10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 2019

or

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

Commission file number 1-15226

ENCANA CORPORATION

(Exact name of registrant as specified in its charter)

Canada	98-0355077
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

Suite 4400, 500 Centre Street S.E., P.O. Box 2850, Calgary, Alberta, Canada, T2P 2S5

(Address of principal executive offices)

Registrant’s telephone number, including area code (403) 645-2000

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  ☒    No  ☐

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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated  filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  

Yes ☐    No  ☒

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Shares	ECA	New York Stock Exchange

Number of registrant’s common shares outstanding as of October 25, 2019 1,299,112,236

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ENCANA CORPORATION

FORM 10-Q

TABLE OF CONTENTS

	PART I
Item 1.	Financial Statements	6
	Condensed Consolidated Statement of Earnings	6
	Condensed Consolidated Statement of Comprehensive Income	6
	Condensed Consolidated Balance Sheet	7
	Condensed Consolidated Statement of Changes in Shareholders’ Equity	8
	Condensed Consolidated Statement of Cash Flows	10
	Notes to Condensed Consolidated Financial Statements	11
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	42
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	69
Item 4.	Controls and Procedures	71
	PART II
Item 1.	Legal Proceedings	72
Item 1A.	Risk Factors	72
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	79
Item 3.	Defaults Upon Senior Securities	79
Item 4.	Mine Safety Disclosures	79
Item 5.	Other Information	79
Item 6.	Exhibits	79
Signatures		80

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DEFINITIONS

Unless the context otherwise indicates, references to “us,” “we,” “our,” “ours,” “Encana” and the “Company” refer to Encana Corporation and its consolidated subsidiaries. In addition, the following are other abbreviations and definitions of certain terms used within this Quarterly Report on Form 10-Q:

“AECO” means Alberta Energy Company and is the Canadian benchmark price for natural gas.

“ASU” means Accounting Standards Update.

“bbl” or “bbls” means barrel or barrels.

“BOE” means barrels of oil equivalent.

“Btu” means British thermal units, a measure of heating value.

“DD&A” means depreciation, depletion and amortization expenses.

“FASB” means Financial Accounting Standards Board.

“Mbbls/d” means thousand barrels per day.

“MBOE/d” means thousand barrels of oil equivalent per day.

“Mcf” means thousand cubic feet.

“MD&A” means Management’s Discussion and Analysis of Financial Condition and Results of Operations.

“MMBOE” means million barrels of oil equivalent.

“MMBtu” means million Btu.

“MMcf/d” means million cubic feet per day.

“NCIB” means normal course issuer bid.

“NGL” or “NGLs” means natural gas liquids.

“NYMEX” means New York Mercantile Exchange.

“NYSE” means New York Stock Exchange.

“OPEC” means Organization of the Petroleum Exporting Countries.

“SEC” means United States Securities and Exchange Commission.

“SIB” means substantial issuer bid.

“TSX” means Toronto Stock Exchange.

“U.S.”, “United States” or “USA” means United States of America.

“U.S. GAAP” means U.S. Generally Accepted Accounting Principles.

“WTI” means West Texas Intermediate.

CONVERSIONS

In this Quarterly Report on Form 10-Q, a conversion of natural gas volumes to BOE is on the basis of six Mcf to one bbl.  BOE is based on a generic energy equivalency conversion method primarily applicable at the burner tip and does not represent economic value equivalency at the wellhead. Given that the value ratio based on the current price of oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value, particularly if used in isolation.

CONVENTIONS

Unless otherwise specified, all dollar amounts are expressed in U.S. dollars, all references to “dollars”, “$” or “US$” are to U.S. dollars and all references to “C$” are to Canadian dollars. All amounts are provided on a before tax basis, unless otherwise stated. In addition, all information provided herein is presented on an after royalties basis.

The term “liquids” is used to represent oil, NGLs and condensate. The term “liquids rich” is used to represent natural gas streams with associated liquids volumes. The term “play” is used to describe an area in which hydrocarbon accumulations or

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prospects of a given type occur. Encana’s focus of development is on hydrocarbon accumulations known to exist over a large areal expanse and/or thick vertical section and are developed using hydraulic fracturing. This type of development typically has a lower geological and/or commercial development risk and lower average decline rate, when compared to conventional development.

The term “core asset” refers to plays that are the focus of the Company’s current capital investment and development plan. The Company continually reviews funding for development of its plays based on strategic fit, profitability and portfolio diversity and, as such, the composition of plays identified as a core asset may change over time.

References to information contained on the Company’s website at www.encana.com are not incorporated by reference into, and does not constitute a part of, this Quarterly Report on Form 10-Q.

FORWARD-LOOKING STATEMENTS AND RISK

This Quarterly Report on Form 10-Q contains certain forward-looking statements or information (collectively, “forward-looking statements”) within the meaning of applicable securities legislation, including the United States Private Securities Litigation Reform Act of 1995. Forward-looking statements include: composition of the Company’s core assets, including allocation of capital and focus of development plans; growth in long-term shareholder value; vision of being a leading North American energy producer; statements with respect to the Company’s strategic objectives including capital allocation strategy, focus of investment, growth of high margin liquids volumes, operating and capital efficiencies and ability to preserve balance sheet strength; ability to deliver free cash flow and balance growth with return of capital to shareholders; ability to lower costs and improve efficiencies to achieve competitive advantage; ability to repeat and deploy successful practices across the Company’s multi-basin portfolio; statements with respect to the expected synergies of the Newfield acquisition; anticipated commodity prices; success of and benefits from technology and innovation, including cube development approach and advanced completion designs; ability to optimize well and completion designs; future well inventory; anticipated drilling, number of drilling rigs and the success thereof; anticipated drilling costs and cycle times; anticipated proceeds and future benefits from various joint venture, partnership and other agreements; estimates of reserves and resources; expected production and product types; statements regarding anticipated cash flow, non-GAAP cash flow margin and leverage ratios; anticipated cash and cash equivalents; anticipated hedging and outcomes of risk management program, including exposure to certain commodity prices and foreign exchange fluctuations, amount of hedged production, market access and physical sales locations; impact of changes in laws and regulations; compliance with environmental legislation and claims related to the purported causes and impact of climate change, and the costs therefrom; adequacy of provisions for abandonment and site reclamation costs; financial flexibility and discipline; ability to meet financial obligations, manage debt and financial ratios, finance growth and comply with financial covenants; impact to the Company as a result of changes to its credit rating; access to the Company’s credit facilities; planned dividend and the declaration and payment of future dividends, if any; adequacy of the Company’s provision for taxes and legal claims; projections and expectation of meeting the targets contained in the Company’s corporate guidance and related statements in respect of funding; ability to manage cost inflation and expected cost structures, including expected operating, transportation and processing and administrative expenses; competitiveness and pace of growth of the Company’s assets within North America and against its peers; outlook of oil and gas industry generally and impact of geopolitical environment; expected future interest expense; the Company’s commitments and obligations and anticipated payments thereunder; the possible impact and timing of accounting pronouncements, rule changes and standards; the completion and timing of the Reorganization (as defined below) and the benefits thereof, including opportunities to enhance long-term value for shareholders, liquidity and capital market access; and the estimated tax impacts and other costs to the Company and shareholders as a result of the Reorganization.

Readers are cautioned against unduly relying on forward-looking statements which, by their nature, involve numerous assumptions, risks and uncertainties that may cause such statements not to occur, or results to differ materially from those expressed or implied. These assumptions include: future commodity prices and differentials; foreign exchange rates; ability to access credit facilities and shelf prospectuses; assumptions contained in the Company’s corporate guidance and as specified herein; data contained in key modeling statistics; availability of attractive hedges and enforceability of risk management program; effectiveness of the Company’s drive to productivity and efficiencies; results from innovations; expectation that counterparties will fulfill their obligations under the gathering, midstream and marketing agreements; access to transportation and processing facilities where Encana operates; assumed tax, royalty and regulatory regimes; receipt, timing and terms of securityholder, stock exchange, regulatory and court approvals required in connection with the Reorganization; director and officer support for the Reorganization; the applicability of certain U.S. and Canadian securities

4

regulations and exemptions to the Reorganization; and expectations and projections made in light of, and generally consistent with, Encana’s historical experience and its perception of historical trends, including with respect to the pace of technological development, benefits achieved and general industry expectations.

Risks and uncertainties that may affect these business outcomes include: ability to generate sufficient cash flow to meet obligations; commodity price volatility; ability to secure adequate transportation and potential pipeline curtailments; variability and discretion of Encana’s board of directors (the “Board of Directors”) to declare and pay dividends, if any; timing and costs of well, facilities and pipeline construction; business interruption, property and casualty losses or unexpected technical difficulties, including impact of weather; the Company's ability to achieve the anticipated benefits of the Reorganization; receipt of securityholder, stock exchange, regulatory and court approvals required in connection with the Reorganization and satisfaction of other conditions; risks relating to the new company following the Reorganization, including triggering provisions in certain agreements; publicity resulting from the Reorganization and impacts to the Company’s business and share price; counterparty and credit risk; impact of a downgrade in credit rating and its impact on access to sources of liquidity; fluctuations in currency and interest rates; risks inherent in the Company’s corporate guidance; failure to achieve cost and efficiency initiatives; risks inherent in marketing operations; risks associated with technology; changes in or interpretation of royalty, tax, environmental, greenhouse gas, carbon, accounting and other laws or regulations; risks associated with existing and potential lawsuits and regulatory actions made against the Company; impact of disputes arising with its partners, including suspension of certain obligations and inability to dispose of assets or interests in certain arrangements; the Company’s ability to acquire or find additional reserves; imprecision of reserves estimates and estimates of recoverable quantities, including future net revenue estimates; risks associated with past and future acquisitions or divestitures of certain assets or other transactions or receipt of amounts contemplated under the transaction agreements (such transactions may include third-party capital investments, farm-outs or partnerships, which Encana may refer to from time to time as “partnerships” or “joint ventures” and the funds received in respect thereof which Encana may refer to from time to time as “proceeds”, “deferred purchase price” and/or “carry capital”, regardless of the legal form) as a result of various conditions not being met; and other risks described herein and in Item 1A. Risk Factors of the Annual Report on Form 10-K for the fiscal year ended December 31, 2018 (“2018 Annual Report on Form 10-K”) and risks and uncertainties impacting Encana's business as described from time to time in the Company's other periodic filings with the SEC.

Although the Company believes the expectations represented by such forward-looking statements are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned that the assumptions, risks and uncertainties referenced above are not exhaustive. Forward-looking statements are made as of the date of this document and, except as required by law, the Company undertakes no obligation to update publicly or revise any forward-looking statements. The forward-looking statements contained in this Quarterly Report on Form 10-Q are expressly qualified by these cautionary statements.

The reader should read carefully the risk factors described herein and in Item 1A. Risk Factors of the 2018 Annual Report on Form 10-K for a description of certain risks that could, among other things, cause actual results to differ from these forward-looking statements.

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PART I

Item 1. Financial Statements

Condensed Consolidated Statement of Earnings (unaudited)

			Three Months Ended						Nine Months Ended
			September 30,						September 30,
(US$ millions, except per share amounts)			2019			2018			2019			2018
Revenues		(Notes 3, 4)
Product and service revenues			$	1,771		$	1,488		$	5,191		$	4,025
Gains (losses) on risk management, net		(Note 22)		81			(241	)		(84	)		(517	)
Sublease revenues				19			15			54			50
Total Revenues				1,871			1,262			5,161			3,558
Operating Expenses		(Note 3)
Production, mineral and other taxes				66			45			187			109
Transportation and processing		(Note 11)		398			278			1,148			799
Operating	(Notes 11, 19, 20)			193			124			545			372
Purchased product				264			282			784			803
Depreciation, depletion and amortization				545			349			1,454			924
Accretion of asset retirement obligation		(Note 14)		9			8			28			24
Administrative	(Notes 11, 18, 19, 20)			81			57			389			187
Total Operating Expenses				1,556			1,143			4,535			3,218
Operating Income (Loss)				315			119			626			340
Other (Income) Expenses
Interest		(Note 5)		99			92			285			265
Foreign exchange (gain) loss, net		(Notes 6, 22)		30			(23	)		(62	)		93
(Gain) loss on divestitures, net				(5	)		-			(4	)		(4	)
Other (gains) losses, net		(Notes 8, 20)		(1	)		5			24			2
Total Other (Income) Expenses				123			74			243			356
Net Earnings (Loss) Before Income Tax				192			45			383			(16	)
Income tax expense (recovery)		(Note 7)		43			6			143			(55	)
Net Earnings (Loss)			$	149		$	39		$	240		$	39
Net Earnings (Loss) per Common Share
Basic & Diluted		(Note 15)	$	0.11		$	0.04		$	0.18		$	0.04
Weighted Average Common Shares Outstanding (millions)
Basic & Diluted		(Note 15)		1,322.8			955.1			1,308.4			962.2

Condensed Consolidated Statement of Comprehensive Income (unaudited)

		Three Months Ended					Nine Months Ended
		September 30,					September 30,
(US$ millions)		2019			2018		2019			2018
Net Earnings (Loss)		$	149		$	39	$	240		$	39
Other Comprehensive Income (Loss), Net of Tax
Foreign currency translation adjustment	(Note 16)		(6	)		22		32			21
Pension and other post-employment benefit plans	(Notes 16, 20)		-			-		(24	)		(1	)
Other Comprehensive Income (Loss)			(6	)		22		8			20
Comprehensive Income (Loss)		$	143		$	61	$	248		$	59

See accompanying Notes to Condensed Consolidated Financial Statements

6

Condensed Consolidated Balance Sheet (unaudited)

			As at			As at
			September 30,			December 31,
(US$ millions)			2019			2018
Assets
Current Assets
Cash and cash equivalents			$	138		$	1,058
Accounts receivable and accrued revenues				1,127			789
Risk management		(Notes 21, 22)		284			554
Income tax receivable				316			275
				1,865			2,676
Property, Plant and Equipment, at cost:		(Note 10)
Oil and natural gas properties, based on full cost accounting
Proved properties				50,094			41,241
Unproved properties				3,943			3,730
Other		(Note 2)		892			2,122
Property, plant and equipment				54,929			47,093
Less: Accumulated depreciation, depletion and amortization				(39,803	)		(38,121	)
Property, plant and equipment, net		(Note 3)		15,126			8,972
Other Assets	(Notes 2, 10, 11)			1,202			147
Risk Management		(Notes 21, 22)		47			161
Deferred Income Taxes				521			835
Goodwill		(Notes 3, 8)		2,595			2,553
		(Note 3)	$	21,356		$	15,344
Liabilities and Shareholders’ Equity
Current Liabilities
Accounts payable and accrued liabilities			$	2,191		$	1,490
Current portion of operating lease liabilities		(Notes 2, 11)		79			-
Income tax payable				1			1
Risk management		(Notes 21, 22)		10			25
Current portion of long-term debt		(Note 12)		-			500
				2,281			2,016
Long-Term Debt		(Note 12)		7,024			3,698
Operating Lease Liabilities		(Notes 2, 11)		972			-
Other Liabilities and Provisions	(Notes 2, 11, 13)			548			1,769
Risk Management		(Notes 21, 22)		14			22
Asset Retirement Obligation		(Note 14)		414			365
Deferred Income Taxes				182			27
				11,435			7,897
Commitments and Contingencies		(Note 24)
Shareholders’ Equity
Share capital - authorized unlimited common shares
2019 issued and outstanding: 1,299.2 million shares (2018: 952.5 million shares)		(Note 15)		7,061			4,656
Paid in surplus		(Note 15)		1,402			1,358
Retained earnings				452			435
Accumulated other comprehensive income		(Note 16)		1,006			998
Total Shareholders’ Equity				9,921			7,447
			$	21,356		$	15,344

See accompanying Notes to Condensed Consolidated Financial Statements

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Condensed Consolidated Statement of Changes in Shareholders’ Equity (unaudited)

Three Months Ended September 30, 2019 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income			Total Shareholders’ Equity
Balance, June 30, 2019		$	7,318		$	1,358	$	327		$	1,012		$	10,015
Net Earnings (Loss)			-			-		149			-			149
Dividends on Common Shares ($0.01875 per share)	(Note 15)		-			-		(24	)		-			(24	)
Common Shares Purchased under Substantial Issuer Bid	(Note 15)		(257	)		44		-			-			(213	)
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			(6	)		(6	)
Balance, September 30, 2019		$	7,061		$	1,402	$	452		$	1,006		$	9,921

Three Months Ended September 30, 2018 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income		Total Shareholders’ Equity
Balance, June 30, 2018		$	4,674		$	1,358	$	(575	)	$	1,040	$	6,497
Net Earnings (Loss)			-			-		39			-		39
Dividends on Common Shares ($0.015 per share)	(Note 15)		-			-		(14	)		-		(14	)
Common Shares Purchased under Normal     Course Issuer Bid	(Note 15)		(19	)		-		(31	)		-		(50	)
Common Shares Issued Under     Dividend Reinvestment Plan	(Note 15)		-			-		-			-		-
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			22		22
Balance, September 30, 2018		$	4,655		$	1,358	$	(581	)	$	1,062	$	6,494

See accompanying Notes to Condensed Consolidated Financial Statements

8

Condensed Consolidated Statement of Changes in Shareholders’ Equity (unaudited)

Nine Months Ended September 30, 2019 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income		Total Shareholders’ Equity
Balance, December 31, 2018		$	4,656		$	1,358	$	435		$	998	$	7,447
Net Earnings (Loss)			-			-		240			-		240
Dividends on Common Shares ($0.05625 per share)	(Note 15)		-			-		(77	)		-		(77	)
Common Shares Purchased under Substantial Issuer Bid	(Note 15)		(257	)		44		-			-		(213	)
Common Shares Purchased under Normal     Course Issuer Bid	(Note 15)		(816	)		-		(221	)		-		(1,037	)
Common Shares Issued	(Notes 8, 15)		3,478			-		-			-		3,478
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			8		8
Impact of Adoption of Topic 842	(Note 2)		-			-		75			-		75
Balance, September 30, 2019		$	7,061		$	1,402	$	452		$	1,006	$	9,921

Nine Months Ended September 30, 2018 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income		Total Shareholders’ Equity
Balance, December 31, 2017		$	4,757		$	1,358	$	(429	)	$	1,042	$	6,728
Net Earnings (Loss)			-			-		39			-		39
Dividends on Common Shares ($0.045 per share)	(Note 15)		-			-		(43	)		-		(43	)
Common Shares Purchased under Normal     Course Issuer Bid	(Note 15)		(102	)		-		(148	)		-		(250	)
Common Shares Issued Under     Dividend Reinvestment Plan	(Note 15)		-			-		-			-		-
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			20		20
Balance, September 30, 2018		$	4,655		$	1,358	$	(581	)	$	1,062	$	6,494

See accompanying Notes to Condensed Consolidated Financial Statements

9

Condensed Consolidated Statement of Cash Flows (unaudited)

		Three Months Ended						Nine Months Ended
		September 30,						September 30,
(US$ millions)		2019			2018			2019			2018
Operating Activities
Net earnings (loss)		$	149		$	39		$	240		$	39
Depreciation, depletion and amortization			545			349			1,454			924
Accretion of asset retirement obligation	(Note 14)		9			8			28			24
Deferred income taxes	(Note 7)		44			6			140			6
Unrealized (gain) loss on risk management	(Note 22)		41			164			385			422
Unrealized foreign exchange (gain) loss	(Note 6)		49			(23	)		(11	)		156
Foreign exchange on settlements	(Note 6)		(18	)		(1	)		(53	)		(47	)
(Gain) loss on divestitures, net			(5	)		-			(4	)		(4	)
Other			3			47			(63	)		55
Net change in other assets and liabilities			(29	)		(17	)		(55	)		(33	)
Net change in non-cash working capital	(Note 23)		(32	)		313			130			199
Cash From (Used in) Operating Activities			756			885			2,191			1,741
Investing Activities
Capital expenditures	(Note 3)		(566	)		(523	)		(2,052	)		(1,626	)
Acquisitions	(Note 9)		(25	)		(15	)		(66	)		(17	)
Corporate acquisition, net of cash and restricted cash acquired	(Note 8)		-			-			94			-
Proceeds from divestitures	(Note 9)		171			24			177			89
Net change in investments and other			(142	)		(8	)		(118	)		72
Cash From (Used in) Investing Activities			(562	)		(522	)		(1,965	)		(1,482	)
Financing Activities
Net issuance (repayment) of revolving long-term debt	(Note 12)		(21	)		-			740			-
Repayment of long-term debt	(Note 12)		-			-			(500	)		-
Purchase of common shares	(Note 15)		(213	)		(50	)		(1,250	)		(250	)
Dividends on common shares	(Note 15)		(24	)		(14	)		(77	)		(43	)
Finance lease payments and other financing arrangements	(Note 11)		(22	)		(23	)		(63	)		(68	)
Cash From (Used in) Financing Activities			(280	)		(87	)		(1,150	)		(361	)
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents
and Restricted Cash Held in Foreign Currency			-			3			4			(2	)
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash			(86	)		279			(920	)		(104	)
Cash, Cash Equivalents and Restricted Cash, Beginning of Period			224			336			1,058			719
Cash, Cash Equivalents and Restricted Cash, End of Period		$	138		$	615		$	138		$	615
Cash, End of Period		$	44		$	30		$	44		$	30
Cash Equivalents, End of Period			94			585			94			585
Restricted Cash, End of Period			-			-			-			-
Cash, Cash Equivalents and Restricted Cash, End of Period		$	138		$	615		$	138		$	615

See accompanying Notes to Condensed Consolidated Financial Statements

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1. Basis of Presentation and Principles of Consolidation

Encana is in the business of the exploration for, the development of, and the production and marketing of oil, NGLs and natural gas.

The interim Condensed Consolidated Financial Statements include the accounts of Encana and entities in which it holds a controlling interest. All intercompany balances and transactions are eliminated on consolidation. Undivided interests in oil and natural gas exploration and production joint ventures and partnerships are consolidated on a proportionate basis. Investments in non-controlled entities over which Encana has the ability to exercise significant influence are accounted for using the equity method.  

The interim Condensed Consolidated Financial Statements are prepared in conformity with U.S. GAAP and the rules and regulations of the SEC. Pursuant to these rules and regulations, certain information and disclosures normally required under U.S. GAAP have been condensed or have been disclosed on an annual basis only. Accordingly, the interim Condensed Consolidated Financial Statements should be read in conjunction with the annual audited Consolidated Financial Statements and the notes thereto for the year ended December 31, 2018, which are included in Item 8 of Encana’s 2018 Annual Report on Form 10-K.

The interim Condensed Consolidated Financial Statements have been prepared following the same accounting policies and methods of computation as the annual audited Consolidated Financial Statements for the year ended December 31, 2018, except as noted below in Note 2. The disclosures provided below are incremental to those included with the annual audited Consolidated Financial Statements.

These unaudited interim Condensed Consolidated Financial Statements reflect, in the opinion of Management, all normal and recurring adjustments necessary to present fairly the financial position and results of the Company as at and for the periods presented. Interim condensed consolidated financial results are not necessarily indicative of consolidated financial results expected for the fiscal year.

2. Recent Accounting Pronouncements

Changes in Accounting Policies and Practices

On January 1, 2019, Encana adopted ASC Topic 842, Leases (“Topic 842”) and related amendments, using the modified retrospective approach recognizing a cumulative effect adjustment at the beginning of the reporting period in which Topic 842 was applied. Results for reporting the periods beginning after January 1, 2019, are presented in accordance with Topic 842, while prior periods have not been restated and are reported in accordance with ASC Topic 840, Leases (“Topic 840”). On transition, Encana elected certain practical expedients permitted under Topic 842 which include:

• No reassessment of the classification of leases previously assessed under Topic 840, whether expired or existing contracts contain leases, or initial direct costs of existing leases; and

• Application of Topic 842 prospectively to all new or modified land easements after January 1, 2019.

Encana also elected the short-term lease exemption, which does not require a right-of-use (“ROU”) asset or lease liability to be recognized on the Consolidated Balance Sheet when the lease term is 12 months or less. The policy and disclosures required under Topic 842 are included in Note 11, Leases.  

