputes and inability to negotiate appropriate collective agreements on acceptable terms consistent
with the Company’s rate decisions; 

  

	•	 risk that the Company is not able to arrange sufficient cost-effective financing to repay maturing debt and to fund
capital expenditures; 

  

	•	 the risk of a credit rating downgrade and its impact on the Company’s funding and liquidity;

  

	•	 risks associated with fluctuations in interest rates and failure to manage exposure to credit risk;

  

	•	 the risk that the Company may not be able to execute plans for capital projects necessary to maintain the performance
of the Company’s assets or to carry out projects in a timely manner; 

  

	•	 the risk of non-compliance with environmental regulations or failure to
mitigate significant health and safety risks and inability to recover environmental expenditures in rate applications; 

  

	•	 the risk that assumptions that form the basis of the Company’s recorded environmental liabilities and related
regulatory assets may change; 

  

	•	 the risk of not being able to recover the Company’s pension expenditures in future rates and uncertainty regarding
the future regulatory treatment of pension, other post-employment benefits and post-retirement benefits costs; 

  

	•	 the potential that Hydro One may incur significant expenses to replace functions currently outsourced if agreements are
terminated or expire before a new service provider is selected; 

  

	•	 the risks associated with economic uncertainty and financial market volatility; 

 

	•	 the inability to prepare financial statements using US GAAP; 

 

	•	 the impact of the ownership by the Province of lands underlying the Company’s transmission system; and

  

	•	 the risk related to the impact of the new accounting pronouncements. 

Hydro One cautions the reader that the above list of factors is not exhaustive. Some of these risks and other factors are discussed in additional detail
under the section “Other Developments - Avista Corporation Merger” and under the section “Hydro One Board of Directors and Executive Officers - Province of Ontario” in this MD&A, and in the section “Risk Management and
Risk Factors” in the 2017 MD&A. 
 In addition, Hydro One cautions the reader that information provided in this MD&A regarding the
Company’s outlook on certain matters, including potential future investments, is provided in order to give context to the nature of some of the Company’s future plans and may not be appropriate for other purposes. 

Additional information about Hydro One, including the Company’s Annual Information Form, is available on SEDAR at www.sedar.com 

and the Company’s website at www.HydroOne.com/Investors. 

  

					
		  	30

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