11

In accordance with Topic 842, Encana recognized a ROU asset and corresponding lease liability for all operating leases on the Consolidated Balance Sheet, other than leases with lease terms of 12 months or less. Prior to the adoption of Topic 842, operating leases were not recognized on the Consolidated Balance Sheet. There was no impact to finance leases on transition to Topic 842. The impact from recognizing operating leases on Encana’s Condensed Consolidated Balance Sheet is as follows:

										Restated
	Reported as at			Impact of						Balances as at
(US$ millions)	December 31, 2018			Adoption						January 1, 2019
Property, Plant and Equipment, at cost:
Oil and natural gas properties, based on full cost accounting
Proved properties	$	41,241		$	-					$	41,241
Unproved properties		3,730			-						3,730
Other		2,122			(1,261	)					861
Property, plant and equipment		47,093			(1,261	)					45,832
Less: accumulated depreciation, depletion and amortization		(38,121	)		128						(37,993	)
Property, plant and equipment, net		8,972			(1,133	)		(1	)		7,839
Other Assets		147			1,015		(1), (2		)		1,162
Deferred Income Taxes		835			(28	)					807
Total Assets		15,344			(146	)					15,198
Current Liabilities
Accounts payable and accrued liabilities		1,490			(12	)		(1	)		1,478
Current portion of operating lease liabilities		-			67			(2	)		67
Income tax payable		1			-						1
Risk management		25			-						25
Current portion of long-term debt		500			-						500
		2,016			55						2,071
Operating Lease Liabilities		-			948			(2	)		948
Other Liabilities and Provisions		1,769			(1,224	)		(1	)		545
Total Liabilities		7,897			(221	)					7,676
Retained Earnings		435			75			(1	)		510
Total Shareholders’ Equity		7,447			75						7,522
Total Liabilities and Shareholders’ Equity	$	15,344		$	(146	)				$	15,198

(1) In accordance with Topic 840, Encana accounted for The Bow office building as a failed sales leaseback and at the effective date of January 1, 2019, The Bow office building remained as such. On transition to Topic 842, Encana re-assessed whether a sale would have occurred at the effective date and determined that a sale occurred. As a result, Encana derecognized the asset and financing liability resulting from the failed sale leaseback transaction measured under Topic 840, recognizing the difference as an adjustment to retained earnings in the Condensed Consolidated Balance Sheet. Upon transition to Topic 842, The Bow office building was determined to be an operating lease for which a ROU asset and corresponding liability was recorded at the present value of remaining minimum lease payments.

(2) ROU assets for operating leases were measured at the amount equal to the lease liability and the unamortized balance of any lease incentives prior to the transition date. The lease liabilities for operating leases were measured at the present value of the remaining minimum lease payments outstanding as at January 1, 2019.

Although Topic 842 did not have a material impact on the Condensed Consolidated Statements of Earnings or Cash Flows, the change in the accounting of The Bow office building resulted in: i) operating lease expense under Topic 842 reported in administrative expense, whereas for the comparative periods presented under Topic 840, Encana recorded depreciation and interest expense in the Condensed Consolidated Statement of Earnings; and ii) cash outflows presented in cash used in operating activities under Topic 842, whereas for the comparative periods presented under Topic 840, interest and financing cash outflows are presented in cash used in operating activities and cash used in financing activities, respectively, in the Condensed Consolidated Statement of Cash Flows.        

On January 1, 2019, Encana adopted ASU 2018-02 “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”. The amendments allow for a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act (“U.S. Tax Reform”). While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact was not material to the

12

Company’s Consolidated Financial Statements. As a result, the Company did not take the election provided in the amendment.

New Standards Issued Not Yet Adopted

As of January 1, 2020, Encana will be required to adopt ASU 2017-04, “Simplifying the Test for Goodwill Impairment”. The amendment eliminates the second step of the goodwill impairment test which requires the Company to measure the impairment based on the excess amount of the carrying value of the reporting unit’s goodwill over the implied fair value of its goodwill. Under this amendment, the goodwill impairment will be measured based on the excess amount of the reporting unit’s carrying value over its respective fair value. The amendment will be applied prospectively at the date of adoption. Encana does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

3. Segmented Information

Encana’s reportable segments are determined based on the Company’s operations and geographic locations as follows:

• Canadian Operations includes the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the Canadian cost center.    

• USA Operations includes the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the U.S. cost center.  

• China Operations included the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the China cost center. The Company terminated its production sharing contract with the China National Offshore Oil Corporation (“CNOOC”) and exited its China Operations effective July 31, 2019.  

• Market Optimization is primarily responsible for the sale of the Company’s proprietary production. These results are reported in the Canadian and USA Operations. Market optimization activities include third-party purchases and sales of product to provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification. These activities are reflected in the Market Optimization segment. Market Optimization sells substantially all of the Company’s upstream production to third-party customers. Transactions between segments are based on market values and are eliminated on consolidation.  

Corporate and Other mainly includes unrealized gains or losses recorded on derivative financial instruments. Once the instruments are settled, the realized gains and losses are recorded in the reporting segment to which the derivative instruments relate. Corporate and Other also includes amounts related to sublease rentals.

As of February 14, 2019, Encana’s segmented results reflect the business combination as discussed in Note 8.

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Results of Operations (For the three months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019			2018
Revenues
Product and service revenues	$	377	$	453	$	1,097	$	718		$	3		$	-
Gains (losses) on risk management, net		87		8		35		(84	)		-			-
Sublease revenues		-		-		-		-			-			-
Total Revenues		464		461		1,132		634			3			-
Operating Expenses
Production, mineral and other taxes		3		4		63		41			-			-
Transportation and processing		211		211		125		34			-			-
Operating		32		34		151		80			4			-
Depreciation, depletion and amortization		100		95		438		241			-			-
Total Operating Expenses		346		344		777		396			4			-
Operating Income (Loss)	$	118	$	117	$	355	$	238		$	(1	)	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	294		$	317		$	-		$	-		$	1,771		$	1,488
Gains (losses) on risk management, net		-			(1	)		(41	)		(164	)		81			(241	)
Sublease revenues		-			-			19			15			19			15
Total Revenues		294			316			(22	)		(149	)		1,871			1,262
Operating Expenses
Production, mineral and other taxes		-			-			-			-			66			45
Transportation and processing		62			33			-			-			398			278
Operating		6			8			-			2			193			124
Purchased product		264			282			-			-			264			282
Depreciation, depletion and amortization		-			-			7			13			545			349
Accretion of asset retirement obligation		-			-			9			8			9			8
Administrative		-			-			81			57			81			57
Total Operating Expenses		332			323			97			80			1,556			1,143
Operating Income (Loss)	$	(38	)	$	(7	)	$	(119	)	$	(229	)		315			119
Other (Income) Expenses
Interest														99			92
Foreign exchange (gain) loss, net														30			(23	)
(Gain) loss on divestitures, net														(5	)		-
Other (gains) losses, net														(1	)		5
Total Other (Income) Expenses														123			74
Net Earnings (Loss) Before Income Tax														192			45
Income tax expense (recovery)														43			6
Net Earnings (Loss)													$	149		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

14

Results of Operations (For the nine months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues
Product and service revenues	$	1,222	$	1,236	$	3,062	$	1,880		$	37	$	-
Gains (losses) on risk management, net		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Total Revenues		1,396		1,329		3,190		1,695			37		-
Operating Expenses
Production, mineral and other taxes		11		12		176		97			-		-
Transportation and processing		640		608		340		92			-		-
Operating		96		98		414		238			16		-
Depreciation, depletion and amortization		287		257		1,141		628			-		-
Total Operating Expenses		1,034		975		2,071		1,055			16		-
Operating Income (Loss)	$	362	$	354	$	1,119	$	640		$	21	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	870		$	909		$	-		$	-		$	5,191		$	4,025
Gains (losses) on risk management, net		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Total Revenues		869			906			(331	)		(372	)		5,161			3,558
Operating Expenses
Production, mineral and other taxes		-			-			-			-			187			109
Transportation and processing		168			99			-			-			1,148			799
Operating		21			25			(2	)		11			545			372
Purchased product		784			803			-			-			784			803
Depreciation, depletion and amortization		-			1			26			38			1,454			924
Accretion of asset retirement obligation		-			-			28			24			28			24
Administrative		-			-			389			187			389			187
Total Operating Expenses		973			928			441			260			4,535			3,218
Operating Income (Loss)	$	(104	)	$	(22	)	$	(772	)	$	(632	)		626			340
Other (Income) Expenses
Interest														285			265
Foreign exchange (gain) loss, net														(62	)		93
(Gain) loss on divestitures, net														(4	)		(4	)
Other (gains) losses, net														24			2
Total Other (Income) Expenses														243			356
Net Earnings (Loss) Before Income Tax														383			(16	)
Income tax expense (recovery)														143			(55	)
Net Earnings (Loss)													$	240		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

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Intersegment Information

							Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the three months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	2,088		$	1,513		$	(1,794	)	$	(1,197	)	$	294		$	316
Operating Expenses
Transportation and processing		173			120			(111	)		(87	)		62			33
Operating		6			8			-			-			6			8
Purchased product		1,947			1,392			(1,683	)		(1,110	)		264			282
Operating Income (Loss)	$	(38	)	$	(7	)	$	-		$	-		$	(38	)	$	(7	)

	Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the nine months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	5,459		$	4,203		$	(4,590	)	$	(3,297	)	$	869		$	906
Operating Expenses
Transportation and processing		465			335			(297	)		(236	)		168			99
Operating		21			25			-			-			21			25
Purchased product		5,078			3,864			(4,294	)		(3,061	)		784			803
Depreciation, depletion and amortization		-			1			-			-			-			1
Operating Income (Loss)	$	(105	)	$	(22	)	$	1		$	-		$	(104	)	$	(22	)

Capital Expenditures

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Canadian Operations	$	99	$	174	$	364	$	553
USA Operations		464		345		1,682		1,065
Market Optimization		2		-		2		-
Corporate & Other		1		4		4		8
	$	566	$	523	$	2,052	$	1,626

Goodwill, Property, Plant and Equipment and Total Assets by Segment

	Goodwill					Property, Plant and Equipment					Total Assets
	As at					As at					As at
	September 30,		December 31,			September 30,		December 31,			September 30,		December 31,
	2019			2018		2019			2018		2019			2018
Canadian Operations	$	660		$	640	$	1,111		$	999	$	1,978		$	1,852
USA Operations		1,935			1,913		13,782			6,591		16,634			9,104
Market Optimization		-			-		2			1		225			295
Corporate & Other		-			-		231			1,381		2,519			4,093
	$	2,595		$	2,553	$	15,126		$	8,972	$	21,356		$	15,344

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4. Revenues from Contracts with Customers

The following tables summarize the Company’s revenues from contracts with customers and other sources of revenues. Encana presents realized and unrealized gains and losses on certain derivative contracts within revenues.

Revenues (For the three months ended September 30)

	Canadian Operations				USA Operations						China Operations (1)
	2019		2018		2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	3	$	1	$	905		$	590		$	3	$	-
NGLs		225		259		99			98			-		-
Natural gas		150		195		95			31			-		-
Service revenues
Gathering and processing		2		1		(1	)		4			-		-
Product and Service Revenues		380		456		1,098			723			3		-
Other Revenues
Gains (losses) on risk management, net (3)		87		8		35			(84	)		-		-
Sublease revenues		-		-		-			-			-		-
Other Revenues		87		8		35			(84	)		-		-
Total Revenues	$	467	$	464	$	1,133		$	639		$	3	$	-

	Market Optimization					Corporate & Other						Consolidated
	2019		2018			2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	107	$	34		$	-		$	-		$	1,018	$	625
NGLs		2		1			-			-			326		358
Natural gas		181		274			-			-			426		500
Service revenues
Gathering and processing		-		-			-			-			1		5
Product and Service Revenues		290		309			-			-			1,771		1,488
Other Revenues
Gains (losses) on risk management, net (3)		-		(1	)		(41	)		(164	)		81		(241	)
Sublease revenues		-		-			19			15			19		15
Other Revenues		-		(1	)		(22	)		(149	)		100		(226	)
Total Revenues	$	290	$	308		$	(22	)	$	(149	)	$	1,871	$	1,262

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

17

Revenues (For the nine months ended September 30)

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	6	$	6	$	2,461	$	1,579		$	37	$	-
NGLs		659		655		332		221			-		-
Natural gas		563		580		276		92			-		-
Service revenues
Gathering and processing		4		5		2		4			-		-
Product and Service Revenues		1,232		1,246		3,071		1,896			37		-
Other Revenues
Gains (losses) on risk management, net (3)		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Other Revenues		174		93		128		(185	)		-		-
Total Revenues	$	1,406	$	1,339	$	3,199	$	1,711		$	37	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues from Customers
Product revenues (2)
Oil	$	205		$	84		$	-		$	-		$	2,709		$	1,669
NGLs		6			6			-			-			997			882
Natural gas		640			793			-			-			1,479			1,465
Service revenues
Gathering and processing		-			-			-			-			6			9
Product and Service Revenues		851			883			-			-			5,191			4,025
Other Revenues
Gains (losses) on risk management, net (3)		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Other Revenues		(1	)		(3	)		(331	)		(372	)		(30	)		(467	)
Total Revenues	$	850		$	880		$	(331	)	$	(372	)	$	5,161		$	3,558

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

The Company’s revenues from contracts with customers consists of product sales including oil, NGLs and natural gas, as well as the provision of gathering and processing services to third parties. Encana had no contract asset or liability balances during the periods presented. As at September 30, 2019, receivables and accrued revenues from contracts with customers were $980 million ($662 million as at December 31, 2018).

Encana’s product sales are sold under short-term contracts with terms that are less than one year at either fixed or market index prices or under long-term contracts exceeding one year at market index prices.  

The Company’s gathering and processing services are provided on an interruptible basis with transaction prices that are for fixed prices and/or variable consideration. Variable consideration received is related to recovery of plant operating costs or escalation of the fixed price based on a consumer price index. As the service contracts are interruptible, with service provided on an “as available” basis, there are no unsatisfied performance obligations remaining at September 30, 2019.

18

As at September 30, 2019, all remaining performance obligations are priced at market index prices or are variable volume delivery contracts. As such, the variable consideration is allocated entirely to the wholly unsatisfied performance obligation or promise to deliver units of production, and revenue is recognized at the amount for which the Company has the right to invoice the product delivered. As the period between when the product sales are transferred and Encana receives payments is generally 30 to 60 days, there is no financing element associated with customer contracts. In addition, Encana does not disclose unsatisfied performance obligations for customer contracts with terms less than 12 months.

5. Interest

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Interest Expense on:
Debt	$	93	$	67	$	268	$	200
The Bow office building (See Note 2)		-		16		-		48
Finance leases (See Note 11)		3		3		10		12
Other		3		6		7		5
	$	99	$	92	$	285	$	265

Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease with lease costs recognized in administrative expense. Previously, payments related to The Bow were recognized as interest expense and principal repayments. See Notes 2 and 11 for further information.

6. Foreign Exchange (Gain) Loss, Net

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	68		$	(74	)	$	(117	)	$	138
Translation of U.S. dollar risk management contracts issued from Canada		5			(3	)		(13	)		7
Translation of intercompany notes		(24	)		54			119			11
		49			(23	)		(11	)		156
Foreign Exchange on Settlements of:
U.S. dollar financing debt issued from Canada		(10	)		-			(22	)		1
U.S. dollar risk management contracts issued from Canada		(2	)		(1	)		(1	)		(11	)
Intercompany notes		(8	)		(1	)		(31	)		(48	)
Other Monetary Revaluations		1			2			3			(5	)
	$	30		$	(23	)	$	(62	)	$	93

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7. Income Taxes

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Current Tax
Canada	$	(2	)	$	-		$	-		$	(66	)
United States		1			-			3			2
Other Countries		-			-			-			3
Total Current Tax Expense (Recovery)		(1	)		-			3			(61	)
Deferred Tax
Canada		(12	)		19			22			(9	)
United States		56			(3	)		117			4
Other Countries		-			(10	)		1			11
Total Deferred Tax Expense (Recovery)		44			6			140			6
Income Tax Expense (Recovery)	$	43		$	6		$	143		$	(55	)
Effective Tax Rate		22.4	%		13.3	%		37.3	%		343.8	%

Encana’s interim income tax expense is determined using the estimated annual effective income tax rate applied to year-to-date net earnings before income tax plus the effect of legislative changes and amounts in respect of prior periods. The estimated annual effective income tax rate is impacted by expected annual earnings, income tax related to foreign operations, the effect of legislative changes, non-taxable capital gains and losses, tax differences on divestitures and transactions, and partnership tax allocations in excess of funding.

On June 28, 2019, Alberta Bill 3, the Job Creation Tax Cut (Alberta Corporate Tax Amendment) Act, was signed into law resulting in a reduction of the Alberta corporate tax rate from 12 percent to 11 percent effective July 1, 2019, with further one percent rate reductions to take effect every year on January 1 until the general corporate tax rate is eight percent on January 1, 2022. During the nine months ended September 30, 2019, the deferred tax expense of $140 million includes an adjustment of $55 million resulting from the re-measurement of the Company’s deferred tax position due to the Alberta tax rate reduction.

During the nine months ended September 30, 2018, the current income tax recovery was primarily due to the resolution of certain tax items relating to prior taxation years. During the three and nine months ended September 30, 2019, the deferred tax expense was primarily due to net earnings before income tax in the respective periods and the impact of the Alberta tax rate reduction discussed above. During the three months ended September 30, 2018, the deferred tax expense was primarily due to the changes in the estimated annual effective income tax rate.

The effective tax rate of 37.3 percent for the nine months ended September 30, 2019 is higher than the Canadian statutory tax rate of 26.6 percent primarily due to the re-measurement of the Company’s deferred tax position resulting from the Alberta tax rate reduction discussed above, partially offset by partnership tax allocations in excess of funding. The effective tax rate of 343.8 percent for the nine months ended September 30, 2018, was higher than the Canadian statutory tax rate of 27 percent primarily due to the resolution of certain tax items relating to prior taxation years.

8. Business Combination

Newfield Exploration Company Acquisition

On February 13, 2019, Encana completed the business combination with Newfield Exploration Company, a Delaware corporation (“Newfield”), pursuant to its Agreement and Plan of Merger with Newfield (the “Merger”). As a result of the Merger, Newfield stockholders received 2.6719 Encana common shares for each share of Newfield common stock that was issued and outstanding immediately prior to the effective date of the Merger. Encana issued approximately 543.4 million common shares representing a value of $3.5 billion and paid approximately $5 million in cash in respect of Newfield’s cash-settled incentive awards. Following the acquisition, Newfield’s senior notes totaling $2.45 billion remained outstanding. Transaction costs of approximately $33 million were included in other (gains) losses, net.

20

Newfield’s operations focused on the exploration and development of oil and gas properties located in the Anadarko and Arkoma Basins of Oklahoma, the Williston Basin of North Dakota and the Uinta Basin of Utah, as well as offshore oil assets located in China. The assets acquired generated revenues of $1,485 million and net earnings of $69 million for the period from February 14, 2019 to September 30, 2019. The results of Newfield’s operations have been included in Encana’s Consolidated Financial Statements as of February 14, 2019.  

Purchase Price Allocation

The transaction was accounted for under the acquisition method, which requires that the assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date, with any excess of the purchase price over the estimated fair value of identified net assets acquired recorded as goodwill. The purchase price allocation represents the consideration paid and the fair values of the assets acquired, and liabilities assumed as of the acquisition date. The purchase price allocation is subject to change based on information that may not yet be available, including, the valuation of any pre-acquisition contingencies, final appraisals and tax returns that provide the underlying tax basis of the net assets and liabilities acquired and uncertain tax positions. The Company expects the purchase price allocation to be completed within 12 months following the acquisition date, during which time the value of the net assets and liabilities acquired may be revised as appropriate.

Preliminary Purchase Price Allocation
Consideration:
Fair value of Encana's common shares issued (1)	$	3,478
Fair value of Newfield liability awards paid in cash (2)		5
Total Consideration	$	3,483
Assets Acquired:
Cash and cash equivalents	$	46
Accounts receivable and accrued revenues		486
Other current assets		50
Proved properties		5,903
Unproved properties		838
Other property, plant and equipment		22
Restricted cash		53
Other assets		105
Goodwill (3)		22
Liabilities Assumed:
Accounts payable and accrued liabilities (3)		(795	)
Long-term debt		(2,603	)
Operating lease liabilities		(76	)
Other long-term liabilities (3)		(61	)
Asset retirement obligation		(184	)
Deferred income taxes (3)		(323	)
Total Purchase Price	$	3,483

(1) The fair value was based on the NYSE closing price of the Encana common shares of $6.40 on February 13, 2019.

(2) The fair value was based on a price of $6.50 per notional unit which was determined using a volume-weighted average of the trading price of Encana common shares on the NYSE on each of the five consecutive trading days ending on the trading day that was three trading days prior to February 13, 2019.

(3) Since the completion of the business combination on February 13, 2019, additional information related to pre-acquisition liabilities and contingencies was obtained resulting in a measurement period adjustment. Changes in the fair value estimates comprised an increase in other liabilities of $12 million, of which the total liability is presented in accounts payable and accrued liabilities, a decrease in deferred tax liabilities of $3 million and a corresponding increase in goodwill of $9 million.

The Company used the income approach valuation technique for the fair value of assets acquired and liabilities assumed. The carrying amounts of cash and cash equivalents, accounts receivable and accrued revenues, restricted cash and other current assets, and accounts payable and accrued liabilities approximate their fair values due to their nature and/or the short-term maturity of the instruments. The fair values of long-term debt, ROU assets and operating lease liabilities were categorized within Level 2 of the fair value hierarchy and were determined using quoted prices and rates from an available pricing source. The fair values of the proved and unproved properties, other property, plant and equipment, other assets, other long-term liabilities and asset retirement obligation were categorized within Level 3 and were determined using relevant market assumptions, including discount rates, future commodity prices and costs, timing of development activities, projections of oil and gas reserves, and estimates for abandonment and reclamation.

21

Goodwill arose from the Newfield acquisition primarily from the requirement to recognize deferred taxes on the difference between the fair value of the assets acquired and liabilities assumed and the respective carry-over tax basis. Goodwill is not amortized and is not deductible for tax purposes.

Unaudited Pro Forma Financial Information

The following unaudited pro forma financial information combines the historical financial results of Encana with Newfield and has been prepared as though the acquisition had occurred on January 1, 2018. The pro forma information is not intended to reflect the actual results of operations that would have occurred if the business combination had been completed at the date indicated. In addition, the pro forma information is not intended to be a projection of Encana’s results of operations for any future period.

Additionally, pro forma earnings were adjusted to exclude acquisition-related costs incurred of approximately $71 million and severance payments made to employees which totaled $134 million for the nine months ended September 30, 2019. The pro forma financial information does not include any cost savings or other synergies that may result from the Merger or any estimated costs that have been or will be incurred to integrate the assets.

For the nine months ended September 30, (US$ millions, except per share amounts)	2019		2018
Revenues	$	5,440	$	5,215
Net Earnings (Loss)	$	376	$	369
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.29	$	0.25

9. Acquisitions and Divestitures

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Acquisitions
Canadian Operations	$	-		$	15		$	-		$	17
USA Operations		25			-			66			-
Total Acquisitions		25			15			66			17
Divestitures
Canadian Operations		-			2			-			(55	)
USA Operations		(171	)		(26	)		(177	)		(34	)
Total Divestitures		(171	)		(24	)		(177	)		(89	)
Net Acquisitions & (Divestitures)	$	(146	)	$	(9	)	$	(111	)	$	(72	)

Acquisitions

For the nine months ended September 30, 2019, acquisitions in the Canadian and USA Operations were nil (2018 - $17 million) and $66 million (2018 - nil), respectively, which primarily included seismic purchases, water rights and purchases with oil and liquids rich potential.

Divestitures

For the three and nine months ended September 30, 2019, divestitures in the USA Operations were $171 million and $177 million, respectively, which primarily included the sale of the Company’s Arkoma natural gas assets. For the three and nine months ended September 30, 2018, divestitures in the USA Operations were $26 million and $34 million, respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

During the nine months ended September 30, 2018, divestitures in the Canadian Operations were $55 million, which primarily included the sale of certain Pipestone assets located in Alberta.

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Amounts received from the Company’s divestiture transactions have been deducted from the respective Canadian and U.S. full cost pools.

10. Property, Plant and Equipment, Net

	As at September 30, 2019							As at December 31, 2018
			Accumulated							Accumulated
	Cost		DD&A			Net		Cost		DD&A			Net
Canadian Operations
Proved properties	$	14,817	$	(13,949	)	$	868	$	13,996	$	(13,261	)	$	735
Unproved properties		223		-			223		237		-			237
Other		20		-			20		27		-			27
		15,060		(13,949	)		1,111		14,260		(13,261	)		999
USA Operations
Proved properties		35,223		(25,186	)		10,037		27,189		(24,099	)		3,090
Unproved properties		3,720		-			3,720		3,493		-			3,493
Other		25		-			25		8		-			8
		38,968		(25,186	)		13,782		30,690		(24,099	)		6,591
Market Optimization		8		(6	)		2		7		(6	)		1
Corporate & Other		893		(662	)		231		2,136		(755	)		1,381
	$	54,929	$	(39,803	)	$	15,126	$	47,093	$	(38,121	)	$	8,972

Canadian and USA Operations property, plant and equipment include internal costs directly related to exploration, development and construction activities of $171 million, which have been capitalized during the nine months ended September 30, 2019 (2018 - $159 million).

Finance Lease Arrangements

The Company has two lease arrangements that are accounted for as finance leases, which include an office building and an offshore production platform. As at September 30, 2019, the total carrying value of assets under finance lease was $39 million ($41 million as at December 31, 2018), net of accumulated amortization of $667 million ($650 million as at December 31, 2018). Long-term liabilities for the finance lease arrangements are included in other liabilities and provisions in the Condensed Consolidated Balance Sheet and are disclosed in Note 13.

Other Arrangement

As at December 31, 2018, Corporate and Other property, plant and equipment and total assets included a carrying value of $1,133 million related to The Bow office building. Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease as discussed in Note 2. As at September 30, 2019, other assets included a ROU asset of $896 million related to The Bow office building.

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11. Leases

Leases entered into for the right to use an asset are classified as either an operating or finance lease. Upon commencement of the lease, a ROU asset and corresponding lease liability are recognized on the Condensed Consolidated Balance Sheet for all operating and finance leases. Encana has elected the short-term lease exemption, which does not require a ROU asset or lease liability to be recognized on the Condensed Consolidated Balance Sheet when the lease term is 12 months or less and does not include an option to purchase the underlying asset that the lessee is reasonably certain to exercise.  

Upon commencement of the lease, ROU assets are recognized based on the initial measurement of the lease liability and adjusted for any lease payments made before commencement date of the lease, less any lease incentives and including any initial direct costs incurred. Lease liabilities are initially measured at the present value of future minimum lease payments over the lease term. The discount rate used to determine the present value is the rate implicit in the lease unless that rate cannot be determined, in which case Encana’s incremental borrowing rate is used.  

Rights to extend or terminate a lease are included in the lease term when there is reasonable certainty the right will be exercised. Factors used to assess reasonable certainty of rights to extend or terminate a lease include current and forecasted drillings plans, anticipated changes in development strategies, historical practice in extending similar contracts and current market conditions. Encana’s lease contracts include rights to extend leases after the initial term, ranging from month-to-month to less than 10 years.

Operating lease ROU assets and liabilities are subsequently measured at the present value of the lease payments not yet paid and discounted at the initial discount rate at commencement of the lease, less any impairments to the ROU asset. Operating lease expense and revenue from subleases are recognized in the Condensed Consolidated Statement of Earnings on a straight-line basis over the lease term. Finance lease ROU assets are amortized on a straight-line basis over the estimated useful life of the asset if the lessee is reasonably certain to exercise a purchase option or ownership of the leased asset transfers at the end of the lease term, otherwise the leased assets are amortized over the lease term. Amortization of finance lease ROU assets is included in depreciation, depletion and amortization in the Condensed Consolidated Statement of Earnings.

Variable lease payments include changes in index rates, mobilization and demobilization costs related to oil and gas equipment and certain costs associated with office and building leases. Variable lease payments are recognized when incurred. Lease and non-lease components are accounted for as a single lease component for compression, coolers and office subleases.

Operating leases include drilling rigs, compressors, marine vessels, camps, office and buildings, certain land easements and various equipment utilized in the development and production of oil, NGLs and natural gas. Finance leases include an office building and an offshore production platform. Subleases relate to office and building leases.

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The tables below summarize Encana’s operating and finance lease costs and include ROU assets and lease liabilities, amounts recognized in net earnings during the period and other lease information.

(US$ millions, unless otherwise specified)	As at September 30, 2019
Condensed Consolidated Balance Sheet (1):
Operating Lease ROU Assets, in Other Assets	$	1,045
Finance Lease ROU Assets, in Other Property Plant and Equipment		39
Operating Lease Liabilities:
Current		79
Long-term		972
Finance Lease Liabilities:
Current, in accounts payable and accrued liabilities		88
Long-term, in other liabilities and provisions		144
Weighted Average Discount Rate
Operating leases	5.42%
Finance leases	5.97%
Weighted Average Remaining Lease Term
Operating leases	16.4 years
Finance leases	3.4 years

(1) Total ROU assets and liabilities are recorded at the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Lease Costs (1):
Operating Lease Costs, Excluding Short-Term Leases	$	45	$	133
Finance Lease Costs:
Amortization of ROU assets		1		3
Interest on lease liabilities		3		10
Total Finance Lease Costs		4		13
Short-Term Lease Costs		93		250
Variable Lease Costs		3		10
Sublease Income:
Operating lease income		15		41
Variable lease income		4		13
Other Information:
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating cash outflows from operating leases		57		157
Investing cash outflows from operating leases		80		220
Operating cash outflows from finance leases		3		10
Financing cash outflows from finance leases		22		63
Supplemental Non-Cash Information:
New ROU operating lease assets and liabilities		1		11

(1) Lease costs include amounts capitalized into property, plant and equipment on the Condensed Consolidated Balance Sheet and lease expense recognized in the Condensed Consolidated Statement of Earnings.

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Operating lease expense is reflected in the Condensed Consolidated Statement of Earnings as follows:

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Operating Lease Expense
Transportation and processing	$	1	$	2
Operating		28		76
Administrative (1)		30		86
Total Operating Lease Expense	$	59	$	164

(1) Includes $23 million and $69 million for the three and nine months ended September 30, 2019, respectively, related to The Bow office building.

The following table outlines the Company’s future lease payments and lease liabilities related to the Company’s operating and finance leases as at September 30, 2019:

	2019			2020			2021			2022			2023			Thereafter			Total
Operating Leases (1)
Expected Future Lease Payments	$	37		$	128		$	112		$	97		$	85		$	1,165		$	1,624
Less: Discounting																				573
Present Value of Future Operating    Lease Payments																			$	1,051
Sublease Income (undiscounted)	$	(10	)	$	(41	)	$	(42	)	$	(37	)	$	(37	)	$	(566	)	$	(733	)
Finance Leases
Expected Future Lease Payments	$	25		$	99		$	87		$	8		$	8		$	30		$	257
Less: Discounting																				25
Present Value of Future Finance    Lease Payments																			$	232
Sublease Income (undiscounted) (2)	$	(2	)	$	(8	)	$	(8	)	$	(8	)	$	(7	)	$	(24	)	$	(57	)

(1) Lease payments are presented based on the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

(2) Classified as operating lease.

There are no commitments for leases with terms greater than one year that have not yet commenced at September 30, 2019.

Refer to Notes 14 and 25 under Item 8 of Encana’s 2018 Annual Report on Form 10-K for comparative period disclosure of future lease payments and sublease income related to capital and operating leases and The Bow office building. Operating leases in the table above includes The Bow office building which was determined to be an operating lease on transition to Topic 842 as disclosed in Note 2. Under Topic 840, The Bow was accounted for as a financing transaction under a failed sales leaseback.  

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12. Long-Term Debt

	As at			As at
	September 30,			December 31,
	2019			2018
U.S. Dollar Denominated Debt
Revolving credit and term loan borrowings	$	740		$	-
U.S. Unsecured Notes:
6.50% due May 15, 2019		-			500
3.90% due November 15, 2021		600			600
5.75% due January 30, 2022 (See Note 8)		750			-
5.625% due July 1, 2024  (See Note 8)		1,000			-
5.375% due January 1, 2026  (See Note 8)		700			-
8.125% due September 15, 2030		300			300
7.20% due November 1, 2031		350			350
7.375% due November 1, 2031		500			500
6.50% due August 15, 2034		750			750
6.625% due August 15, 2037		462			462
6.50% due February 1, 2038		505			505
5.15% due November 15, 2041		244			244
Total Principal		6,901			4,211
Increase in Value of Debt Acquired		157			22
Unamortized Debt Discounts and Issuance Costs		(34	)		(35	)
Total Long-Term Debt	$	7,024		$	4,198
Current Portion	$	-		$	500
Long-Term Portion		7,024			3,698
	$	7,024		$	4,198

As at September 30, 2019, total long-term debt had a carrying value of $7,024 million and a fair value of $7,825 million (as at December 31, 2018 - carrying value of $4,198 million and a fair value of $4,511 million). The estimated fair value of long-term borrowings is categorized within Level 2 of the fair value hierarchy and has been determined based on market information of long-term debt with similar terms and maturity, or by discounting future payments of interest and principal at interest rates expected to be available to the Company at period end.

As at September 30, 2019, the Company had outstanding commercial paper of $740 million maturing at various dates with a weighted average interest rate of approximately 2.63 percent. These amounts are supported, and Management expects that they will continue to be supported, by revolving credit facilities that have no repayment requirements within the next year and which expire in 2022.

13. Other Liabilities and Provisions

	As at		As at
	September 30,		December 31,
	2019		2018
The Bow Office Building	$	-	$	1,224
Finance Lease Obligations (See Note 11)		144		211
Unrecognized Tax Benefits		172		167
Pensions and Other Post-Employment Benefits		170		105
Long-Term Incentive Costs (See Note 19)		29		34
Other Derivative Contracts (See Notes 21, 22)		8		10
Other		25		18
	$	548	$	1,769

Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease. See Notes 2 and 11 for further information.

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14. Asset Retirement Obligation

	As at			As at
	September 30,			December 31,
	2019			2018
Asset Retirement Obligation, Beginning of Year	$	455		$	514
Liabilities Incurred		13			17
Liabilities Acquired (See Note 8)		184			-
Liabilities Settled and Divested		(100	)		(56	)
Change in Estimated Future Cash Outflows		-			(20	)
Accretion Expense		28			32
Foreign Currency Translation		10			(32	)
Asset Retirement Obligation, End of Period	$	590		$	455
Current Portion	$	176		$	90
Long-Term Portion		414			365
	$	590		$	455

15. Share Capital

Authorized

The Company is authorized to issue an unlimited number of no par value common shares and Class A Preferred Shares limited to a number equal to not more than 20 percent of the issued and outstanding number of common shares at the time of issuance. No Class A Preferred Shares are outstanding.

Issued and Outstanding

	As at September 30, 2019						As at December 31, 2018
	Number (millions)			Amount			Number (millions)			Amount
Common Shares Outstanding, Beginning of Year		952.5		$	4,656			973.1		$	4,757
Common Shares Purchased		(196.7	)		(1,073	)		(20.7	)		(102	)
Common Shares Issued		543.4			3,478			-			-
Common Shares Issued Under Dividend Reinvestment Plan		-			-			0.1			1
Common Shares Outstanding, End of Period		1,299.2		$	7,061			952.5		$	4,656

On February 13, 2019, Encana completed the acquisition of all the issued and outstanding shares of common stock of Newfield whereby Encana issued approximately 543.4 million common shares to Newfield shareholders, representing an exchange ratio of 2.6719 Encana common shares for each share of Newfield common stock held. See Note 8 for further information on the business combination.

Substantial Issuer Bid

On June 10, 2019, the Company announced its intention to purchase, for cancellation, up to $213 million of its common shares through a substantial issuer bid (“SIB”) which commenced on July 8, 2019. On August 29, 2019, the Company purchased approximately 47.3 million common shares at a price of $4.50 per share for an aggregate purchase price of approximately $213 million, of which $257 million was charged to share capital and $44 million was credited to paid in surplus.

The purchase was made in accordance with the terms and conditions of the SIB, with consideration allocated to share capital equivalent to the average carrying amount of the shares, with the excess of the carrying amount over the purchase consideration credited to paid in surplus.

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Normal Course Issuer Bid

On February 27, 2019, the Company announced that the TSX accepted the Company’s notice of intention to purchase, for cancellation, up to approximately 149.4 million Encana common shares pursuant to a NCIB over a 12-month period from March 4, 2019 to March 3, 2020.

During the nine months ended September 30, 2019, the Company purchased approximately 149.4 million common shares under its current NCIB for total consideration of approximately $1,037 million. Of the amount paid, $816 million was charged to share capital and $221 million was charged to retained earnings.

All purchases were made in accordance with the NCIB at prevailing market prices plus brokerage fees, with consideration allocated to share capital up to the average carrying amount of the shares, with any excess allocated to retained earnings.

For the nine months ended September 30, 2018 and the twelve months ended December 31, 2018, the Company purchased approximately 20.7 million common shares under the previous NCIB which was in place from February 28, 2018 to February 27, 2019 for total consideration of approximately $250 million. Of the amount paid, $102 million was charged to share capital and $148 million was charged to retained earnings.

Dividend Reinvestment Plan

On February 28, 2019, Encana suspended its dividend reinvestment plan (“DRIP”). During the twelve months ended December 31, 2018, Encana issued 69,329 common shares totaling $0.6 million under the DRIP.

Dividends

During the three months ended September 30, 2019, Encana declared and paid dividends of $0.01875 per common share totaling $24 million (2018 - $0.015 per common share totaling $14 million). During the nine months ended September 30, 2019, Encana declared and paid dividends of $0.05625 per common share totaling $77 million (2018 - $0.045 per common share totaling $43 million).

For the three and nine months ended September 30, 2018, the dividends paid included $0.1 million and $0.5 million, respectively, in common shares issued in lieu of cash dividends under the DRIP.

On October 30, 2019, the Board of Directors declared a dividend of $0.01875 per common share payable on December 31, 2019 to common shareholders of record as of December 13, 2019.

Earnings Per Common Share

The following table presents the computation of net earnings (loss) per common share:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(US$ millions, except per share amounts)	2019		2018		2019		2018
Net Earnings (Loss)	$	149	$	39	$	240	$	39
Number of Common Shares:
Weighted average common shares outstanding - Basic		1,322.8		955.1		1,308.4		962.2
Effect of dilutive securities		-		-		-		-
Weighted Average Common Shares Outstanding - Diluted		1,322.8		955.1		1,308.4		962.2
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.11	$	0.04	$	0.18	$	0.04

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Encana Stock Option Plan

Encana has share-based compensation plans that allow employees to purchase common shares of the Company. Option exercise prices are not less than the market value of the common shares on the date the options are granted. All options outstanding as at September 30, 2019 have associated Tandem Stock Appreciation Rights (“TSARs”) attached. In lieu of exercising the option, the associated TSARs give the option holder the right to receive a cash payment equal to the excess of the market price of Encana’s common shares at the time of the exercise over the original grant price. Historically, most holders of options with TSARs have elected to exercise their stock options as a Stock Appreciation Right (“SAR”) in exchange for a cash payment. As a result, outstanding TSARs are not considered potentially dilutive securities.

Encana Restricted Share Units

Encana has a share-based compensation plan whereby eligible employees and Directors are granted Restricted Share Units (“RSUs”). An RSU is a conditional grant to receive the equivalent of an Encana common share upon vesting of the RSUs and in accordance with the terms and conditions of the compensation plan and grant agreements. The Company currently settles vested RSUs in cash. As a result, RSUs are currently not considered potentially dilutive securities.  

16. Accumulated Other Comprehensive Income

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019			2018		2019			2018
Foreign Currency Translation Adjustment
Balance, Beginning of Period	$	1,014		$	1,028	$	976		$	1,029
Change in Foreign Currency Translation Adjustment		(6	)		22		32			21
Balance, End of Period	$	1,008		$	1,050	$	1,008		$	1,050
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Period	$	(2	)	$	12	$	22		$	13
Plan Amendment		-			-		(29	)		-
Income Taxes		-			-		6			-
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 20)		-			-		(1	)		(1	)
Income Taxes		-			-		-			-
Balance, End of Period	$	(2	)	$	12	$	(2	)	$	12
Total Accumulated Other Comprehensive Income	$	1,006		$	1,062	$	1,006		$	1,062

During the nine months ended September 30, 2019, Encana amended the other post-employment benefits arrangements in conjunction with the integration of the Newfield business acquired. The plan amendment resulted in an increase to pension liabilities with a corresponding loss recognized in other comprehensive income.

17. Variable Interest Entities

Veresen Midstream Limited Partnership

Veresen Midstream Limited Partnership (“VMLP”) provides gathering, compression and processing services under various agreements related to the Company’s development of liquids and natural gas production in the Montney play. As at September 30, 2019, VMLP provides approximately 1,206 MMcf/d of natural gas gathering and compression and 939 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from up to 12 to 26 years and have various renewal terms providing up to a potential maximum of 10 years.

Encana has determined that VMLP is a VIE and that Encana holds variable interests in VMLP. Encana is not the primary beneficiary as the Company does not have the power to direct the activities that most significantly impact VMLP’s economic performance. These key activities relate to the construction, operation, maintenance and marketing of the assets owned by VMLP. The variable interests arise from certain terms under the various long-term service agreements and include: i) a take or pay for volumes in certain agreements; ii) an operating fee of which a portion can be converted into a fixed fee once

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VMLP assumes operatorship of certain assets; and iii) a potential payout of minimum costs in certain agreements. The potential payout of minimum costs will be assessed in the eighth year of the assets’ service period and is based on whether there is an overall shortfall of total system cash flows from natural gas gathered and compressed under certain agreements. The potential payout amount can be reduced in the event VMLP markets unutilized capacity to third-party users. Encana is not required to provide any financial support or guarantees to VMLP.

As a result of Encana’s involvement with VMLP, the maximum total exposure, which represents the potential exposure to Encana in the event the assets under the agreements are deemed worthless, is estimated to be $2,359 million as at September 30, 2019. The estimate comprises the take or pay volume commitments and the potential payout of minimum costs. The take or pay volume commitments associated with certain gathering and processing assets are included in Note 24 under Transportation and Processing. The potential payout requirement is highly uncertain as the amount is contingent on future production estimates, pace of development and the amount of capacity contracted to third parties. As at September 30, 2019, there were no accounts payable and accrued liabilities outstanding related to the take or pay commitment.

18. Restructuring Charges

In February 2019, in conjunction with the Newfield business combination as described in Note 8, Encana announced workforce reductions to better align staffing levels and the organizational structure with the Company’s strategy. During the three and nine months ended September 30, 2019, the Company incurred total restructuring charges of $4 million and $134 million, respectively, before tax, primarily related to severance costs. As at September 30, 2019, $4 million remains accrued and is expected to be paid during the remainder of 2019 and in 2020.

Restructuring charges are included in administrative expense presented in the Corporate and Other segment in the Condensed Consolidated Statement of Earnings.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Severance and Benefits	$	4	$	-	$	132	$	-
Outplacement, Moving and Other Expenses		-		-		2		-
Restructuring Expenses	$	4	$	-	$	134	$	-

	As at			As at
	September 30,			December 31,
	2019			2018
Outstanding Restructuring Accrual, Beginning of Year	$	-		$	-
Restructuring Expenses Incurred		134			-
Restructuring Costs Paid		(130	)		-
Outstanding Restructuring Accrual, End of Period (1)	$	4		$	-

(1) Included in accounts payable and accrued liabilities in the Condensed Consolidated Balance Sheet.

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19. Compensation Plans

Encana has a number of compensation arrangements under which the Company awards various types of long-term incentive grants to eligible employees and Directors. They may include TSARs, Performance TSARs, SARs, Performance Share Units (“PSUs”), Deferred Share Units (“DSUs”) and RSUs. These compensation arrangements are share-based.  

Encana accounts for TSARs, Performance TSARs, SARs, PSUs and RSUs as cash-settled share-based payment transactions and, accordingly, accrues compensation costs over the vesting period based on the fair value of the rights determined using the Black-Scholes-Merton and other fair value models.  

The following weighted average assumptions were used to determine the fair value of the share units outstanding:  

	As at September 30, 2019		As at September 30, 2018
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units
Risk Free Interest Rate	1.58%	1.58%	2.18%	2.18%
Dividend Yield	1.63%	1.64%	0.46%	0.46%
Expected Volatility Rate (1)	44.14%	42.77%	55.44%	51.90%
Expected Term	2.9 yrs	2.6 yrs	1.6 yrs	2.0 yrs
Market Share Price	US$4.60	C$6.07	US$13.11	C$16.93

(1) Volatility was estimated using historical rates.

The Company has recognized the following share-based compensation costs:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Total Compensation Costs of Transactions Classified as Cash-Settled	$	2		$	36		$	46		$	118
Less: Total Share-Based Compensation Costs Capitalized		(1	)		(11	)		(16	)		(33	)
Total Share-Based Compensation Expense (Recovery)	$	1		$	25		$	30		$	85
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	-		$	8		$	12		$	24
Administrative		1			17			18			61
	$	1		$	25		$	30		$	85

As at September 30, 2019, the liability for share-based payment transactions totaled $65 million ($165 million as at December 31, 2018), of which $36 million ($131 million as at December 31, 2018) is recognized in accounts payable and accrued liabilities and $29 million ($34 million as at December 31, 2018) is recognized in other liabilities and provisions in the Condensed Consolidated Balance Sheet.

	As at September 30, 2019			As at December 31, 2018
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested		$	53		$	148
Vested			12			17
		$	65		$	165

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The following units were granted primarily in conjunction with the Company’s annual grant of long-term incentive awards. The TSARs, SARs, PSUs and RSUs were granted at the volume-weighted average trading price of Encana’s common shares for the five days prior to the grant date.

Nine Months Ended September 30, 2019 (thousands of units)
TSARs	1,244
SARs	1,718
PSUs	7,833
DSUs	111
RSUs	11,004

20. Pension and Other Post-Employment Benefits

The Company has recognized total benefit plans expense which includes pension benefits and other post-employment benefits (“OPEB”) for the nine months ended September 30 as follows:

	Pension Benefits				OPEB				Total
	2019		2018		2019		2018		2019		2018
Net Defined Periodic Benefit Cost	$	1	$	1	$	13	$	5	$	14	$	6
Defined Contribution Plan Expense		18		17		-		-		18		17
Total Benefit Plans Expense	$	19	$	18	$	13	$	5	$	32	$	23

Of the total benefit plans expense, $20 million (2018 - $17 million) was included in operating expense and $6 million (2018 - $6 million) was included in administrative expense. Excluding service costs, net defined periodic benefit costs of $6 million (2018 - nil) were recorded in other (gains) losses, net.

The net defined periodic benefit cost for the nine months ended September 30 is as follows:

	Defined Benefits						OPEB						Total
	2019			2018			2019			2018			2019			2018
Service Cost	$	1		$	1		$	7		$	5		$	8		$	6
Interest Cost		5			5			3			2			8			7
Expected Return on Plan Assets		(5	)		(6	)		-			-			(5	)		(6	)
Amounts Reclassified from Accumulated Other     Comprehensive Income:
Amortization of net actuarial (gains) and losses		-			1			(1	)		(2	)		(1	)		(1	)
Curtailment		-			-			4			-			4			-
Total Net Defined Periodic Benefit Cost (1)	$	1		$	1		$	13		$	5		$	14		$	6

(1) The components of total net defined periodic benefit cost, excluding the service cost component, are included in other (gains) losses, net.

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21. Fair Value Measurements

The fair values of cash and cash equivalents, accounts receivable and accrued revenues, and accounts payable and accrued liabilities approximate their carrying amounts due to the short-term maturity of those instruments. The fair values of restricted cash and marketable securities included in other assets approximate their carrying amounts due to the nature of the instruments held.

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note 22. These items are carried at fair value in the Condensed Consolidated Balance Sheet and are classified within the three levels of the fair value hierarchy in the following tables. There have been no significant transfers between the hierarchy levels during the period.

Fair value changes and settlements for amounts related to risk management assets and liabilities are recognized in revenues and foreign exchange gains and losses according to their purpose.

As at September 30, 2019	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	256	$	92	$	348	$	(68	)	$	280
Long-term assets		-		59		22		81		(35	)		46
Foreign Currency Derivatives:
Current assets		-		4		-		4		-			4
Long-term assets		-		1		-		1		-			1
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	78	$	-	$	78	$	(68	)	$	10
Long-term liabilities		-		49		-		49		(35	)		14
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	2	$	-	$	2	$	-		$	2
Long-term in other liabilities and provisions		-		8		-		8		-			8

As at December 31, 2018	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	492	$	139	$	631	$	(77	)	$	554
Long-term assets		-		177		-		177		(16	)		161
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	81	$	-	$	81	$	(77	)	$	4
Long-term liabilities		-		38		-		38		(16	)		22
Foreign Currency Derivatives:
Current liabilities		-		21		-		21		-			21
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	4	$	-	$	4	$	-		$	4
Long-term in other liabilities and provisions		-		10		-		10		-			10

(1) Netting to offset derivative assets and liabilities where the legal right and intention to offset exists, or where counterparty master netting arrangements contain provisions for net settlement.

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The Company’s Level 1 and Level 2 risk management assets and liabilities consist of commodity fixed price contracts, fixed price swaptions, NYMEX costless collars, NYMEX call options, NYMEX three-way options, foreign currency swaps and basis swaps with terms to 2025. Level 2 also includes financial guarantee contracts as discussed in Note 22. The fair values of these contracts are based on a market approach and are estimated using inputs which are either directly or indirectly observable from active markets, such as exchange and other published prices, broker quotes and observable trading activity throughout the term of the instruments.  

Level 3 Fair Value Measurements

As at September 30, 2019, the Company’s Level 3 risk management assets and liabilities consist of WTI three-way options and WTI costless collars with terms to 2020. The WTI three-way options are a combination of a sold call, bought put and a sold put. The WTI costless collars are a combination of a sold call and a bought put. These contracts allow the Company to participate in the upside of commodity prices to the ceiling of the call option and provide the Company with complete (collars) or partial (three-way) downside price protection through the put options. The fair values of the WTI three-way options and WTI costless collars are based on the income approach and are modelled using observable and unobservable inputs such as implied volatility. The unobservable inputs are obtained from third parties whenever possible and reviewed by the Company for reasonableness.

A summary of changes in Level 3 fair value measurements for the nine months ended September 30 is presented below:

	Risk Management
	2019			2018
Balance, Beginning of Year	$	139		$	(51	)
Total Gains (Losses)		24			(177	)
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances		-			-
Settlements		(49	)		80
Transfers Out of Level 3 (1)		-			-
Balance, End of Period	$	114		$	(148	)
Change in Unrealized Gains (Losses) Related to    Assets and Liabilities Held at End of Period	$	83		$	(136	)

(1) The Company’s policy is to recognize transfers out of Level 3 on the date of the event of change in circumstances that caused the transfer.

Quantitative information about unobservable inputs used in Level 3 fair value measurements is presented below:

	Valuation Technique	Unobservable Input	As at September 30, 2019	As at December 31, 2018
Risk Management - WTI Options	Option Model	Implied Volatility	22% - 61%	29% - 73%

A 10 percent increase or decrease in implied volatility for the WTI options would cause an approximate corresponding $9 million ($6 million as at December 31, 2018) increase or decrease to net risk management assets and liabilities.

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22. Financial Instruments and Risk Management

A)  Financial Instruments

Encana’s financial assets and liabilities are recognized in cash and cash equivalents, accounts receivable and accrued revenues, other assets, accounts payable and accrued liabilities, risk management assets and liabilities, long-term debt, and other liabilities and provisions.

B)  Risk Management Activities

Encana uses derivative financial instruments to manage its exposure to cash flow variability from commodity prices and fluctuating foreign currency exchange rates. The Company does not apply hedge accounting to any of its derivative financial instruments. As a result, gains and losses from changes in the fair value are recognized in net earnings.

Commodity Price Risk

Commodity price risk arises from the effect that fluctuations in future commodity prices may have on future cash flows. To partially mitigate exposure to commodity price risk, the Company has entered into various derivative financial instruments.  The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors. The Company’s policy is to not use derivative financial instruments for speculative purposes.  

Crude Oil and NGLs - To partially mitigate crude oil and NGL commodity price risk, the Company uses WTI-based contracts such as fixed price contracts, fixed price swaptions, options and costless collars. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

Natural Gas - To partially mitigate natural gas commodity price risk, the Company uses NYMEX-based contracts such as fixed price contracts, fixed price swaptions, options and costless collars. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

Foreign Exchange Risk

Foreign exchange risk arises from changes in foreign currency exchange rates that may affect the fair value or future cash flows of the Company’s financial assets or liabilities. To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts. As at September 30, 2019, Encana has entered into $250 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7516 to C$1, which mature monthly through the remainder of 2019 and $425 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7483 to C$1, which mature monthly throughout 2020.

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Risk Management Positions as at September 30, 2019

	Notional Volumes	Term	Average Price		Fair Value
Crude Oil and NGL Contracts			US$/bbl
Fixed Price Contracts
WTI Fixed Price	45.0 Mbbls/d	2019		60.24	$	26
WTI Fixed Price	24.0 Mbbls/d	2020		60.05		74
Propane Fixed Price	3.8 Mbbls/d	2019		35.72		11
Propane Fixed Price	1.8 Mbbls/d	2020		21.00		1
Butane Fixed Price	6.5 Mbbls/d	2019		40.54		10
Ethane Fixed Price	5.3 Mbbls/d	2019		17.23		5
WTI Fixed Price Swaptions (1)	4.0 Mbbls/d	2021		58.00		(4	)
WTI Three-Way Options
Sold call / bought put / sold put	87.5 Mbbls/d	2019	67.72 / 56.47 / 45.86			27
Sold call / bought put / sold put	80.0 Mbbls/d	2020	61.68 / 53.44 / 43.44			54
WTI Costless Collars
Sold call / bought put	43.0 Mbbls/d	2019	65.57 / 56.28			13
Sold call / bought put	15.0 Mbbls/d	2020	68.71 / 50.00			20
Basis Contracts (2)		2019				(19	)
		2020				(34	)
Crude Oil and NGLs Fair Value Position						184
Natural Gas Contracts			US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	687 MMcf/d	2019		2.72		19
NYMEX Fixed Price	653 MMcf/d	2020		2.69		64
NYMEX Fixed Price Swaptions (3)	180 MMcf/d	2021		2.61		(9	)
NYMEX Three-Way Options
Sold call / bought put / sold put	330 MMcf/d	2020	2.72 / 2.60 / 2.25			7
NYMEX Costless Collars
Sold call / bought put	177 MMcf/d	2019	3.05 / 2.89			8
Sold call / bought put	55 MMcf/d	2020	2.88 / 2.50			4
NYMEX Call Options
Sold call	230 MMcf/d	2019		3.75		-
Bought call	230 MMcf/d	2019		3.75		(1	)
Sold call	230 MMcf/d	2020		3.25		4
Basis Contracts (4)		2019				10
		2020				30
		2021				(2	)
		2022 - 2025				(8	)
Other Financial Positions						(1	)
Natural Gas Fair Value Position						125
Net Premiums Received on Unexpired Options						(7	)
Other Derivative Contracts
Fair Value Position						(10	)
Foreign Currency Contracts
Fair Value Position (5)		2019 - 2020				5
Total Fair Value Position and Net Premiums Received					$	297

(1) WTI Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(2) Encana has entered into crude and NGL differential swaps associated with Midland, Magellan East Houston, Belvieu, Conway, Brent, Louisiana Light Sweet and WTI.

(3) NYMEX Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(4) Encana has entered into natural gas basis swaps associated with AECO, Dawn, Chicago, Malin, Waha, Houston Ship Channel and NYMEX.

(5) Encana has entered into U.S. dollar denominated fixed-for-floating average currency swaps to protect against fluctuations between the Canadian and U.S. dollars.

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Earnings Impact of Realized and Unrealized Gains (Losses) on Risk Management Positions

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	122		$	(77	)	$	301		$	(95	)
Foreign Currency Derivatives:
Foreign exchange		2			1			1			11
	$	124		$	(76	)	$	302		$	(84	)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	(41	)	$	(164	)	$	(385	)	$	(422	)
Foreign Currency Derivatives:
Foreign exchange		(11	)		9			26			(17	)
	$	(52	)	$	(155	)	$	(359	)	$	(439	)
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	81		$	(241	)	$	(84	)	$	(517	)
Foreign Currency Derivatives:
Foreign exchange		(9	)		10			27			(6	)
	$	72		$	(231	)	$	(57	)	$	(523	)

(1) Includes realized gains of $2 million and $5 million for the three and nine months ended September 30, 2019, respectively, (2018 - gains of $2 million and $5 million, respectively) related to other derivative contracts.

(2) Includes unrealized losses of nil and $1 million for the three and nine months ended September 30, 2019, respectively, (2018 - losses of nil and $1 million, respectively) related to other derivative contracts.

Reconciliation of Unrealized Risk Management Positions from January 1 to September 30

	2019						2018
	Fair Value			Total Unrealized Gain (Loss)			Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	654
Change in Fair Value of Contracts in Place at Beginning of Year    and Contracts Entered into During the Period		(57	)	$	(57	)	$	(523	)
Settlement of Other Derivative Contracts		5
Amortization of Option Premiums During the Period		(3	)
Fair Value of Contracts Realized During the Period		(302	)		(302	)		84
Fair Value of Contracts and Net Premiums Received, End of Period	$	297		$	(359	)	$	(439	)

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value.  See Note 21 for a discussion of fair value measurements.

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Unrealized Risk Management Positions

	As at		As at
	September 30,		December 31,
	2019		2018
Risk Management Assets
Current	$	284	$	554
Long-term		47		161
		331		715
Risk Management Liabilities
Current		10		25
Long-term		14		22
		24		47
Other Derivative Contracts
Current in accounts payable and accrued liabilities		2		4
Long-term in other liabilities and provisions		8		10
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	297	$	654

C)  Credit Risk

Credit risk arises from the potential that the Company may incur a loss if a counterparty to a financial instrument fails to meet its obligation in accordance with agreed terms. While exchange-traded contracts are subject to nominal credit risk due to the financial safeguards established by the NYSE and the TSX, over-the-counter traded contracts expose Encana to counterparty credit risk. This credit risk exposure is mitigated through the use of credit policies approved by the Board of Directors governing the Company’s credit portfolio including credit practices that limit transactions according to counterparties’ credit quality. Mitigation strategies may include master netting arrangements, requesting collateral and/or transacting credit derivatives. The Company executes commodity derivative financial instruments under master agreements that have netting provisions that provide for offsetting payables against receivables. As a result of netting provisions, the Company’s maximum exposure to loss under derivative financial instruments due to credit risk is limited to the net amounts due from the counterparties under the derivative contracts, as disclosed in Note 21. As at September 30, 2019, the Company had no significant credit derivatives in place and held no collateral.

As at September 30, 2019, cash equivalents include high-grade, short-term securities, placed primarily with financial institutions and companies with strong investment grade ratings. Any foreign currency agreements entered into are with major financial institutions that have investment grade credit ratings.  

A substantial portion of the Company’s accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risks. As at September 30, 2019, approximately 96 percent (97 percent as at December 31, 2018) of Encana’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

As at September 30, 2019, Encana had three counterparties whose net settlement position individually accounted for more than 10 percent of the fair value of the outstanding in-the-money net risk management contracts by counterparty. These counterparties accounted for 20 percent, 13 percent and 13 percent of the fair value of the outstanding in-the-money net risk management contracts. As at December 31, 2018, Encana had four counterparties whose net settlement position accounted for 30 percent, 13 percent, 12 percent and 10 percent of the fair value of the outstanding in-the-money net risk management contracts.

During 2015 and 2017, Encana entered into agreements resulting from divestitures, which may require Encana to fulfill certain payment obligations on the take or pay volume commitments assumed by the purchasers. The circumstances that would require Encana to perform under the agreements include events where a purchaser fails to make payment to the guaranteed party and/or a purchaser is subject to an insolvency event. The agreements have remaining terms from two to five years with a fair value recognized of $10 million as at September 30, 2019 ($14 million as at December 31, 2018). The

39

maximum potential amount of undiscounted future payments is $154 million as at September 30, 2019, and is considered unlikely.

23. Supplementary Information

Supplemental disclosures to the Condensed Consolidated Statement of Cash Flows are presented below:

A) Net Change in Non-Cash Working Capital

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Operating Activities
Accounts receivable and accrued revenues	$	61		$	(8	)	$	178		$	(152	)
Accounts payable and accrued liabilities		(82	)		59			(66	)		99
Current portion of operating lease liabilities		(9	)		-			52			-
Income tax receivable and payable		(2	)		262			(34	)		252
	$	(32	)	$	313		$	130		$	199

B) Non-Cash Activities

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 14)	$	2		$	3		$	13		$	13
Property, plant and equipment accruals		(80	)		(20	)		(33	)		61
Capitalized long-term incentives		1			11			(31	)		6
Property additions/dispositions (swaps)		63			55			66			195
New ROU operating lease assets and liabilities (See Note 11)		(1	)		-			(11	)		-
Non-Cash Financing Activities
Common shares issued in conjunction with the Newfield business    combination (See Note 8)	$	-		$	-		$	(3,478	)	$	-
Common shares issued under dividend reinvestment plan (See Note 15)		-			-			-			-

24. Commitments and Contingencies

Commitments

The following table outlines the Company’s commitments as at September 30, 2019:

	Expected Future Payments
(undiscounted)	2019		2020		2021		2022		2023		Thereafter		Total
Transportation and Processing	$	197	$	731	$	625	$	594	$	485	$	2,407	$	5,039
Drilling and Field Services		64		24		6		-		-		-		94
Building Leases		4		15		14		11		7		15		66
Total	$	265	$	770	$	645	$	605	$	492	$	2,422	$	5,199

Associated with the adoption of Topic 842, all operating leases were recognized on the Condensed Consolidated Balance Sheet. Accordingly, operating leases with terms greater than one year are not included in the commitments table above. The table above includes short-term leases with contract terms less than 12 months, such as drilling rigs and field office leases, as well as non-lease operating cost components associated with building leases. See Notes 2 and 11 for additional disclosures on leases.

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Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note 17. Divestiture transactions can reduce certain commitments disclosed above.

Contingencies

Encana is involved in various legal claims and actions arising in the normal course of the Company’s operations. Although the outcome of these claims cannot be predicted with certainty, the Company does not expect these matters to have a material adverse effect on Encana’s financial position, cash flows or results of operations. Management’s assessment of these matters may change in the future as certain of these matters are in early stages or are subject to a number of uncertainties. For material matters that the Company believes an unfavorable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures. If an unfavorable outcome were to occur, there exists the possibility of a material impact on the Company’s consolidated net earnings or loss for the period in which the effect becomes reasonably estimable. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. Such accruals are based on the Company’s information known about the matters, estimates of the outcomes of such matters and experience in handling similar matters.

In conjunction with the acquisition of Newfield as described in Note 8, various legal claims and actions arising in the normal course of Newfield’s operations were assumed by Encana. On March 29, 2019, Newfield and its wholly-owned subsidiary entered into an Agreement and Mutual Release with Sapura Energy Berhad, formerly known as SapuraKencana Petroleum Berhad, and Sapura Exploration and Production Inc., formerly known as SapuraKencana Energy Inc. (collectively, “Sapura”) to settle arbitration claims arising from Sapura’s purchase of Newfield’s Malaysian business in February 2014. Under the Agreement and Mutual Release, Newfield and its wholly-owned subsidiary paid Sapura $22.5 million. The settlement amount including legal fees was included in the purchase price allocation as part of the current liabilities assumed by Encana at the acquisition date. Although the outcome of any remaining legal claims and actions assumed by Encana following the acquisition of Newfield cannot be predicted with certainty, the Company does not expect these matters to have a material adverse effect on Encana’s financial position, cash flows or results of operations.

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

The MD&A is intended to provide a narrative description of Encana’s business from management’s perspective. This MD&A should be read in conjunction with the unaudited interim Condensed Consolidated Financial Statements and accompanying notes for the period ended September 30, 2019 (“Consolidated Financial Statements”), which are included in Part I, Item 1 of this Quarterly Report on Form 10-Q and the audited Consolidated Financial Statements and accompanying notes and MD&A for the year ended December 31, 2018, which are included in Items 8 and 7, respectively, of the 2018 Annual Report on Form 10‑K. Common industry terms and abbreviations are used throughout this MD&A and are defined in the Definitions, Conversions and Conventions sections of this Quarterly Report on Form 10-Q. This MD&A includes the following sections:

• Executive Overview

• Results of Operations

• Liquidity and Capital Resources

• Non-GAAP Measures

Executive Overview

Strategy

Encana is a leading North American energy producer that is focused on developing its multi-basin portfolio of oil, NGLs and natural gas producing plays. Encana is committed to growing long-term shareholder value through a combination of profitable growth and generating cash flows in excess of capital expenditures. The Company is pursuing the key business objectives of preserving balance sheet strength, maximizing profitability through operational and capital efficiencies, returning capital to shareholders through sustainable dividends, and driving cash flow through a disciplined capital allocation strategy by investing in a limited number of core assets with high margin liquids.

In executing its strategy, Encana focuses on its core values of One, Agile and Driven, which guide the organization to be flexible, responsive, determined and motivated with a commitment to excellence and a passion to succeed as a team. Encana rapidly deploys successful ideas and practices across its assets, becoming more efficient as innovative and sustainable improvements are implemented.

Encana continually reviews and evaluates its strategy and changing market conditions. In 2019, Encana is focusing on quality cash flow growth from high margin, scalable, top tier assets located in some of the best plays in North America, referred to as the “Core Assets”. As at September 30, 2019, these comprised Permian and Anadarko in the U.S., and Montney in Canada. These top tier assets form a multi-basin portfolio of oil, NGLs and natural gas producing plays enabling flexible and efficient investment of capital into high margin liquids plays that support sustainable cash flow generation. The Company’s other upstream assets, including Eagle Ford, Duvernay, Williston and Uinta continue to deliver operating cash flows for the Company.

For additional information on Encana’s strategy, its reporting segments and the plays in which the Company operates as at December 31, 2018, refer to Items 1 and 2 of the 2018 Annual Report on Form 10-K. On February 13, 2019, Encana completed the acquisition of Newfield; as such, the post-acquisition results of operations of Newfield are included in the Company’s interim consolidated results beginning February 14, 2019. For additional information on the business combination and segmented results, refer to Notes 8 and 3, respectively, to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. For additional information on the reserves volumes acquired with the Newfield acquisition, refer to Exhibit 99.4 in the Company’s Current Report on Form 8-K filed on February 28, 2019 regarding Supplemental Pro Forma Oil, Natural Gas Liquids and Natural Gas Reserves Information as of December 31, 2018.

In evaluating its operations and assessing its leverage, the Company reviews performance-based measures such as Non‑GAAP Cash Flow, Non-GAAP Cash Flow Margin, Total Costs and debt-based metrics such as Debt to Adjusted Capitalization and Net Debt to Adjusted EBITDA, which are non-GAAP measures and do not have any standardized meaning under U.S. GAAP. These measures may not be similar to measures presented by other issuers and should not be viewed as a substitute for measures reported under U.S. GAAP. Additional information regarding these measures, including reconciliations to the closest GAAP measure, can be found in the Non-GAAP Measures section of this MD&A.

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Highlights

During the first nine months of 2019, Encana focused on executing its 2019 capital plan, generating cash from operating activities and returning capital to shareholders through dividends and share buybacks. Since the completion of the Newfield acquisition in February, the Company has fully integrated the businesses and is on track to exceed the synergies previously announced from the strategic combination. Higher upstream product revenues in the first nine months of 2019 compared to 2018 resulted from higher production volumes, partially offset by lower average realized prices, excluding the impact of risk management activities. Total production volumes increased by 60 percent compared to 2018 primarily due to the Newfield acquisition and successful drilling programs. Decreases in average realized liquids and natural gas prices of 23 percent and nine percent, respectively, were primarily due to lower benchmark prices. Encana continues to focus on optimizing realized prices from the diversification of the Company’s downstream markets.

Significant Developments

• Completed the acquisition of all issued and outstanding shares of common stock of Newfield whereby Encana issued approximately 543.4 million common shares on February 13, 2019. The acquired operations are focused on the development of oil-rich properties primarily located in the Anadarko Basin in Oklahoma. Following the acquisition, Newfield’s senior notes totaling $2.45 billion remain outstanding.

• Purchased, for cancellation, approximately 149.4 million common shares for total consideration of approximately $1,037 million, thereby fully executing the Company’s previously announced NCIB for up to 10 percent of Encana’s public float of common shares.

• Purchased, for cancellation, approximately 47.3 million common shares for total consideration of approximately $213 million, thereby fully executing the Company’s previously announced substantial issuer bid.

• Terminated the Company’s production sharing contract with the China National Offshore Oil Corporation (“CNOOC”), which governed Encana’s China Operations, effective July 31, 2019. Subsequently, Encana no longer has operations in China.

• Completed the sale of the Company’s Arkoma Basin natural gas assets on August 27, 2019, comprising approximately 140,000 net acres in Oklahoma, for proceeds of $155 million, after closing adjustments.

Financial Results

Three months ended September 30, 2019

• Reported net earnings of $149 million, including net gains on risk management in revenues of $81 million, before tax, and a net foreign exchange loss of $30 million, before tax.

• Generated cash from operating activities of $756 million, Non-GAAP Cash Flow of $817 million and Non‑GAAP Cash Flow Margin of $14.67 per BOE.

• Returned capital to shareholders through the purchase, for cancellation, of approximately 47.3 million common shares for total consideration of approximately $213 million and paid dividends of $0.01875 per common share totaling $24 million.

Nine months ended September 30, 2019

• Reported net earnings of $240 million, including restructuring charges of $134 million, before tax, a net loss on risk management in revenues of $84 million, before tax, a net foreign exchange gain of $62 million, before tax, and acquisition costs of $33 million, before tax.

• Generated cash from operating activities of $2,191 million, Non-GAAP Cash Flow of $2,116 million and Non‑GAAP Cash Flow Margin of $13.95 per BOE.

• Returned capital to shareholders through the purchase, for cancellation, of approximately 196.7 million common shares for total consideration of approximately $1,250 million and paid dividends of $0.05625 per common share totaling $77 million.

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• Held cash and cash equivalents of $138 million and had $4.0 billion in available credit facilities of which Encana’s $2.5 billion revolving credit facility supported the issuance of $740 million of commercial paper as at September 30, 2019.

Capital Investment

• Directed $467 million, or 83 percent, of total capital spending to Permian, Anadarko and Montney in the third quarter of 2019 and $1,554 million, or 76 percent, during the first nine months of 2019.

• Focused on highly efficient capital activity and short-cycle high margin projects providing flexibility to respond to fluctuations in commodity prices.

Production

Three months ended September 30, 2019

• Produced average oil and NGL volumes of 329.2 Mbbls/d which accounted for 54 percent of total production volumes. Average oil and plant condensate production volumes of 237.3 Mbbls/d were 72 percent of total liquids production volumes.

• Produced average natural gas volumes of 1,655 MMcf/d which accounted for 46 percent of total production volumes.

Nine months ended September 30, 2019

• Produced average oil and NGL volumes of 295.2 Mbbls/d which accounted for 53 percent of total production volumes. Average oil and plant condensate production volumes of 214.4 Mbbls/d were 73 percent of total liquids production volumes.

• Produced average natural gas volumes of 1,562 MMcf/d which accounted for 47 percent of total production volumes.

Revenues and Operating Expenses

• Focused on market diversification to other downstream markets to optimize realized commodity prices and revenues through a combination of derivative financial instruments and transportation contracts.

• Continued to benefit from secured pipeline transportation capacity to the Dawn and Houston markets to protect against AECO and Midland differentials to NYMEX and WTI, respectively; maintained access to local markets through existing transportation contracts.

• Incurred Total Costs in the third quarter and the first nine months of 2019 of $11.95 per BOE and $12.66 per BOE, respectively, a decrease compared to 2018 of $0.65 per BOE and $0.57 per BOE, respectively. Total Costs includes production, mineral and other taxes, upstream transportation and processing expense, upstream operating expense and administrative expense. Total Costs excludes the impact of long-term incentive and restructuring costs. Significant items in the third quarter and the first nine months of 2019 impacting Total Costs include:

o Lower upstream transportation and processing expense in the third quarter and the first nine months of 2019 compared to 2018 of $1.00 per BOE and $0.93 per BOE, respectively, primarily due to the higher proportion of total production volumes from the USA Operations, which benefit from lower than average per BOE transportation and processing costs. Production volumes in the USA Operations were higher in the third quarter and first nine months of 2019 compared to 2018 due to the Newfield acquisition; and

o Higher administrative expense, excluding long-term incentive costs and restructuring costs, in the third quarter and the first nine months of 2019 compared to 2018 of $0.21 per BOE and $0.23 per BOE, respectively, primarily due to the change in accounting treatment for The Bow office building.

• Preserved operational efficiencies achieved in previous years and minimized the effect of inflationary costs.

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Subsequent Event

On October 31, 2019, the Company announced its intention to complete a corporate reorganization (the “Reorganization”) which includes (i) a proposed plan of arrangement under the Canada Business Corporations Act involving, among others, Encana, Encana securityholders and a wholly-owned subsidiary of Encana to be named Ovintiv Inc. (“Ovintiv”), pursuant to which, among other things, Encana will complete a share consolidation on the basis of one post-consolidation share for each five pre-consolidation shares and Ovintiv will ultimately acquire all of the issued and outstanding Encana common shares in exchange for shares of Ovintiv on a one-for-one basis and become the parent company of Encana and its subsidiaries (collectively, the “Arrangement”), and (ii) as soon as practicable following the Arrangement, Ovintiv migrating out of Canada and becoming a Delaware corporation. Following completion of the Reorganization, Ovintiv and its subsidiaries will continue to carry on the business currently conducted by Encana and its subsidiaries. Subject to receipt of securityholder, stock exchange and court approvals, as well as the satisfaction of other conditions precedent, the Reorganization is expected to be completed in 2020.

2019 Outlook

Industry Outlook

The oil and gas industry is cyclical and commodity prices are inherently volatile. Oil prices during 2019 are expected to reflect global supply and demand dynamics as well as the geopolitical and macroeconomic environment. At a meeting in December 2018, OPEC and certain non-OPEC countries (collectively “OPEC”) agreed to reduce crude oil production, beginning in January 2019 for an initial period of six months, seeking to balance the global oil market in response to changing fundamentals. In July 2019, OPEC agreed to extend production cuts for an additional period of nine months from July 2019 to March 2020. Risks to the global economy, including trade disputes, U.S. sanctions policy, U.S. production growth, and potential oil supply outages in major producing countries resulting from geopolitical instability, could further contribute to price volatility in 2019. OPEC is scheduled to meet again in December 2019 to review production levels which could potentially result in other supply adjustments and contribute to price fluctuations.

Natural gas prices in 2019 will be affected by the timing of supply and demand growth and the effects of seasonal weather. Natural gas prices in western Canada have seen significant negative price pressure as strong supply continues to surpass regional demand and stress effective pipeline capacity. Despite initial price strength related to lower than normal storage in 2019, mild summer weather and continued production increases in both the northeast U.S. and associated gas production in the Permian Basin are putting downward pressure on U.S. natural gas prices. As a result, potential for improvement in longer-term U.S. natural gas prices remains limited.

Company Outlook

Encana is well positioned in the current price environment to balance moderate liquids growth with the generation of cash flows in excess of capital expenditures. The Company enters into derivative financial instruments which mitigate price volatility and help sustain revenues during periods of lower prices. A portion of the Company’s production is sold at prevailing market prices which also allows Encana to participate in potential price increases. As at September 30, 2019, the Company has hedged approximately 175.5 Mbbls/d of expected crude oil and condensate production and 864 MMcf/d of expected natural gas production for the remainder of the year. Additional information on Encana’s hedging program can be found in Note 22 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Markets for crude oil and natural gas are exposed to different price risks. While the market price for crude oil tends to move in the same direction as the global market, regional differentials may develop. Natural gas prices may vary between geographic regions depending on local supply and demand conditions. Encana proactively utilizes transportation contracts to diversify the Company’s downstream markets, reducing significant exposure to any given market. Through a combination of derivative financial instruments and transportation capacity, Encana has mitigated the majority of its exposure to Midland and AECO pricing in 2019. In addition, Encana continues to seek new markets to yield higher returns.

The Company’s full year 2019 guidance ranges discussed within Capital Investment, Production and Operating Expenses in this Outlook section reflect the Reportable Guidance ranges.

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Capital Investment

Encana is on track to meet its updated full year 2019 capital investment guidance of $2.55 billion to $2.65 billion and expects to fund its capital program from 2019 cash generated from operating activities. During the first nine months of 2019, the Company spent $2,052 million, of which $728 million was directed to Permian with 84 net wells drilled, $556 million was directed to Anadarko with 51 net wells drilled since the Newfield acquisition closed on February 13, 2019, and $270 million was directed to Montney with 58 net wells drilled. Capital investment in the Core Assets is expected to be optimized by Encana’s cube development approach to maximize returns and recovery. Capital investment for the remainder of 2019 is expected to be primarily allocated to the Core Assets with a focus on maximizing returns from high margin liquids and to other upstream assets to optimize operating free cash flows.

Encana continually strives to improve well performance and lower costs through innovative techniques. Encana's large-scale cube development model utilizes multi-well pads and advanced completion designs to access stacked pay resource to maximize returns and resource recovery from its reservoirs. The deployment of cube development in Anadarko has reduced well costs by approximately $1.4 million per well in 2019 compared to Newfield’s 2018 well costs, exceeding the Company’s previously announced expected savings of $1 million per well. The impact of Encana’s disciplined capital program and continuous innovation create flexibility and opportunity to grow cash flows and production volumes going forward.

Production

Encana’s shift to a more balanced portfolio has reduced the extent of exposure to commodity market volatility and positioned the Company to generate sustainable future cash flows. During the first nine months of 2019, average liquids production volumes were 295.2 Mbbls/d, or 53 percent of total production volumes, and average natural gas production volumes were 1,562 MMcf/d, or 47 percent of total production volumes. The Company has updated its full year 2019 production volume guidance ranges for liquids to 297.0 Mbbls/d to 301.0 Mbbls/d and for natural gas to 1,560 MMcf/d to 1,575 MMcf/d. Encana is on track to meet its updated full year 2019 production volume guidance ranges as the Company executes the remainder of its capital plans for its Core Assets.

Operating Expenses

For 2019, Encana lowered its guidance range for Total Costs to $12.60 per BOE to $12.90 per BOE and expects Total Costs for the year to be approximately $12.75 per BOE. Total Costs includes production, mineral and other taxes, upstream transportation and processing expense, upstream operating expense and administrative expense. Total Costs excludes the impact of long-term incentive and restructuring costs. In the first nine months of 2019, Total Costs of $12.66 per BOE were below the full year 2019 guidance range as integration synergies were realized. Upstream transportation and processing expense was $6.46 per BOE, while upstream operating expense and administrative expense, excluding long-term incentive costs and restructuring costs, were $3.40 per BOE and $1.57 per BOE, respectively. Encana expects efficiency improvements and effective supply chain management, including favorable price negotiations, to offset any inflationary pressures.

Workforce reductions and operating efficiencies have reduced operating and administrative costs by $100 million to date and are expected to be reduced by approximately $200 million on an annualized basis, compared to the combined costs of Newfield and Encana prior to the acquisition. These synergies surpass the Company’s original estimate of $125 million and exclude expected restructuring costs incurred in 2019. To date, restructuring costs of $134 million have been incurred.

Additional information on Encana’s 2019 Corporate Guidance can be accessed on the Company’s website in the Corporate Presentation at www.encana.com.

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Results of Operations

Selected Financial Information

	Three months ended September 30,						Nine months ended September 30,
($ millions)		2019		2018				2019			2018
Product and Service Revenues
Upstream product revenues		$	1,476	$	1,166			$	4,315		$	3,107
Market optimization			294	317					870			909
Service revenues			1	5					6			9
Total Product and Service Revenues			1,771		1,488				5,191			4,025
Gains (Losses) on Risk Management, Net			81		(241	)			(84	)		(517	)
Sublease Revenues			19		15				54			50
Total Revenues			1,871		1,262				5,161			3,558
Total Operating Expenses (1)			1,556		1,143				4,535			3,218
Operating Income (Loss)			315		119				626			340
Total Other (Income) Expenses			123		74				243			356
Net Earnings (Loss) Before Income Tax			192		45				383			(16	)
Income Tax Expense (Recovery)			43		6				143			(55	)
Net Earnings (Loss)		$	149	$	39			$	240		$	39

(1) Total Operating Expenses include non-cash items such as DD&A, accretion of asset retirement obligations and long-term incentive costs.

Subsequent to the completion of the Newfield acquisition on February 13, 2019, the post‑acquisition results of the operations of Newfield are included in the Company’s interim consolidated results beginning February 14, 2019. As a result of the business combination and the addition of the Anadarko asset to Encana’s portfolio, the Company’s Core Assets were redefined to include Permian and Anadarko in the U.S. and Montney in Canada. The 2018 Core Assets production presentation has been updated to align with the Company’s 2019 Core Assets and reflects Permian and Montney.

Revenues

Encana’s revenues are substantially derived from sales of oil, NGLs and natural gas production. Increases or decreases in Encana’s revenue, profitability and future production are highly dependent on the commodity prices the Company receives. Prices are market driven and fluctuate due to factors beyond the Company’s control, such as supply and demand, seasonality and geopolitical and economic factors. The Canadian Operations realized prices are linked to Edmonton Condensate and AECO, as well as other downstream natural gas benchmarks, including Dawn. The USA Operations realized prices generally reflect WTI and NYMEX benchmark prices, as well as other downstream oil benchmarks, including Houston. The other downstream benchmarks reflect the diversification of the Company’s markets. Realized NGL prices are significantly influenced by oil and other benchmark prices and the NGL production mix. Recent trends in benchmark prices relevant to Encana are shown in the table below.

Benchmark Prices

	Three months ended September 30,				Nine months ended September 30,
(average for the period)	2019		2018		2019		2018
Oil & NGLs
WTI ($/bbl)	$	56.45	$	69.50	$	57.06	$	66.75
Houston ($/bbl)		61.14		73.51		62.84		70.16
Edmonton Condensate (C$/bbl)		68.70		87.34		70.21		85.30
Natural Gas
NYMEX ($/MMBtu)	$	2.23	$	2.90	$	2.67	$	2.90
AECO (C$/Mcf)		1.04		1.35		1.39		1.41
Dawn (C$/MMBtu)		2.81		3.79		3.26		3.73

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Production Volumes and Realized Prices

	Three months ended September 30,									Nine months ended September 30,
	Production Volumes (1)				Realized Prices (2)					Production Volumes (1)				Realized Prices (2)
	2019		2018			2019		2018		2019		2018			2019		2018
Oil (Mbbls/d, $/bbl)
Canadian Operations		0.7		0.3		$	58.24	$	60.32		0.5		0.4		$	51.55	$	57.83
USA Operations		177.6		95.2			55.26		66.84		159.0		87.3			56.47		65.66
China Operations (3)		0.5		-			60.35		-		2.0		-			66.37		-
Total		178.8		95.5			55.29		66.82		161.5		87.7			56.58		65.62
NGLs – Plant Condensate (Mbbls/d, $/bbl)
Canadian Operations		45.9		36.3			50.73		64.82		42.9		31.2			51.74		64.61
USA Operations		12.6		4.7			41.70		55.23		10.0		3.8			43.93		55.12
Total		58.5		41.0			48.78		63.73		52.9		35.0			50.26		63.60
NGLs – Other (Mbbls/d, $/bbl)
Canadian Operations		17.0		14.4			5.39		30.25		16.3		12.5			10.66		28.87
USA Operations		74.9		27.8			7.48		28.27		64.5		24.7			12.01		24.08
Total		91.9		42.2			7.09		28.95		80.8		37.2			11.74		25.69
Total Oil & NGLs (Mbbls/d, $/bbl)
Canadian Operations		63.6		51.0			38.65		55.03		59.7		44.1			40.52		54.44
USA Operations		265.1		127.7			41.12		58.01		233.5		115.8			43.65		56.45
China Operations (3)		0.5		-			60.35		-		2.0		-			66.37		-
Total		329.2		178.7			40.67		57.16		295.2		159.9			43.18		55.90
Natural Gas (MMcf/d, $/Mcf)
Canadian Operations		1,038		1,038			1.54		1.96		1,027		975			1.95		2.09
USA Operations		617		159			1.67		2.19		535		148			1.89		2.25
Total		1,655		1,197			1.59		1.99		1,562		1,123			1.93		2.11
Total Production (MBOE/d, $/BOE)
Canadian Operations		236.7		224.1			17.12		21.62		230.8		206.5			19.14		21.46
USA Operations		367.9		154.1			32.43		50.30		322.8		140.5			34.72		48.90
China Operations (3)		0.5		-			60.35		-		2.0		-			66.37		-
Total		605.1		378.2			26.46		33.30		555.6		347.0			28.36		32.57
Production Mix (%)
Oil & Plant Condensate		39		36							39		35
NGLs – Other		15		11							14		11
Total Oil & NGLs		54		47							53		46
Natural Gas		46		53							47		54
Production Growth
Year Over Year (%) (4)
Total Oil & NGLs		84									85
Natural Gas		38									39
Total Production		60									60
Core Assets Production (5)
Oil (Mbbls/d)		118.2		62.1							106.9		57.4
NGLs – Plant Condensate (Mbbls/d)		48.6		33.0							44.7		27.3
NGLs – Other (Mbbls/d)		80.2		32.7							70.5		28.4
Total Oil & NGLs (Mbbls/d)		247.0		127.8							222.1		113.1
Natural Gas (MMcf/d)		1,416		1,028							1,325		948
Total Production (MBOE/d)		482.8		299.1							442.9		271.0
% of Total Encana Production		80		79							80		78

(1) Average daily.

(2) Average per-unit prices, excluding the impact of risk management activities.

(3) The Company acquired its China Operations as part of the Newfield business combination on February 13, 2019. Subsequently, the Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019. Production from China Operations is presented for the period from February 14, 2019 through July 31, 2019.

(4) Includes production impacts of acquisitions and divestitures.

(5) Core Assets production presentation aligns with the Company’s 2019 Core Assets, which include Permian, Anadarko and Montney. Core Assets production for 2018 has been updated and reflects Permian and Montney.

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Upstream Product Revenues

	Three months ended September 30,
($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas (1)			Total
2018 Upstream Product Revenues	$	587		$	241		$	113		$	219		$	1,160
Increase (decrease) due to:
Sales prices		(77	)		(67	)		(86	)		(54	)		(284	)
Production volumes		399			88			33			78			598
2019 Upstream Product Revenues	$	909		$	262		$	60		$	243		$	1,474
	Nine months ended September 30,
($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas (1)			Total
2018 Upstream Product Revenues	$	1,572		$	607		$	261		$	647		$	3,087
Increase (decrease) due to:
Sales prices		(170	)		(165	)		(161	)		(70	)		(566	)
Production volumes		1,093			284			158			247			1,782
2019 Upstream Product Revenues	$	2,495		$	726		$	258		$	824		$	4,303

(1) Natural gas revenues for the third quarter and the first nine months of 2019 exclude certain other revenue and royalty adjustments with no associated production volumes of $2 million and $12 million, respectively (2018 - royalty adjustments of $6 million and $20 million, respectively).

Oil Revenues

Three months ended September 30, 2019 versus September 30, 2018

Oil revenues increased $322 million compared to the third quarter of 2018 primarily due to:

• Higher average oil production volumes of 83.3 Mbbls/d increased revenues by $399 million. Higher volumes were primarily due to the Newfield acquisition (72.7 Mbbls/d) and successful drilling programs in Anadarko, Williston and Permian (17.7 Mbbls/d), partially offset by natural declines in Eagle Ford (4.6 Mbbls/d); and

• Lower average realized oil prices of $11.53 per bbl, or 17 percent, decreased revenues by $77 million. The decrease reflected lower WTI and Houston benchmark prices which were down 19 percent and 17 percent, respectively, partially offset by strengthening regional pricing relative to the WTI benchmark price in the USA Operations.

Nine months ended September 30, 2019 versus September 30, 2018

Oil revenues increased $923 million compared to the first nine months of 2018 primarily due to:

• Higher average oil production volumes of 73.8 Mbbls/d increased revenues by $1,093 million. Higher volumes were primarily due to the Newfield acquisition (64.0 Mbbls/d) and successful drilling programs in Anadarko, Permian and Williston (15.5 Mbbls/d), partially offset by the sale of the San Juan assets in the fourth quarter of 2018 (2.2 Mbbls/d) and natural declines in Eagle Ford (2.2 Mbbls/d); and

• Lower average realized oil prices of $9.04 per bbl, or 14 percent, decreased revenues by $170 million. The decrease reflected lower WTI and Houston benchmark prices which were down 15 percent and 10 percent, respectively, partially offset by strengthening regional pricing relative to the WTI benchmark price in the USA Operations.

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NGL Revenues

Three months ended September 30, 2019 versus September 30, 2018

NGL revenues decreased $32 million compared to the third quarter of 2018 primarily due to:

• Lower average realized other NGL prices of $21.86 per bbl, or 76 percent, decreased revenues by $86 million reflecting lower other NGL benchmark prices and lower regional pricing; and

• Lower average realized plant condensate prices of $14.95 per bbl, or 23 percent, decreased revenues by $67 million. The decrease reflected lower Edmonton Condensate and WTI benchmark prices which were down 21 percent and 19 percent, respectively, as well as fluctuations in regional pricing relative to the Edmonton Condensate and WTI benchmark prices;

partially offset by:

• Higher average plant condensate production volumes of 17.5 Mbbls/d increased revenues by $88 million. Higher volumes were primarily due to successful drilling programs in Montney, Anadarko and Duvernay (12.1 Mbbls/d) and the Newfield acquisition (5.6 Mbbls/d); and

• Higher average other NGL production volumes of 49.7 Mbbls/d increased revenues by $33 million. Higher volumes were primarily due to the Newfield acquisition (35.6 Mbbls/d) and successful drilling programs in Anadarko, Permian and Montney (15.0 Mbbls/d).

Nine months ended September 30, 2019 versus September 30, 2018

NGL revenues increased $116 million compared to the first nine months of 2018 primarily due to:

• Higher average plant condensate production volumes of 17.9 Mbbls/d increased revenues by $284 million. Higher volumes were primarily due to successful drilling programs in Montney and Anadarko (12.8 Mbbls/d) and the Newfield acquisition (4.7 Mbbls/d); and

• Higher average other NGL production volumes of 43.6 Mbbls/d increased revenues by $158 million. Higher volumes were primarily due to the Newfield acquisition (29.8 Mbbls/d) and successful drilling programs in Anadarko, Montney and Permian (15.5 Mbbls/d);

partially offset by:

• Lower average realized plant condensate prices of $13.34 per bbl, or 21 percent, decreased revenues by $165 million. The decrease reflected lower Edmonton Condensate and WTI benchmark prices which were down 18 percent and 15 percent, respectively, as well as fluctuations in regional pricing relative to the Edmonton Condensate and WTI benchmark prices; and

• Lower average realized other NGL prices of $13.95 per bbl, or 54 percent, decreased revenues by $161 million reflecting lower other NGL benchmark prices and lower regional pricing.

Natural Gas Revenues

Three months ended September 30, 2019 versus September 30, 2018

Natural gas revenues increased $24 million compared to the third quarter of 2018 primarily due to:

• Higher average natural gas production volumes of 458 MMcf/d increased revenues by $78 million primarily due to the Newfield acquisition (421 MMcf/d) and successful drilling programs in Anadarko, Montney and Permian (71 MMcf/d), partially offset by increased third-party plant downtime and pipeline restrictions in Montney (20 MMcf/d), lower production in Other Upstream Operations primarily due to natural declines (8 MMcf/d) and the sale of the San Juan assets in the fourth quarter of 2018 (7 MMcf/d); and

• Lower average realized natural gas prices of $0.40 per Mcf, or 20 percent, decreased revenues by $54 million reflecting lower Dawn, NYMEX and AECO benchmark prices which were down 26 percent, 23 percent and 23 percent, respectively, partially offset by a higher proportion of total production volumes in the USA Operations with higher regional pricing resulting from the Newfield acquisition.

50

Nine months ended September 30, 2019 versus September 30, 2018

Natural gas revenues increased $177 million compared to the first nine months of 2018 primarily due to:

• Higher average natural gas production volumes of 439 MMcf/d increased revenues by $247 million primarily due to the Newfield acquisition (369 MMcf/d) and successful drilling programs in Montney, Anadarko and Permian (101 MMcf/d), partially offset by lower production in Other Upstream Operations primarily due to natural declines (14 MMcf/d) and the sale of the San Juan assets in the fourth quarter of 2018 (7 MMcf/d); and

• Lower average realized natural gas prices of $0.18 per Mcf, or nine percent, decreased revenues by $70 million reflecting lower Dawn and NYMEX benchmark prices which were down 13 percent and eight percent, respectively, partially offset by a higher proportion of total production volumes in the USA Operations with higher regional pricing resulting from the Newfield acquisition.

Gains (Losses) on Risk Management, Net

As a means of managing commodity price volatility, Encana enters into commodity derivative financial instruments on a portion of its expected oil, NGL and natural gas production volumes. The Company’s commodity price mitigation program reduces volatility and helps sustain revenues during periods of lower prices. Additional information on the Company’s commodity price positions as at September 30, 2019 can be found in Note 22 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

The following tables provide the effects of Encana’s risk management activities on revenues.

	Three months ended September 30,						Nine months ended September 30,
($ millions)	2019			2018			2019			2018
Realized Gains (Losses) on Risk Management
Commodity Price (1)
Oil	$	10		$	(87	)	$	56		$	(208	)
NGLs - Plant Condensate		9			(40	)		24			(98	)
NGLs - Other		28			(7	)		61			(7	)
Natural Gas		73			56			156			216
Other (2)		2			1			4			2
Total		122			(77	)		301			(95	)
Unrealized Gains (Losses) on Risk Management		(41	)		(164	)		(385	)		(422	)
Total Gains (Losses) on Risk Management, Net	$	81		$	(241	)	$	(84	)	$	(517	)
	Three months ended September 30,						Nine months ended September 30,
(Per-unit)	2019			2018			2019			2018
Realized Gains (Losses) on Risk Management
Commodity Price (1)
Oil ($/bbl)	$	0.63		$	(9.77	)	$	1.27		$	(8.68	)
NGLs - Plant Condensate ($/bbl)	$	1.77		$	(10.84	)	$	1.66		$	(10.31	)
NGLs - Other ($/bbl)	$	3.28		$	(1.72	)	$	2.76		$	(0.63	)
Natural Gas ($/Mcf)	$	0.48		$	0.51		$	0.37		$	0.70
Total ($/BOE)	$	2.17		$	(2.23	)	$	1.96		$	(1.02	)

(1) Includes realized gains and losses related to the Canadian and USA Operations.

(2) Other primarily includes realized gains or losses from Market Optimization and other derivative contracts with no associated production volumes.

Encana recognizes fair value changes from its risk management activities each reporting period. The changes in fair value result from new positions and settlements that occur during each period, as well as the relationship between contract prices and the associated forward curves. Realized gains or losses on risk management activities related to commodity price mitigation are included in the Canadian Operations, USA Operations and Market Optimization revenues as the contracts are cash settled. Unrealized gains or losses on fair value changes of unsettled contracts are included in the Corporate and Other segment.

51

Market Optimization Revenues

Market Optimization product revenues relate to activities that provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification. The Company also purchases and sells third-party volumes under long-term marketing arrangements associated with the Company’s previous divestitures.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018
Market Optimization	$	294	$	317	$	870	$	909

Three months ended September 30, 2019 versus September 30, 2018

Market Optimization revenues decreased $23 million compared to the third quarter of 2018 primarily due to:

• Lower benchmark prices ($68 million) and lower sales of third-party purchased natural gas volumes ($56 million);

partially offset by:

• Higher sales of third-party purchased liquids volumes primarily relating to price optimization activities and additional third-party purchases to meet sales commitments in the USA Operations ($101 million).

Nine months ended September 30, 2019 versus September 30, 2018

Market Optimization revenues decreased $39 million compared to the first nine months of 2018 primarily due to:

• Lower sales of third-party purchased natural gas volumes ($109 million) and lower benchmark prices ($104 million);

partially offset by:

• Higher sales of third-party purchased liquids volumes ($174 million) due to:

o Changing market conditions resulting in additional third-party purchases to meet sales commitments in the Canadian Operations in the first quarter of 2019; and

o Price optimization activities and additional third-party purchases to meet sales commitments in the USA Operations in the third quarter of 2019.

Sublease Revenues

Sublease revenues primarily include amounts related to the sublease of office space in The Bow office building recorded in the Corporate and Other segment. Additional information on The Bow office sublease can be found in Notes 2 and 11 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

52

Operating Expenses

Production, Mineral and Other Taxes

Production, mineral and other taxes include production and property taxes. Production taxes are generally assessed as a percentage of oil and natural gas production revenues. Property taxes are generally assessed based on the value of the underlying assets.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018
Canadian Operations	$	3	$	4	$	11	$	12
USA Operations		63		41		176		97
Total	$	66	$	45	$	187	$	109
	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018
Canadian Operations	$	0.15	$	0.20	$	0.18	$	0.22
USA Operations	$	1.85	$	2.91	$	1.99	$	2.53
Total	$	1.18	$	1.31	$	1.23	$	1.15

Three months ended September 30, 2019 versus September 30, 2018

Production, mineral and other taxes increased $21 million compared to the third quarter of 2018 primarily due to:

• Higher production volumes as a result of the Newfield acquisition ($31 million);

partially offset by:

• Lower production tax mainly as a result of lower commodity prices ($7 million) and the sale of the San Juan assets in the fourth quarter of 2018 ($2 million).

Nine months ended September 30, 2019 versus September 30, 2018

Production, mineral and other taxes increased $78 million compared to the first nine months of 2018 primarily due to:

• Higher production volumes and property values as a result of the Newfield acquisition ($84 million) and higher production volumes, effective rates and assessed property values in Permian ($17 million);

partially offset by:

• Lower production tax mainly as a result of lower commodity prices ($21 million) and the sale of the San Juan assets in the fourth quarter of 2018 ($5 million).

53

Transportation and Processing

Transportation and processing expense includes transportation costs incurred to move product from production points to sales points including gathering, compression, pipeline tariffs, trucking and storage costs. Encana also incurs costs related to processing provided by third parties or through ownership interests in processing facilities to bring raw production to sales‑quality product.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018
Canadian Operations	$	211	$	211	$	640	$	608
USA Operations		125		34		340		92
Upstream Transportation and Processing		336		245		980		700
Market Optimization		62		33		168		99
Total	$	398	$	278	$	1,148	$	799
	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018
Canadian Operations	$	9.68	$	10.26	$	10.15	$	10.78
USA Operations	$	3.72	$	2.38	$	3.86	$	2.39
Upstream Transportation and Processing	$	6.05	$	7.05	$	6.46	$	7.39

Three months ended September 30, 2019 versus September 30, 2018

Transportation and processing expense increased $120 million compared to the third quarter of 2018 primarily due to:

• Higher production volumes as a result of the Newfield acquisition and successful drilling in Anadarko ($93 million), and rate escalation in certain transportation contracts relating to previously divested assets and incremental transportation costs associated with third-party purchased volumes ($27 million).

Upstream transportation and processing decreased $1.00 per BOE compared to the third quarter of 2018 primarily due to a higher proportion of total production volumes in the USA Operations resulting from the Newfield acquisition.

Nine months ended September 30, 2019 versus September 30, 2018

Transportation and processing expense increased $349 million compared to the first nine months of 2018 primarily due to:

• Higher production volumes as a result of the Newfield acquisition and successful drilling in Anadarko ($251 million), growth in Montney and Permian ($85 million), rate escalation in certain transportation contracts relating to previously divested assets and incremental transportation costs associated with third-party purchased volumes ($64 million), and higher costs relating to the diversification of the Company’s downstream markets ($8 million);

partially offset by:

• Lower U.S./Canadian dollar exchange rate ($18 million), lower commodity prices ($16 million) and lower activity in Deep Panuke where the Company ceased production in the second quarter of 2018 ($11 million).

Upstream transportation and processing decreased $0.93 per BOE compared to the first nine months of 2018 primarily due to a higher proportion of total production volumes in the USA Operations resulting from the Newfield acquisition.

54

Operating

Operating expense includes costs paid by Encana, net of amounts capitalized, to operate oil and natural gas properties in which the Company has a working interest. These costs primarily include labor, service contract fees, chemicals and fuel.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019			2018
Canadian Operations	$	32	$	34	$	96		$	98
USA Operations		151		80		414			238
China Operations (1)		4		-		16			-
Upstream Operating Expense		187		114		526			336
Market Optimization		6		8		21			25
Corporate & Other		-		2		(2	)		11
Total	$	193	$	124	$	545		$	372
	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019			2018
Canadian Operations	$	1.45	$	1.61	$	1.51		$	1.70
USA Operations	$	4.48	$	5.56	$	4.70		$	6.16
China Operations (1)	$	66.11	$	-	$	27.53		$	-
Upstream Operating Expense (2)	$	3.35	$	3.22	$	3.46		$	3.51

(1) The Company acquired its China Operations as part of the Newfield business combination on February 13, 2019. Subsequently, the Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019. Upstream Operating Expense for China Operations is presented for the period from February 14, 2019 through July 31, 2019.

(2) Upstream Operating Expense per BOE for the third quarter and first nine months of 2019 includes long-term incentive costs of $0.01/BOE and $0.06/BOE, respectively (2018 - $0.15/BOE and $0.16/BOE, respectively).

Three months ended September 30, 2019 versus September 30, 2018

Operating expense increased $69 million compared to the third quarter of 2018 primarily due to:

• The Newfield acquisition and growth in Anadarko, as well as higher activity in Permian ($79 million);

partially offset by:

• Lower long-term incentive costs resulting from a decrease in Encana’s share price in the third quarter of 2019 ($8 million), lower activity in Eagle Ford ($5 million) and the sale of the San Juan assets in the fourth quarter of 2018 ($3 million).

Nine months ended September 30, 2019 versus September 30, 2018

Operating expense increased $173 million compared to the first nine months of 2018 primarily due to:

• The Newfield acquisition and growth in Anadarko, as well as higher activity in Permian ($223 million);

partially offset by:

• Lower long-term incentive costs resulting from a decrease in Encana’s share price in the first nine months of 2019 ($12 million), lower activity in Eagle Ford ($11 million), the sale of the San Juan assets in the fourth quarter of 2018 ($7 million) and lower salaries and benefits in the Canadian Operations ($5 million).

Additional information on Encana’s long-term incentives can be found in Note 19 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

55

Purchased Product

Purchased product expense includes purchases of oil, NGLs and natural gas from third parties that are used to provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification. The Company also purchases and sells third-party volumes under long-term marketing arrangements associated with the Company’s previous divestitures.

	Three months ended September 30,					Nine months ended September 30,
($ millions)		2019		2018		2019		2018
Market Optimization		$	264	$	282	$	784	$	803

Three months ended September 30, 2019 versus September 30, 2018

Purchased product expense decreased $18 million compared to the third quarter of 2018 primarily due to:

• Lower benchmark prices ($70 million) and lower third-party purchased natural gas volumes ($49 million);

partially offset by:

• Higher third-party purchased liquids volumes primarily relating to price optimization activities and additional third-party purchases to meet sales commitments in the USA Operations ($101 million).

Nine months ended September 30, 2019 versus September 30, 2018

Purchased product expense decreased $19 million compared to the first nine months of 2018 primarily due to:

• Lower benchmark prices ($99 million) and lower third-party purchased natural gas volumes ($94 million);

partially offset by:

• Higher third-party purchased liquids volumes ($174 million) due to:

o Changing market conditions resulting in additional third-party purchases to meet sales commitments in the Canadian Operations in the first quarter of 2019; and

o Price optimization activities and additional third-party purchases to meet sales commitments in the USA Operations in the third quarter of 2019.

56

Depreciation, Depletion & Amortization

Proved properties within each country cost centre are depleted using the unit-of-production method based on proved reserves as discussed in Note 1 to the Consolidated Financial Statements included in Item 8 of the 2018 Annual Report on Form 10-K. Depletion rates are impacted by impairments, acquisitions, divestitures and foreign exchange rates, as well as fluctuations in 12-month average trailing prices which affect proved reserves volumes.

Under full cost accounting, the carrying amount of Encana’s oil and natural gas properties within each country cost centre is subject to a ceiling test performed quarterly. Ceiling test impairments are recognized when the capitalized costs exceed the sum of the estimated after-tax future net cash flows from proved reserves as calculated under SEC requirements using the 12‑month average trailing prices and discounted at 10 percent.

In the first nine months of 2019, the 12-month average trailing prices have generally declined. Further declines in the 12‑month average trailing commodity prices could reduce proved reserves values and result in the recognition of future ceiling test impairments. Future ceiling test impairments can also result from changes to reserves estimates, future development costs, capitalized costs and unproved property costs. Proceeds received from oil and natural gas divestitures are generally deducted from the Company’s capitalized costs and can reduce the risk of ceiling test impairments.

Additional information can be found in the Critical Accounting Estimates section of the MD&A included in Item 7 of the 2018 Annual Report on Form 10-K. Corporate assets are carried at cost and depreciated on a straight-line basis over the estimated service lives of the assets.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018
Canadian Operations	$	100	$	95	$	287	$	257
USA Operations		438		241		1,141		628
Upstream DD&A		538		336		1,428		885
Market Optimization		-		-		-		1
Corporate & Other		7		13		26		38
Total	$	545	$	349	$	1,454	$	924
	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018
Canadian Operations	$	4.61	$	4.57	$	4.56	$	4.55
USA Operations	$	12.93	$	17.05	$	12.95	$	16.39
Upstream DD&A	$	9.67	$	9.65	$	9.45	$	9.34

Three months ended September 30, 2019 versus September 30, 2018

DD&A increased $196 million compared to the third quarter of 2018 primarily due to:

• Higher production volumes in the USA Operations ($337 million), partially offset by lower depletion rates in the USA Operations ($141 million).

The depletion rate in the USA Operations decreased $4.12 per BOE compared to the third quarter of 2018 primarily due to higher reserve volumes primarily in Permian, as well as additional reserve volumes acquired with the Newfield acquisition.

Nine months ended September 30, 2019 versus September 30, 2018

DD&A increased $530 million compared to the first nine months of 2018 primarily due to:

• Higher production volumes in the USA and Canadian Operations ($760 million and $32 million, respectively), partially offset by lower depletion rates in the USA Operations ($248 million).

57

The depletion rate in the USA Operations decreased $3.44 per BOE compared to the first nine months of 2018 primarily due to higher reserve volumes primarily in Permian, as well as additional reserve volumes acquired with the Newfield acquisition.

Administrative

Administrative expense represents costs associated with corporate functions provided by Encana staff in Calgary, Denver and The Woodlands offices. Costs primarily include salaries and benefits, general office, information technology, restructuring and long-term incentive costs.

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018
Administrative, excluding Long-Term Incentive and
Restructuring Costs	$	76	$	40	$	237	$	126
Long-term incentive costs		1		17		18		61
Restructuring costs		4		-		134		-
Total Administrative	$	81	$	57	$	389	$	187
	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018
Administrative, excluding Long-Term Incentive and
Restructuring Costs	$	1.38	$	1.17	$	1.57	$	1.34
Long-term incentive costs		0.01		0.47		0.12		0.64
Restructuring costs		0.07		-		0.88		-
Total Administrative	$	1.46	$	1.64	$	2.57	$	1.98

Three months ended September 30, 2019 versus September 30, 2018

Administrative expense in the third quarter of 2019 increased $24 million compared to the third quarter of 2018 primarily due to the impact from adopting ASC Topic 842, “Leases”, as discussed further below ($30 million), costs related to the Newfield acquisition ($8 million), and restructuring costs ($4 million), partially offset by lower long-term incentive costs resulting from a larger change in Encana’s share price in the third quarter of 2019 compared to the change in the share price in the third quarter of 2018 ($16 million).

Nine months ended September 30, 2019 versus September 30, 2018

Administrative expense in the first nine months of 2019 increased $202 million compared to the first nine months of 2018 primarily due to restructuring costs ($134 million), the impact from adopting ASC Topic 842, “Leases”, as discussed further below ($86 million) and administrative costs associated with the Newfield acquisition ($25 million), including non-recurring integration expenses of $8 million, partially offset by lower long-term incentive costs resulting from a larger change in Encana’s share price in the first nine months of 2019 compared to the change in the share price in the first nine months of 2018 ($43 million).

During the first nine months of 2019, Encana completed workforce reductions in conjunction with the Newfield acquisition to better align staffing levels and the organizational structure. Additional information on restructuring charges can be found in Note 18 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

On January 1, 2019, Encana adopted ASC Topic 842 which requires all operating leases to be recognized on the balance sheet. As a result, The Bow office building was determined to be an operating lease with the lease payments recorded in administrative expense starting in 2019. Previously, payments related to The Bow office building were recognized as interest expense and principal repayment. Prior periods have not been restated and are reported in accordance with ASC Topic 840, “Leases”. Additional information on the adoption of ASC Topic 842 can be found in Notes 2 and 11 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

58

Other (Income) Expenses

	Three months ended September 30,						Nine months ended September 30,
($ millions)	2019			2018			2019			2018
Interest	$	99		$	92		$	285		$	265
Foreign exchange (gain) loss, net		30			(23	)		(62	)		93
(Gain) loss on divestitures, net		(5	)		-			(4	)		(4	)
Other (gains) losses, net		(1	)		5			24			2
Total Other (Income) Expenses	$	123		$	74		$	243		$	356

Interest

Interest expense primarily includes interest on Encana’s long-term debt arising from U.S. dollar denominated unsecured notes. Additional information on changes in interest can be found in Note 5 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Interest expense in the third quarter of 2019 increased $7 million compared to the third quarter of 2018 due to higher interest expense on long-term debt primarily relating to Newfield’s outstanding senior notes and issuances under the Company’s U.S. commercial paper (“U.S. CP”) program ($34 million), partially offset by the change in accounting treatment for The Bow office building as a result of the adoption of ASC Topic 842 ($16 million) and lower interest expense resulting from the repayment of the Company’s $500 million senior note in the second quarter of 2019 ($8 million).

Interest expense in the first nine months of 2019 increased $20 million compared to the first nine months of 2018 due to higher interest expense on long-term debt primarily relating to Newfield’s outstanding senior notes and issuances under the Company’s U.S. CP program ($80 million) and an interest recovery due to the resolution of certain tax items relating to prior taxation years in 2018 ($11 million), partially offset by the change in accounting treatment for The Bow office building as a result of the adoption of ASC Topic 842 ($48 million), lower interest expense resulting from the repayment of the Company’s $500 million senior note in the second quarter of 2019 ($12 million) and capitalized interest ($8 million).

Additional information on the adoption of ASC Topic 842 can be found in Notes 2 and 11 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Foreign Exchange (Gain) Loss, Net

Foreign exchange gains and losses primarily result from the impact of fluctuations in the Canadian to U.S. dollar exchange rate. Additional information on changes in foreign exchange gains or losses can be found in Note 6 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Additional information on foreign exchange rates and the effects of foreign exchange rate changes can be found in Item 3 of this Quarterly Report on Form 10‑Q.

Three months ended September 30, 2019 versus September 30, 2018

In the third quarter of 2019, Encana recorded a net foreign exchange loss of $30 million compared to a gain in 2018 of $23 million primarily due to:

• Unrealized foreign exchange losses on the translation of U.S. dollar financing debt issued from Canada compared to gains in 2018 ($142 million);

partially offset by:

• Unrealized foreign exchange gains on the translation of intercompany notes compared to losses in 2018 ($78 million) and realized foreign exchange gains on the settlement of U.S. dollar financing debt issued from Canada in 2019 ($10 million).

59

Nine months ended September 30, 2019 versus September 30, 2018

In the first nine months of 2019, Encana recorded a net foreign exchange gain of $62 million compared to a loss in 2018 of $93 million primarily due to:

• Unrealized foreign exchange gains on the translation of U.S. dollar financing debt issued from Canada compared to losses in 2018 ($255 million), realized foreign exchange gains on the settlement of U.S. dollar financing debt issued from Canada compared to losses in 2018 ($23 million) and unrealized foreign exchange gains on the translation of U.S. dollar risk management contracts issued from Canada compared to losses in 2018 ($20 million);

partially offset by:

• Higher unrealized foreign exchange losses on the translation of intercompany notes compared to 2018 ($108 million) and lower realized foreign exchange gains on the settlement of intercompany notes compared to 2018 ($17 million).

Other (Gains) Losses, Net

Other (gains) losses, net, primarily includes other non-recurring revenues or expenses and may also include items such as interest income, interest received from tax authorities, reclamation charges relating to decommissioned assets and adjustments related to other assets.

Other losses in the first nine months of 2019 primarily includes legal fees and transaction costs related to the Newfield acquisition of $33 million, partially offset by interest income of $11 million.

60

Income Tax

	Three months ended September 30,					Nine months ended September 30,
($ millions)	2019			2018		2019		2018
Current Income Tax Expense (Recovery)	$	(1	)	$	-	$	3	$	(61	)
Deferred Income Tax Expense (Recovery)		44			6		140		6
Income Tax Expense (Recovery)	$	43		$	6	$	143	$	(55	)
Effective Tax Rate	22.4%			13.3%		37.3%		343.8%

Income Tax Expense (Recovery)

Three months ended September 30, 2019 versus September 30, 2018

In the third quarter of 2019, Encana recorded higher income tax expense of $37 million compared to 2018 primarily due to net earnings of $192 million before income tax for the three months ended September 30, 2019, compared to net earnings of $45 million before income tax for the three months ended September 30, 2018.

Nine months ended September 30, 2019 versus September 30, 2018

In the first nine months of 2019, Encana recorded an income tax expense of $143 million compared to an income tax recovery of $55 million in 2018, primarily due to net earnings of $383 million before income tax in the first nine months of 2019, compared to a net loss before income tax of $16 million in 2018, the impact of the Alberta tax rate reduction discussed below and the tax impact resulting from the resolution of certain tax items relating to prior taxation years in 2018.

On June 28, 2019, Alberta Bill 3, the Job Creation Tax Cut (Alberta Corporate Tax Amendment) Act, was signed into law resulting in a reduction of the Alberta corporate tax rate from 12 percent to 11 percent effective July 1, 2019, with further one percent rate reductions to take effect every year on January 1 until the general corporate tax rate is eight percent on January 1, 2022. During the nine months ended September 30, 2019, the deferred tax expense of $140 million includes an adjustment of $55 million resulting from the re-measurement of the Company’s deferred tax position due to the Alberta tax rate reduction.

Effective Tax Rate

Encana’s interim income tax expense is determined using the estimated annual effective income tax rate applied to year‑to‑date net earnings before income tax plus the effect of legislative changes and amounts in respect of prior periods. The estimated annual effective income tax rate is primarily impacted by expected annual earnings, income tax related to foreign operations, the effect of legislative changes, non-taxable capital gains and losses, tax differences on divestitures and transactions, and partnership tax allocations in excess of funding.

The Company’s effective tax rate of 22.4 percent in the third quarter of 2019 is lower than the Canadian statutory tax rate of 26.6 percent primarily resulting from the impact of foreign jurisdictional tax rates relative to the Canadian statutory tax rate applied to jurisdictional earnings and partnership tax allocations in excess of funding. The Company’s effective tax rate of 37.3 percent in the first nine months of 2019 is higher than the Canadian statutory tax rate primarily resulting from the re-measurement of the Company’s deferred tax position due to the Alberta tax rate reduction discussed above, partially offset by the impact of foreign jurisdictional tax rates relative to the Canadian statutory tax rate applied to jurisdictional earnings and partnership tax allocations in excess of funding.

The determination of income and other tax liabilities of the Company and its subsidiaries requires interpretation of complex domestic and foreign tax laws and regulations, that are subject to change. The Company’s interpretation of taxation laws may differ from the interpretation of the tax authorities. As a result, there are tax matters under review for which the timing of resolution is uncertain. The Company believes that the provision for income taxes is adequate.

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Liquidity and Capital Resources

Sources of Liquidity

The Company has the flexibility to access cash equivalents and a range of funding alternatives at competitive rates through committed revolving credit facilities as well as debt and equity capital markets. Encana closely monitors the accessibility of cost-effective credit and ensures that sufficient liquidity is in place to fund capital expenditures and dividend payments. In addition, the Company may use cash and cash equivalents, cash from operating activities, or proceeds from asset divestitures to fund its operations or to manage its capital structure as discussed below. At September 30, 2019, $17 million in cash and cash equivalents was held by U.S. subsidiaries. The cash held by U.S. subsidiaries is accessible and may be subject to additional Canadian income taxes and U.S. withholding taxes if repatriated.

The Company’s capital structure consists of total shareholders’ equity plus long-term debt, including the current portion. The Company’s objectives when managing its capital structure are to maintain financial flexibility to preserve Encana’s access to capital markets and its ability to meet financial obligations and finance internally generated growth, as well as potential acquisitions. Encana has a practice of maintaining capital discipline and strategically managing its capital structure by adjusting capital spending, adjusting dividends paid to shareholders, issuing new shares, purchasing shares for cancellation, issuing new debt or repaying existing debt.

	As at September 30,
($ millions, except as indicated)	2019			2018
Cash and Cash Equivalents	$	138		$	615
Available Credit Facility – Encana (1)		2,500			2,500
Available Credit Facility – U.S. Subsidiary (1)		1,500			1,500
Issuance of U.S. Commercial Paper		(740	)		-
Total Liquidity	$	3,398		$	4,615
Long-Term Debt, including current portion (2)	$	7,024		$	4,198
Total Shareholders’ Equity (3)	$	9,921		$	6,494
Debt to Capitalization (%) (4)		41			39
Debt to Adjusted Capitalization (%) (5)		28			23

(1) Collectively, the “Credit Facilities”.

(2) Long-Term Debt as at September 30, 2019, includes outstanding U.S. CP totaling $740 million and the senior notes acquired in conjunction with the Newfield business combination on February 13, 2019, totaling $2,450 million.

(3) Shareholders’ Equity reflects the common shares issued to Newfield shareholders on February 13, 2019, totaling $3,478 million and the common shares purchased, for cancellation, under Encana’s NCIB program and substantial issuer bid.

(4) Calculated as long-term debt, including the current portion, divided by shareholders’ equity plus long-term debt, including the current portion.

(5) A non-GAAP measure which is defined in the Non-GAAP Measures section of this MD&A.

As at September 30, 2019, the Company had $740 million of commercial paper outstanding under its U.S. CP program to provide for short‑term funding requirements, which is supported by Encana’s $2.5 billion revolving credit facility. Further details on the U.S. CP program can be found in the Sources and Uses of Cash section of this MD&A.

Encana is currently in compliance with, and expects that it will continue to be in compliance with, all financial covenants under the Credit Facilities. Management monitors Debt to Adjusted Capitalization, which is a non-GAAP measure defined in the Non-GAAP Measures section of this MD&A, as a proxy for Encana’s financial covenant under the Credit Facilities, which requires debt to adjusted capitalization to be less than 60 percent. As at September 30, 2019, Debt to Adjusted Capitalization was 28 percent. The definitions used in the covenant under the Credit Facilities adjust capitalization for cumulative historical ceiling test impairments that were recorded as at December 31, 2011 in conjunction with the Company’s January 1, 2012 adoption of U.S. GAAP. Additional information on financial covenants can be found in Note 13 to the Consolidated Financial Statements included in Item 8 of the 2018 Annual Report on Form 10‑K.

The Company’s debt-based metrics have increased over the prior year due to the increase in long-term debt resulting from the Newfield acquisition. Further details on the Company’s debt-based metrics can be found in the Non-GAAP Measures section of this MD&A.

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Sources and Uses of Cash

In the third quarter and first nine months of 2019, Encana primarily generated cash through operating activities. The following table summarizes the sources and uses of the Company’s cash and cash equivalents.

		Three months ended September 30,					Nine months ended September 30,
($ millions)	Activity Type	2019			2018		2019			2018
Sources of Cash, Cash Equivalents and Restricted Cash
Cash from operating activities	Operating	$	756		$	885	$	2,191		$	1,741
Proceeds from divestitures	Investing		171			24		177			89
Corporate acquisition, net of cash and restricted cash acquired	Investing		-			-		94			-
Net issuance of revolving long-term debt	Financing		-			-		740			-
Other	Investing		-			-		-			72
			927			909		3,202			1,902
Uses of Cash and Cash Equivalents
Capital expenditures	Investing		566			523		2,052			1,626
Acquisitions	Investing		25			15		66			17
Net repayment of revolving long-term debt	Financing		21			-		-			-
Repayment of long-term debt	Financing		-			-		500			-
Purchase of common shares	Financing		213			50		1,250			250
Dividends on common shares	Financing		24			14		77			43
Other	Investing/Financing		164			31		181			68
			1,013			633		4,126			2,004
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents     and Restricted Cash Held in Foreign Currency			-			3		4			(2	)
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		$	(86	)	$	279	$	(920	)	$	(104	)

Operating Activities

Cash from operating activities in the third quarter and first nine months of 2019 was $756 million and $2,191 million, respectively, and was primarily a reflection of the impacts from the Newfield acquisition, increases in production volumes, the effects of the commodity price mitigation program and changes in non‑cash working capital, partially offset by lower average realized commodity prices.

Additional detail on changes in non-cash working capital can be found in Note 23 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Encana expects it will continue to meet the payment terms of its suppliers.

Non-GAAP Cash Flow in the third quarter and first nine months of 2019 was $817 million and $2,116 million, respectively, and was primarily impacted by the items affecting cash from operating activities which are discussed below and in the Results of Operations section of this MD&A.

Three months ended September 30, 2019 versus September 30, 2018

Net cash from operating activities decreased $129 million compared to the third quarter of 2018 primarily due to:

• Changes in non-cash working capital ($345 million), lower realized commodity prices ($284 million), higher transportation and processing expense ($120 million), higher operating and administrative expense, excluding non-cash long-term incentive costs ($76 million and $35 million, respectively), higher interest on long-term debt ($34 million) and higher production, mineral and other taxes ($21 million);

partially offset by:

• Higher production volumes ($598 million) and realized gains on risk management in revenues in the third quarter of 2019 compared to realized losses in 2018 ($199 million).

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Nine months ended September 30, 2019 versus September 30, 2018

Net cash from operating activities increased $450 million compared to the first nine months of 2018 primarily due to:

• Higher production volumes ($1,782 million) and realized gains on risk management in revenues in the first nine months of 2019 compared to realized losses in 2018 ($396 million);

partially offset by:

• Lower realized commodity prices ($566 million), higher transportation and processing expense ($349 million), restructuring costs ($134 million), higher operating and administrative expense, excluding non-cash long-term incentive costs ($201 million and $140 million, respectively), higher interest on long-term debt ($86 million), higher production, mineral and other taxes ($78 million), changes in non-cash working capital ($69 million), current tax expense in 2019 compared to a recovery in 2018 ($64 million) and acquisition costs ($33 million).

Investing Activities

Cash used in investing activities in the first nine months of 2019 was $1,965 million primarily due to capital expenditures. Capital expenditures increased $426 million compared to the first nine months of 2018 due to an increase in the Company’s capital program for 2019 relating to the Anadarko asset acquired in the Newfield acquisition ($556 million). Cash from operating activities exceeded capital expenditures by $139 million.

Corporate acquisition in the first nine months of 2019 was $94 million, which reflected the net cash acquired upon the Newfield business combination.

Acquisitions in the first nine months of 2019 were $66 million which included seismic purchases, water rights and purchases with oil and liquids rich potential.

Divestitures in the first nine months of 2019 were $177 million, which primarily included the sale of the Company’s Arkoma Basin natural gas assets in Oklahoma, comprising approximately 140,000 net acres. Proceeds from the sale of the Arkoma Basin natural gas assets were used to reduce the Company’s long-term debt. Divestitures in the first nine months of 2018 were $89 million, which primarily included the sale of certain Pipestone assets in Alberta.

Capital expenditures and acquisition and divestiture activity are summarized in Notes 3, 8 and 9 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Financing Activities

Net cash used in financing activities over the past three years has been impacted by Encana’s strategy to enhance liquidity, strengthen its balance sheet and return value to shareholders through the purchase of common shares. The Company has paid dividends each of the past three years and increased its dividend in the first quarter of 2019.

Net cash used in financing activities in the first nine months of 2019 increased $789 million compared to the first nine months of 2018 primarily due to the purchase of common shares under a NCIB ($787 million) and substantial issuer bid ($213 million) as discussed below, repayment of long‑term debt ($500 million), as well as increased dividends paid ($34 million) in the first nine months of 2019 compared to the first nine months of 2018, partially offset by the net issuance of commercial paper under the Company’s U.S. CP program ($740 million). Further detail on Encana’s U.S. CP program can be found below.

Encana’s long-term debt totaled $7,024 million at September 30, 2019 and $4,198 million at December 31, 2018. On May 15, 2019, the Company repaid the $500 million 6.50 percent senior note using proceeds from the U.S. CP program.

Following the completion of the Newfield acquisition on February 13, 2019, Newfield’s senior notes totaling $2.45 billion remained outstanding as at September 30, 2019. These include a $750 million 5.75 percent senior note due January 30, 2022, a $1.0 billion 5.625 percent senior note due July 1, 2024 and a $700 million 5.375 percent senior note due January 1, 2026. For additional information on long-term debt, refer to Note 12 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. The increase in long‑term debt resulting from the Newfield acquisition increased the Company’s debt-based metrics. Further details on the Company’s debt-based metrics can be found in the Non-GAAP Measures section of this MD&A.

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The Company has access to two credit facilities totaling $4.0 billion, which remain committed through July 2022. The Credit Facilities provide financial flexibility and allow the Company to fund its operations, development activities or capital programs. At September 30, 2019, no amounts were outstanding under the Credit Facilities. During the first nine months of 2019, the Company utilized its U.S. CP program which is supported by Encana’s $2.5 billion revolving credit facility. At September 30, 2019, Encana had $740 million of commercial paper outstanding under its U.S. CP program with an average term of 48 days and a weighted average interest rate of approximately 2.63 percent.

The Credit Facilities, together with cash and cash equivalents less any outstanding commercial paper, provide Encana with total liquidity of $3.4 billion. At September 30, 2019, Encana also had approximately $153 million in undrawn letters of credit issued in the normal course of business primarily as collateral security, to support future abandonment liabilities and for transportation arrangements.

Encana has filed a Canadian shelf prospectus and a U.S. shelf registration statement, under which the Company may issue from time to time, debt securities, common shares, Class A preferred shares, subscription receipts, warrants, units, share purchase contracts and share purchase units in Canada and/or the U.S. At September 30, 2019, $6.0 billion remained accessible under the Canadian shelf prospectus. The ability to issue securities under the Canadian shelf prospectus or U.S. shelf registration statement is dependent upon market conditions and securities law requirements.

Dividends

Encana pays quarterly dividends to shareholders at the discretion of the Board of Directors.

	Three months ended September 30,					Nine months ended September 30,
($ millions, except as indicated)		2019		2018		2019		2018
Dividend Payments (1)		$	24	$	14	$	77	$	43
Dividend Payments ($/share)		$	0.01875	$	0.015	$	0.05625	$	0.045

(1) 2018 includes common shares issued in lieu of cash dividends under Encana’s Dividend Reinvestment Plan (“DRIP”). On February 28, 2019, the Company announced the suspension of its DRIP effective immediately.

As previously announced, the Company increased its dividend by 25 percent in the first quarter of 2019 as part of Encana’s commitment to returning capital to shareholders. Dividends paid in the first nine months of 2019 increased $34 million compared to the first nine months of 2018 due to additional common shares issued as part of the Newfield acquisition, in addition to the 25 percent increase in the dividend per share, partially offset by common shares purchased, for cancellation, pursuant to the Company’s previously announced substantial issuer bid and NCIB.

On October 30, 2019, the Board of Directors declared a dividend of $0.01875 per common share payable on December 31, 2019 to common shareholders of record as of December 13, 2019.

Substantial Issuer Bid

On August 29, 2019, the Company used cash on hand and issued commercial paper to purchase, for cancellation, approximately 47.3 million of its outstanding common shares for total consideration of approximately $213 million under its previously announced substantial issuer bid.

For additional information on the substantial issuer bid, refer to Note 15 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Normal Course Issuer Bid

On February 27, 2019, the Company announced it received approval from the TSX to purchase up to approximately 149.4 million common shares, for cancellation, pursuant to a NCIB over a 12-month period commencing March 4, 2019 and ending March 3, 2020. In first nine months of 2019, the Company used cash on hand to purchase, for cancellation, approximately 149.4 million common shares for total consideration of approximately $1,037 million.

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In the third quarter and first nine months of 2018, the Company used cash on hand to purchase, for cancellation, approximately 3.9 million and 20.7 million common shares, respectively, for total consideration of approximately $50 million and $250 million, respectively, under the previous NCIB which commenced on February 28, 2018 and expired on February 27, 2019.

For additional information on the NCIB, refer to Note 15 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Off-Balance Sheet Arrangements

For information on off-balance sheet arrangements and transactions, refer to the Off-Balance Sheet Arrangements section of the MD&A included in Item 7 of the 2018 Annual Report on Form 10-K.

Commitments and Contingencies

For information on commitments and contingencies, refer to Note 24 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

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Non-GAAP Measures

Certain measures in this document do not have any standardized meaning as prescribed by U.S. GAAP and, therefore, are considered non-GAAP measures. These measures may not be comparable to similar measures presented by other issuers and should not be viewed as a substitute for measures reported under U.S. GAAP. These measures are commonly used in the oil and gas industry and by Encana to provide shareholders and potential investors with additional information regarding the Company’s liquidity and its ability to generate funds to finance its operations. Non-GAAP measures include: Non-GAAP Cash Flow, Non-GAAP Cash Flow Margin, Total Costs, Debt to Adjusted Capitalization and Net Debt to Adjusted EBITDA. Management’s use of these measures is discussed further below.

Non-GAAP Cash Flow and Non-GAAP Cash Flow Margin

Non-GAAP Cash Flow is a non-GAAP measure defined as cash from (used in) operating activities excluding net change in other assets and liabilities, net change in non-cash working capital and current tax on sale of assets.

Non-GAAP Cash Flow Margin is a non-GAAP measure defined as Non-GAAP Cash Flow per BOE of production.

Management believes these measures are useful to the Company and its investors as a measure of operating and financial performance across periods and against other companies in the industry, and are an indication of the Company’s ability to generate cash to finance capital programs, to service debt and to meet other financial obligations. These measures are used, along with other measures, in the calculation of certain performance targets for the Company’s management and employees.

	Three months ended September 30,						Nine months ended September 30,
($ millions, except as indicated)	2019			2018			2019			2018
Cash From (Used in) Operating Activities	$	756		$	885		$	2,191		$	1,741
(Add back) deduct:
Net change in other assets and liabilities		(29	)		(17	)		(55	)		(33	)
Net change in non-cash working capital		(32	)		313			130			199
Current tax on sale of assets		-			-			-			-
Non-GAAP Cash Flow (1)	$	817		$	589		$	2,116		$	1,575
Production Volumes (MMBOE)		55.7			34.8			151.7			94.7
Non-GAAP Cash Flow Margin ($/BOE)	$	14.67		$	16.93		$	13.95		$	16.63

(1) The third quarter and first nine months of 2019 include restructuring costs of $4 million and $134 million, respectively, and acquisition costs of nil and $33 million, respectively.

Total Costs

Total Costs is a non-GAAP measure defined as the summation of production, mineral and other taxes, upstream transportation and processing expense, upstream operating expense and administrative expense, excluding the impact of long-term incentive and restructuring costs. Management believes this measure is useful to the Company and its investors as a measure of operational efficiency across periods.

	Three months ended September 30,				Nine months ended September 30,
($ millions, except as indicated)	2019		2018		2019		2018
Production, Mineral and Other Taxes	$	66	$	45	$	187	$	109
Upstream Transportation and Processing		336		245		980		700
Upstream Operating		187		114		526		336
Administrative		81		57		389		187
Deduct (add back):
Long-term incentive costs		1		22		27		76
Restructuring costs		4		-		134		-
Total Costs	$	665	$	439	$	1,921	$	1,256
Divided by:
Production Volumes (MMBOE)		55.7		34.8		151.7		94.7
Total Costs ($/BOE) (1)	$	11.95	$	12.60	$	12.66	$	13.23

(1) Calculated using whole dollars and volumes.

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Debt to Adjusted Capitalization

Debt to Adjusted Capitalization is a non-GAAP measure which adjusts capitalization for historical ceiling test impairments that were recorded as at December 31, 2011. Management monitors Debt to Adjusted Capitalization as a proxy for Encana’s financial covenant under the Credit Facilities which require debt to adjusted capitalization to be less than 60 percent. Adjusted Capitalization includes debt, total shareholders’ equity and an equity adjustment for cumulative historical ceiling test impairments recorded as at December 31, 2011 in conjunction with the Company’s January 1, 2012 adoption of U.S. GAAP.

($ millions, except as indicated)	September 30, 2019		December 31, 2018
Long-Term Debt, including current portion	$	7,024	$	4,198
Total Shareholders’ Equity		9,921		7,447
Equity Adjustment for Impairments at December 31, 2011		7,746		7,746
Adjusted Capitalization	$	24,691	$	19,391
Debt to Adjusted Capitalization	28%		22%

The increase in Debt to Adjusted Capitalization is primarily due to the increase in long-term debt resulting from the Newfield acquisition.

Net Debt to Adjusted EBITDA

Net Debt to Adjusted EBITDA is a non-GAAP measure whereby Net Debt is defined as long-term debt, including the current portion, less cash and cash equivalents and Adjusted EBITDA is defined as trailing 12-month net earnings (loss) before income taxes, DD&A, impairments, accretion of asset retirement obligation, interest, unrealized gains/losses on risk management, foreign exchange gains/losses, gains/losses on divestitures and other gains/losses.

Management believes this measure is useful to the Company and its investors as a measure of financial leverage and the Company’s ability to service its debt and other financial obligations. This measure is used, along with other measures, in the calculation of certain financial performance targets for the Company’s management and employees.

($ millions, except as indicated)	September 30, 2019			December 31, 2018
Long-Term Debt, including current portion	$	7,024		$	4,198
Less:
Cash and cash equivalents		138			1,058
Net Debt		6,886			3,140
Net Earnings (Loss)		1,270			1,069
Add back (deduct):
Depreciation, depletion and amortization		1,802			1,272
Impairments		-		-
Accretion of asset retirement obligation		36			32
Interest		371			351
Unrealized (gains) losses on risk management		(556	)		(519	)
Foreign exchange (gain) loss, net		13			168
(Gain) loss on divestitures, net		(5	)		(5	)
Other (gains) losses, net		39			17
Income tax expense (recovery)		292			94
Adjusted EBITDA (trailing 12-month)	$	3,262		$	2,479
Net Debt to Adjusted EBITDA (times)		2.1			1.3

The increase in Net Debt is primarily due to the increase in long-term debt resulting from the Newfield acquisition, whereas Adjusted EBITDA only includes Newfield’s results of operations for the post-acquisition period from February 14, 2019 to September 30, 2019. The Company expects Net Debt to Adjusted EBITDA to trend downward through the remainder of 2019.

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about Encana’s potential exposure to market risks. The term “market risk” refers to the Company’s risk of loss arising from adverse changes in oil, NGL and natural gas prices, foreign currency exchange rates and interest rates. The following disclosures are not meant to be precise indicators of expected future losses but rather indicators of reasonably possible losses. The forward-looking information provides indicators of how the Company views and manages ongoing market risk exposures. The Company’s policy is to not use derivative financial instruments for speculative purposes.  

COMMODITY PRICE RISK

Commodity price risk arises from the effect fluctuations in future commodity prices, including oil, NGLs and natural gas, may have on future revenues, expenses and cash flows. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot market prices applicable to the Company’s natural gas production. Pricing for oil and natural gas production has been volatile and unpredictable as discussed in Item 1A. “Risk Factors” of the 2018 Annual Report on Form 10-K. To partially mitigate exposure to commodity price risk, the Company may enter into various derivative financial instruments including futures, forwards, swaps, options and costless collars. The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors and may vary from time to time. Both exchange traded and over-the-counter traded derivative instruments may be subject to margin-deposit requirements, and the Company may be required from time to time to deposit cash or provide letters of credit with exchange brokers or counterparties to satisfy these margin requirements. For additional information relating to the Company’s derivative and financial instruments, see Note 22 under Part I, Item 1 of this Quarterly Report on Form 10-Q.

The table below summarizes the sensitivity of the fair value of the Company’s risk management positions to fluctuations in commodity prices, with all other variables held constant. The Company has used a 10 percent variability to assess the potential impact of commodity price changes. Fluctuations in commodity prices could have resulted in unrealized gains (losses) impacting pre-tax net earnings as follows:

	September 30, 2019
(US$ millions)	10% Price Increase			10% Price Decrease
Crude oil price	$	(198	)	$	194
NGL price		(3	)		3
Natural gas price		(63	)		55

FOREIGN EXCHANGE RISK

Foreign exchange risk arises from changes in foreign exchange rates that may affect the fair value or future cash flows of the Company’s financial assets or liabilities. As Encana operates primarily in Canada and the United States, fluctuations in the exchange rate between the U.S. and Canadian dollars can have a significant effect on the Company’s reported results. Although Encana’s financial results are consolidated in Canadian dollars, the Company reports its results in U.S. dollars as most of its revenues are closely tied to the U.S. dollar and to facilitate a more direct comparison to other North American oil and gas companies.

The table below summarizes selected foreign exchange impacts on Encana’s financial results when compared to the same periods in 2018.

	Three Months Ended September 30,						Nine Months Ended September 30,
	$ millions			$/BOE			$ millions			$/BOE
Increase (Decrease) in:
Capital Investment	$	(2	)				$	(18	)
Transportation and Processing Expense (1)		(2	)	$	(0.04	)		(18	)	$	(0.12	)
Operating Expense (1)		-			-			(3	)		(0.02	)
Administrative Expense		-			-			(4	)		(0.03	)
Depreciation, Depletion and Amortization (1)		(1	)		(0.02	)		(8	)		(0.05	)

(1) Reflects upstream operations.

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Foreign exchange gains and losses also arise when monetary assets and monetary liabilities denominated in foreign currencies are translated and settled, and primarily include:

• U.S. dollar denominated financing debt issued from Canada

• U.S. dollar denominated risk management assets and liabilities held in Canada

• U.S. dollar denominated cash and short-term investments held in Canada

• Foreign denominated intercompany loans

To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts. As at September 30, 2019, Encana has entered into $250 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7516 to C$1, which mature monthly through the remainder of 2019 and $425 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7483 to C$1, which mature monthly throughout 2020.

As at September 30, 2019, Encana had $4.5 billion in U.S. dollar long-term debt and $181 million in U.S. dollar finance lease obligations issued from Canada that were subject to foreign exchange exposure.

The table below summarizes the sensitivity to foreign exchange rate fluctuations, with all other variables held constant. The Company has used a 10 percent variability to assess the potential impact from Canadian to U.S. foreign currency exchange rate changes. Fluctuations in foreign currency exchange rates could have resulted in unrealized gains (losses) impacting pre-tax net earnings as follows:

	September 30, 2019
(US$ millions)	10% Rate Increase			10% Rate Decrease
Foreign currency exchange	$	(214	)	$	261

INTEREST RATE RISK

Interest rate risk arises from changes in market interest rates that may affect the fair value or future cash flows from the Company’s financial assets or liabilities. The Company may partially mitigate its exposure to interest rate changes by holding a mix of both fixed and floating rate debt and may also enter into interest rate derivatives to partially mitigate effects of fluctuations in market interest rates.

As at September 30, 2019, the Company had floating rate debt of $740 million. Accordingly, the sensitivity in net earnings for each one percent change in interest rates on floating rate debt was $5 million (2018 - nil).

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Item 4: Controls and Procedures

DISCLOSURE CONTROLS AND PROCEDURES

Encana’s Chief Executive Officer and Chief Financial Officer performed an evaluation of the Company’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (“Exchange Act”). The Company’s disclosure controls and procedures are designed to ensure that information required to be disclosed by the Company in reports it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the SEC, and to ensure that the information required to be disclosed by the Company in reports that it files or submits under the Exchange Act, is accumulated and communicated to the Company’s management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2019.

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING

For the nine months ended September 30, 2019, management’s assessment of, and conclusion on, the effectiveness of internal control over financial reporting did not include the internal controls of the entities acquired in the Newfield acquisition on February 13, 2019. Newfield’s total assets and total revenues represented approximately 26 percent of the Company’s consolidated total assets at September 30, 2019 and approximately 29 percent and 29 percent of the Company’s consolidated total revenues for the three and nine months ended September 30, 2019, respectively. Under guidelines established by the SEC, companies are permitted to exclude acquisitions from their assessment of internal control over financial reporting for a period of up to one year following an acquisition while integrating the acquired company. The Company is in the process of integrating Newfield’s and the Company’s internal controls over financial reporting. As a result of these integration activities, certain controls will be evaluated and may be changed. Except as noted above, there were no changes in the Company’s internal control over financial reporting that occurred during the third quarter of 2019 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART II

Item 1. Legal Proceedings

Please refer to Item 3 of the 2018 Annual Report on Form 10-K and Note 24 of Encana’s Condensed Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report on Form 10-Q.

Item 1A. Risk Factors

Encana announced on October 31, 2019 its intention to establish corporate domicile in the United States. In connection with the Reorganization, Encana entered into an Arrangement and Reorganization Agreement dated October 31, 2019 (the “Agreement”) with 1847432 Alberta ULC (“184Co”), which is currently a wholly-owned subsidiary of Encana and will be a predecessor of Ovintiv following completion of the Reorganization.  The Reorganization is being implemented in accordance with the terms of and subject to the conditions contained in the Agreement, which sets out the terms of the Reorganization. Capitalized terms used in the following discussion and not otherwise defined in this Quarterly Report on Form 10-Q shall have the meanings given to such terms in the Agreement.

Risks Relating to Ovintiv

The rights of stockholders under Delaware law may differ from the rights of shareholders under Canadian law.

If the Reorganization is completed, Encana shareholders will become stockholders of a Delaware corporation. There are significant differences between the Canada Business Corporations Act (the “CBCA”) and the General Corporation Law of the State of Delaware (the “DGCL”). For example, under the CBCA, many significant corporate actions such as amending a corporation's articles of incorporation or consummating a merger require the approval of at least two-thirds of the votes cast by shareholders, whereas under the DGCL, in most cases, such actions require the approval of a majority of the voting power of outstanding stock entitled to vote on the matter. Furthermore, shareholders under the CBCA are entitled to appraisal rights under a number of extraordinary corporate actions, including an amalgamation with another unrelated corporation, certain amendments to a corporation's articles of incorporation or the sale of all or substantially all of a corporation's assets, whereas under the DGCL, stockholders are only entitled to appraisal rights in connection with certain mergers, consolidations and similar transactions. As shown by the examples above, if the Reorganization is completed, in certain circumstances, holders of shares of common stock of Ovintiv will be afforded different protections under the DGCL than Encana shareholders had under the CBCA.

Provisions in the Ovintiv Certificate of Incorporation and Ovintiv Bylaws could discourage a takeover that Ovintiv stockholders may consider favorable.

In addition to protections afforded under the DGCL, the Ovintiv Certificate of Incorporation and Ovintiv Bylaws will contain provisions that could have the effect of delaying or preventing changes in control or changes in management or the board of directors of Ovintiv (the “Ovintiv Board”). These provisions include:

• no cumulative voting in the election of directors, which limits the ability of minority stockholders to elect director candidates;

• the exclusive right of the Ovintiv Board to establish the size of the Ovintiv Board and to elect a director to fill a vacancy created by the expansion of the Ovintiv Board or the death, resignation, disqualification or removal of a director, which prevents stockholders from being able to fill vacancies on the Ovintiv Board;

• the ability of the Ovintiv Board to issue shares of preferred stock in one or more series and, with respect to each such series, to fix the number of shares constituting such series and the designations, powers, preferences, rights, qualifications, limitations and restrictions in respect of the shares of such series, without stockholder approval, which could be used to significantly dilute the ownership of a hostile acquirer;

• a prohibition on stockholder action by written consent, which forces stockholder action to be taken at an annual or special meeting of stockholders;

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• the requirement that a special meeting of stockholders may be called only by the Ovintiv Board or one or more stockholders of record who hold, in the aggregate, at least 20% of all outstanding shares of common stock of Ovintiv, which may delay the ability of stockholders to force consideration of a proposal or to take action, including the removal of directors; and

• advance notice procedures that stockholders must comply with in order to nominate candidates to the Ovintiv Board, include nominees in the proxy materials of Ovintiv or propose matters to be acted upon at a stockholders' meeting, which may discourage or deter a potential acquirer from conducting a solicitation of proxies to elect the acquirer's own slate of directors or otherwise attempting to obtain control of Ovintiv.

The Ovintiv Certificate of Incorporation will designate the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by stockholders, which could limit stockholders' ability to obtain a favorable judicial forum for disputes with Ovintiv or its directors or officers or other matters pertaining to Ovintiv's internal affairs.

The Ovintiv Certificate of Incorporation will provide that, subject to limited exceptions, the Court of Chancery of the State of Delaware will be the exclusive forum for:

• any derivative action or proceeding brought on behalf of Ovintiv;

• any action asserting a breach of fiduciary duty owed by any current or former director, officer or stockholder of Ovintiv to Ovintiv or Ovintiv's stockholders;

• any action asserting a claim arising pursuant to any provision of the DGCL; or

• any action asserting a claim governed by the internal affairs doctrine.

This choice of forum provision may limit a stockholder's ability to bring a claim in a judicial forum that it finds favorable for disputes with Ovintiv or its directors, officers or other matters pertaining to Ovintiv's internal affairs, and may discourage lawsuits with respect to such claims. Alternatively, if a court were to find these provisions of the Ovintiv Certificate of Incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, Ovintiv may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect its business, financial condition or operating results.

There has been no prior public trading for the shares of common stock of Ovintiv on the NYSE or the TSX and the market price of the shares of common stock of Ovintiv may be subject to volatility.

Although the Encana common shares have historically been listed on the NYSE and the TSX, there has been no public trading market for the shares of common stock of Ovintiv. Following the listing of the shares of common stock of Ovintiv on the NYSE and the TSX, and having regard to the share consolidation being completed pursuant to the Reorganization, there can be no assurance that the trading market for such shares will continue to be as active or liquid as was the trading market for the Encana common shares prior to the Reorganization or that the trading price of the shares of common stock of Ovintiv following the Reorganization may not be effectively lower than the trading price of the Encana common shares (including as a result of the share consolidation pursuant to the Reorganization).  

As is the case with the Encana common shares, the market price of the shares of common stock of Ovintiv may be volatile. The value of an investment in the shares of common stock of Ovintiv may decrease or increase abruptly, and such volatility may bear little or no relation to Encana's performance. The price of the shares of common stock of Ovintiv may fall in response to market appraisal of Encana's strategy or if Encana's results of operations and/or prospects are below the expectations of market analysts or shareholders. In addition, stock markets have, from time to time, experienced significant price and volume fluctuations that have affected the market price of securities, and may, in the future, experience similar fluctuations which may be unrelated to Ovintiv's operating performance and prospects but nevertheless affect the price of the shares of common stock of Ovintiv. This volatility may affect the ability of holders of shares of common stock of Ovintiv to

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sell these at an advantageous price. Broad market fluctuations, as well as economic conditions generally may adversely affect the market price of the shares of common stock of Ovintiv.

Ovintiv will need to enter into certain new arrangements which may not be on terms as favorable as arrangements entered into by Encana.

Concurrently with or immediately following completion of the Reorganization, Ovintiv expects to enter into new arrangements as the ultimate parent company to Encana and its subsidiaries, including entering into guarantees, establishing credit facilities and arranging other sources of financing. While Ovintiv anticipates such terms will be materially consistent with the arrangements currently in place for Encana, there is no assurance that such arrangement will not impose additional operating or financial restrictions on Ovintiv, or that such arrangements will be on commercially reasonable terms or terms that are acceptable to Ovintiv.

Following the Reorganization, a downgrade of Ovintiv's credit ratings could increase its cost of capital and limit its access to capital, suppliers or counterparties.

Following the Reorganization, Ovintiv anticipates its rating of long-term and short-term debt to be consistent with Encana's current ratings as Ovintiv and its subsidiaries will carry on the business currently carried on by Encana and its subsidiaries and there will be no change in the underlying financial condition of the company. The credit ratings are based upon operating performance, liquidity and leverage ratios, overall financial position, and other factors viewed by the credit rating agencies as relevant to both the oil and gas industry and Ovintiv's economic outlook. Because Ovintiv may rely in part on debt financing for ongoing operations, a downgrade in its credit rating may increase the cost of borrowing under Ovintiv's credit facilities, limit access to private and public markets to raise short-term and long-term debt, and negatively impact Ovintiv's cost of capital.

Credit ratings may also be important to suppliers or counterparties when they seek to engage in certain transactions. Downgrades in one or more of Ovintiv's credit ratings may require it to post collateral, letters of credit, cash or other forms of security as financial assurance of its performance under certain contractual arrangements with marketing counterparties, facility construction contracts, and pipeline and midstream service providers. In connection with certain over-the-counter derivatives contracts and other trading agreements, Ovintiv could be required to provide additional collateral or to terminate transactions with certain counterparties based on its credit rating. The occurrence of any of the foregoing could have a material adverse effect on Ovintiv's liquidity and capital position.  

Ovintiv's ability to pay dividends in the future is not guaranteed.

Any future determination to pay dividends will be at the discretion of the Ovintiv Board and will depend upon many factors, including Ovintiv's results of operations, financial position, capital requirements, distributable reserves, credit terms, general economic conditions and other factors as the Ovintiv Board may deem relevant from time to time. Consequently, investors may not receive any return on investment unless they sell their shares of common stock of Ovintiv for a price greater than that which they paid for them.

The issuance of additional shares of common stock of Ovintiv in connection with future acquisitions or growth opportunities, any Ovintiv Incentive Plan or otherwise may dilute all other shareholdings.

Ovintiv may seek to raise financing to fund future growth opportunities. In certain circumstances, Ovintiv may, for these and other purposes, including pursuant to any Ovintiv incentive plan, issue additional equity or convertible equity securities. As a result, existing holders of shares of common stock of Ovintiv may suffer dilution in their percentage ownership or the market price of such shares may be adversely affected.

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Risks Relating to the Reorganization

Encana may fail to realize the perceived benefits of the Reorganization, including as a result of the common stock of Ovintiv not being included in a Canadian or U.S. stock market index; Encana’s business may be subject to disruption due to uncertainty associated with the U.S. domestication.

Encana has pursued the Reorganization because it believes that the U.S. domestication will enhance shareholder value over the long-term by raising the profile and marketability of Encana's capital stock in the United States through, among other things, the ability to attract deeper and growing pools of passive investment capital in the United States, particularly if shares of common stock of Ovintiv are able to be included in certain U.S. stock market indices and other investment vehicles that only include securities of U.S.-domiciled companies.  However, if, following the Reorganization, the shares of common stock of Ovintiv are removed from Canadian stock market indices and not included in such U.S. stock market indices, certain retail and institutional shareholders may be forced to sell their shares of common stock of Ovintiv, which could increase stock price volatility or cause the market price of the shares of common stock of Ovintiv to fall.  Given that inclusion and continued inclusion in a stock market index is subject to numerous factors which can be applied subjectively by the entity managing the index, there can be no assurances that Ovintiv will be not be removed from applicable Canadian stock market indices nor can there be any assurances that Ovintiv will be included in any U.S. stock market indices in a timely manner, or at all.

In addition, while Encana will maintain its existing Canadian presence and Ovintiv and its affiliates will carry on the business currently conducted by Encana and its subsidiaries, certain relationships, including with employees, landowners, suppliers, lenders, partners, governments and other stakeholders, may be subject to disruption due to uncertainty associated with the U.S. domestication. Specifically, certain stakeholders may be reluctant to engage in business with Encana prior to or Ovintiv following completion of the Reorganization, or may impose additional conditions on or apply less favorable terms to transactions involving Encana and/or Ovintiv.

The success of the Reorganization will depend, in part, on the ability of Encana to realize the anticipated benefits associated with the Reorganization and associated reorganization of Encana's corporate structure, and Encana may not be able to realize such benefits on a timely basis or at all.

The Reorganization is conditional, and the conditions may not be satisfied.

Completion of the Reorganization is conditional, among other things, upon the receipt of approvals and the satisfaction of other conditions, including (i) the authorization, upon official notice of issuance, of the listing of the shares of common stock of Ovintiv on the NYSE, (ii) the approval of the listing of the shares of common stock of Ovintiv on the TSX, (iii) court approval in respect of the Arrangement, and (iv) the receipt of the required securityholder approvals. Although Encana is diligently applying its efforts to take, or cause to be taken, all actions to do, or cause to be done, all things necessary, proper or advisable to obtain the requisite approvals, there can be no assurance that these conditions will be fulfilled or that the Reorganization will be completed. Further, even if the required securityholder approvals have been obtained, the Board of Directors may decide to delay or not proceed with the Reorganization if it determines that the Reorganization is no longer advisable.

The Reorganization may result in material Canadian federal income tax (including material Canadian "emigration tax") and/or material U.S. federal income tax for Encana or Ovintiv.

For Canadian federal income tax purposes, based on and subject to current assumptions and current market value, Encana does not expect the Reorganization to give rise to material corporate-level Canadian federal income tax for Encana or Ovintiv. However, in certain circumstances, Ovintiv may become subject to corporate-level Canadian federal income tax. The U.S. domestication, which occurs as part of the Reorganization, will cause Ovintiv to cease to be resident in Canada for the purpose of the Canadian Income Tax Act and as a result Ovintiv will be deemed to have a taxation year end immediately prior to the U.S. domestication. Ovintiv will also be deemed to have disposed of each of its properties immediately before its deemed taxation year end for proceeds of disposition equal to the fair market value of such properties and to have reacquired such properties immediately thereafter at a cost amount equal to fair market value. Ovintiv will be required to include in its taxable income under the Canadian Income Tax Act any income and net taxable capital gains realized as a result of the deemed disposition of its properties. Ovintiv also will be subject to an additional "emigration tax" on the amount by which

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the fair market value, immediately before its deemed taxation year end resulting from the Reorganization, of all of the properties owned by Ovintiv exceeds the total of certain of its liabilities and the paid-up capital of all the issued and outstanding shares of Ovintiv immediately before the deemed taxation year end.

While Encana expects that the deemed disposition of Ovintiv's properties that will occur as part of the Reorganization and the computation relevant for emigration tax will not result in any material Canadian federal income tax (including material "emigration tax") to Encana or Ovintiv at current estimates of fair market value, if a material number of Encana shareholders are eligible to, and do, become electing shareholders by making and filing valid Section 85 elections, the adjusted cost base to Ovintiv of its properties and the aggregate of the paid-up capital of its shares and the relevant liabilities of Ovintiv could be lower than the aggregate fair market value of its properties, which could result in a material tax liability to Ovintiv. Further, there is no certainty that the fair market value of the properties of Ovintiv as currently estimated will not increase or be accepted by Canadian federal tax authorities, which may result in additional taxes payable as a result of the Reorganization. Encana has not applied to the Canadian federal tax authorities for a ruling on this matter and does not intend to do so.

For U.S. federal income tax purposes, based on and subject to current assumptions and current market value, Encana does not expect the Reorganization to give rise to material corporate-level U.S. federal income tax for Encana or Ovintiv. However, in certain circumstances, Encana or Ovintiv may become subject to corporate-level U.S. federal income tax. Ovintiv could be subject to U.S. federal income taxation in connection with the U.S. domestication to the extent, if any, that, at the time of such U.S. domestication (a) the aggregate fair market value of all of the outstanding shares of common stock of Ovintiv exceeds (b) the U.S. tax basis in Ovintiv's assets (computed under U.S. federal income tax principles) less liabilities of Encana assumed by Ovintiv.

There can be no assurance that the fair market value of the shares of common stock of Ovintiv as currently estimated will not increase, that the IRS will accept the determination of Ovintiv's U.S. tax basis in its assets or that the IRS will not otherwise challenge Encana's position that neither Encana nor Ovintiv is subject to U.S. federal income tax in connection with the Reorganization. Encana has not applied to the IRS for a ruling related to the Reorganization and does not intend to do so.

If the IRS does not agree with the calculation of the "all earnings and profits amount" attributable to the Encana common shares, certain U.S. holders of shares of common stock of Ovintiv may owe U.S. federal income taxes (or a higher than anticipated amount of U.S. federal income taxes) as a result of the U.S. domestication.

Certain U.S. holders that, at the time of the U.S. domestication, (i) own shares of common stock of Ovintiv with a fair market value of $50,000 or more (but who are not 10% U.S. holders), and (ii) that would otherwise recognize taxable gain for U.S. federal income tax purposes with respect to their shares of common stock of Ovintiv in connection with the U.S. domestication, may make the "all earnings and profits" election with respect to their Ovintiv stock in lieu of recognizing such taxable gain. A U.S. holder that validly makes the "all earnings and profits" election will be required to include in income, as a deemed dividend, the "all earnings and profits amount" (as defined under applicable Treasury Regulations) that is attributable, under U.S. tax principles, to such U.S. holder's shares of common stock of Ovintiv. A 10% U.S. holder is generally required to include in income, as a deemed dividend, the "all earnings and profits amount" attributable to the shares of common stock of Ovintiv owned by such U.S. holder.

Encana is currently in the process of determining its historical earnings and profits and also expects to determine its earnings and profits for 2019 and for the portion of 2020 ending with the effective date of the Reorganization. Encana will not complete this determination until after completion of the U.S. domestication. Based on information that is currently available, however, Encana anticipates that it may have a significant earnings and profits cumulative balance. In general, the "all earnings and profits amount" attributable to shares of common stock of Ovintiv held by a particular U.S. holder should generally depend on Encana's accumulated earnings and profits from the date that the Encana common shares were acquired by such U.S. holder through the effective date of the Reorganization. The determination of Encana's earnings and profits is a complex determination and may be impacted by numerous factors. Accordingly, there can be no assurance that the IRS will agree with Ovintiv's determination of such earnings and profits. If the IRS does not agree with such earnings and profits calculations, the earnings and profits of Encana may be greater than reported on Ovintiv's website. In such case, a U.S. holder that makes an "all earnings and profits" election or a 10% U.S. holder could have a positive (or a more positive than anticipated) "all earnings and profits amount" in respect of such U.S. holder's shares and thereby recognize greater taxable income.

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U.S. holders are strongly urged to consult their own tax advisors regarding the U.S. federal income tax consequences of the Reorganization to them in their particular circumstances, including whether to make the "all earnings and profits" election where applicable, and the appropriate filing requirements with respect to this election.

Completion of the Reorganization may affect the timing of audit or reassessments by tax authorities.

The determination of income and other tax liabilities of Encana and its subsidiaries requires interpretation of complex domestic and foreign laws and regulations that are subject to change. Encana's interpretation of taxation law may differ from the interpretation of the tax authorities. There are tax matters under review for which the timing of resolution is uncertain. While Encana believes that the provision for income taxes is adequate, completion of the Reorganization may affect the timing of audit and reassessment of taxes by certain tax authorities, which reassessments may be without technical merit and possibly material.

Ovintiv's effective tax rate may change in the future, including as a result of the U.S. domestication.

Following the U.S. domestication, Ovintiv may be subject to current U.S. federal income taxes on the earnings of Ovintiv's non-U.S. subsidiaries in a manner that may adversely impact the company's effective tax rate. In addition, recently enacted U.S. tax reform legislation has significantly changed the U.S. federal income taxation of U.S. corporations, including by reducing the U.S. corporate income tax rate, limiting interest deductions, permitting immediate expensing of certain capital expenditures, requiring current taxation of certain "global intangible low-taxed income" of non-U.S. subsidiaries (regardless of whether any distributions are made by such subsidiaries), adopting elements of a territorial tax system, revising the rules governing net operating losses, and introducing new anti-base erosion provisions. The legislation is unclear in many respects and could be subject to potential amendments and technical corrections, as well as interpretations and implementing regulations by the U.S. Treasury Department and the IRS, any of which could lessen or increase certain adverse impacts of the legislation.

In light of these factors, there can be no assurance that Ovintiv's effective income tax rate will not change in future periods, including as a result of and following the U.S. domestication, which could have a material adverse effect on Ovintiv's income tax position.

Encana will devote significant time and resources to effecting the Reorganization, including incurring non-recurring costs related to the Reorganization.

Encana and its management have devoted and will continue to be required to devote significant time and resources to effecting the completion of the Reorganization and related and incidental activities. There is a risk that the challenges associated with managing these various initiatives will result in business disruptions and that consequently the underlying businesses will not perform in line with expectations. These disruptions could have an adverse effect on the business, financial condition and reputation of Ovintiv.

In addition, Encana expects to incur a number of non-recurring costs associated with the Reorganization, including legal fees, accountants' fees, proxy solicitor fees, filing fees, mailing expenses and financial printing expenses. There can be no assurance that the actual costs will not exceed those estimated and the actual completion of the Reorganization may result in additional and unforeseen expenses. Most of these costs will be payable whether or not the Reorganization is completed. While it is expected that benefits of the Reorganization achieved by Ovintiv will offset these transaction costs over time, this net benefit may not be achieved in the short-term or at all, particularly if the Reorganization is delayed or does not happen at all. These combined factors could adversely affect the business, operating profit and overall financial condition of Ovintiv.

Encana may choose to defer or abandon the Reorganization.

Even if the required securityholder approvals have been obtained and other conditions required to complete the Reorganization have been satisfied, Encana may decide to defer or abandon the Reorganization at any time prior to the effective time of the Reorganization and in such case Encana will have incurred substantial costs and will have devoted significant attention and resources relating to the Reorganization, but will not realize any of the anticipated benefits of the Reorganization.

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Negative publicity resulting from the Reorganization could adversely affect Encana's business and the market price of the Encana common shares and the shares of common stock of Ovintiv.

Domestication transactions that have been undertaken by other companies have in some cases generated significant news coverage, some of which has been negative. Negative publicity generated by the Reorganization could cause certain persons with whom Encana has a business relationship to be more reluctant to do business with Encana prior to the Reorganization, or Ovintiv following the Reorganization. In addition, negative publicity could cause certain of Encana's employees, particularly those in Canada, to perceive uncertainty regarding future opportunities available to them. Either of these events could have a significant adverse impact on Encana's business. Negative publicity could also cause some Encana shareholders to sell Encana common shares or decrease the demand for new investors to purchase such shares, which could have an adverse impact on the price of the Encana common shares and the shares of common stock of Ovintiv.

Completion of the Reorganization may trigger certain provisions in agreements to which Encana is a party.

While the Reorganization will not result in an effective change of control of Encana, the completion of the Reorganization may trigger certain technical change in control, right of first offer, notice, consent, assignment or other provisions in agreements to which Encana or its subsidiaries are a party. If Encana and/or Ovintiv are unable to assert that such provisions should not apply, or is unable to comply with or negotiate waivers of those provisions, the counterparties may exercise their rights and remedies under the agreements, including potentially terminating such agreements or seeking monetary damages or, in certain situations, Ovintiv may be required to make an offer to purchase outstanding debt securities of its subsidiary Newfield. Even if Encana is able to negotiate waivers, the counterparties may require a fee for such waivers or seek to renegotiate the agreements on terms less favorable to Ovintiv.

Payments in connection with the exercise of dissent rights by Encana shareholders may impact Ovintiv's financial resources.

Under the CBCA, Encana shareholders who (i) do not vote in favor of the Reorganization resolution, (ii) deliver to Encana a dissent notice, (iii) continuously hold their Encana common shares through the effective time of the Reorganization, and (iv) otherwise comply with the requirements and procedures of Section 190 of the CBCA (as modified by the Interim Order and Plan of Arrangement), are entitled to receive payment in cash of the "fair value" of their Encana common shares. Should a material number of Encana shareholders exercise dissent rights, a substantial cash payment may be required to be made to such dissenting shareholders that could have an adverse effect on Ovintiv's financial condition and cash resources if the Reorganization is completed. It is a condition precedent to completion of the Reorganization that the time period for the exercise of any dissent rights conferred upon Encana shareholders in respect of the Reorganization shall have expired and Encana shareholders shall not have exercised (or otherwise be deemed to have exercised) dissent rights with respect to that number of Encana common shares that would make it inadvisable to proceed with the implementation of the Reorganization, as determined by Encana in its sole discretion.

Enforcement of rights against Ovintiv in Canada may be limited.

Ovintiv will be located outside of Canada and, following the effective time of the Reorganization, the majority of its directors, officers and experts are likely to reside outside of Canada. Accordingly, it may not be possible for Ovintiv stockholders to effect service of process within Canada upon Ovintiv or the majority of its directors, officers or experts, or to enforce judgments obtained in Canadian courts against Ovintiv or the majority of its directors, officers or experts.

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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchase of Equity Securities

On June 10, 2019, the Company announced its intention to purchase, for cancellation, up to $213 million of its outstanding common shares through a SIB. The SIB subsequently expired on August 28, 2019 and on August 29, 2019, in accordance with the terms and conditions of the SIB, the Company purchased approximately 47.3 million common shares at a price of $4.50 per share for an aggregate purchase price of approximately $213 million.

The following table presents the common shares purchased during the three months ended September 30, 2019.

Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Value of Shares That May Yet be Purchased Under the Plans or Programs
July 1 to July 31, 2019		-	$	-		-		213,000,000
August 1 to August 31, 2019		47,333,333		4.50		47,333,333		-
September 1 to September 30, 2019		-		-		-		-
Total		47,333,333	$	4.50		47,333,333		-

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

Exhibit No	Description
10.1	Change in Control Agreement between Encana Corporation and Brendan McCracken effective September 10, 2019.
10.2	Change in Control Agreement between Encana Corporation and Gregory D. Givens effective September 10, 2019.
10.3	Fifth Amendment to the Encana (USA) Retirement Plan amended and restated effective March 14, 2014.
10.4	Sixth Amendment to the Encana (USA) Retirement Plan amended and restated effective March 14, 2014.
10.5	Amendment No. 4 to the Encana Corporation Canadian Pension Plan amended and restated as of January 1, 2011.
31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934.
31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934.
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350.
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350.
101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	Inline XBRL Taxonomy Schema Document.
101.CAL	Inline XBRL Calculation Linkbase Document.
101.DEF	Inline XBRL Definition Linkbase Document.
101.LAB	Inline XBRL Label Linkbase Document.
101.PRE	Inline XBRL Presentation Linkbase Document.
104	The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2019, has been formatted in Inline XBRL.

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SIGNATURES

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

ENCANA CORPORATION
By:	/s/ Corey D. Code
	Name:	Corey D. Code
	Title:	Executive Vice-President & Chief Financial Officer

Dated: November 4, 2019

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EX-10.1

Exhibit 10.1

CHANGE IN CONTROL AGREEMENT

This Change in Control Agreement (this “Agreement”) is made effective as of September 10, 2019 between Encana Corporation, a corporation amalgamated under the laws of Canada (the “Corporation”), and Brendan McCracken of the City of Calgary in the Province of Alberta (the “Executive”).

WHEREAS the Board of Directors of the Corporation (the “Board”) has determined that it is in the best interests of the Corporation and its shareholders to assure that the Corporation will have the continued dedication of the Executive, notwithstanding the possibility or threat of a Change in Control (as defined herein);

AND WHEREAS the Board believes it is imperative to diminish the inevitable distraction of the Executive by virtue of the personal uncertainties and risks created by a pending or threatened Change in Control and to encourage the Executive’s full attention and dedication to the Corporation in the event of any threatened or pending Change in Control, and to provide the Executive with compensation and benefits arrangements upon a Change in Control that ensure that the compensation and benefits expectations of the Executive will be satisfied and that provide the Executive with compensation and benefits arrangements that are competitive with those of other companies;

AND WHEREAS to accomplish these objectives, the Board has caused the Corporation to enter into this Agreement;

NOW THEREFORE, in consideration of the covenants and agreements hereinafter set forth and for other good and valuable consideration (the receipt and sufficiency whereof are hereby acknowledged by each of the Executive and the Corporation (each, a “Party” and collectively, the “Parties”), the Parties hereby mutually covenant and agree as follows:

1.0 Term of Agreement

1.1 Term. This Agreement shall commence on the date hereof and shall continue in effect during the Executive’s employment with the Corporation as an executive officer until such time as there shall occur a Change in Control of the Corporation and for a period of two years following the Effective Date (as defined below) of such Change in Control (the “Term”); provided, however, that the payment of compensation and benefits to the Executive under this Agreement may continue beyond the end of the Term in accordance with the applicable provisions of this Agreement.

2.0 Definitions

For purposes of this Agreement, the following definitions shall apply:

2.1 “Affiliate”: the term “Affiliate” shall be interpreted in accordance with the definition of such term as contained in Section 2 of the Canada Business Corporations Act (Canada).

2.2 “Cause” means:

(a) the willful and continued failure by the Executive to substantially perform his or her duties with the Corporation or an Affiliate after a written demand for substantial performance is delivered to the Executive by the Board, which demand specifically identifies the manner in

which the Board believes the Executive has not substantially performed his or her duties, and the Executive fails to correct such failure to perform his or her duties within thirty (30) days after such written demand is delivered to the Executive; provided, however, that if such failure occurs after the occurrence of an event or circumstance which would entitle the Executive to resign for Good Reason, such alleged failure shall not constitute the basis for “Cause”; or

(b) the willful engaging by the Executive in conduct which is demonstrably and materially injurious to the Corporation or an Affiliate, monetarily or otherwise.

For purposes of this Section 2.2, (i) any action by the Executive or any failure on the Executive’s part to act, shall be deemed “willful” only when done (or omitted to be done) by the Executive not in good faith and only if, when done (or omitted to be done), the Executive had or ought to have had the reasonable belief that the Executive’s action or omission would not be in the best interests of the Corporation or an Affiliate, and (ii) if the Corporation is not the ultimate parent corporation of the group that includes the Corporation and all of its Affiliates after a Change in Control, references to the “Board” shall mean the board of directors (or equivalent governing body) of the ultimate parent entity of such group.

Notwithstanding the foregoing, the Executive shall not be deemed to have been terminated for Cause unless and until (A) the Executive has been provided with the opportunity, after reasonable advance notice, to appear before the Board, together with the Executive’s legal counsel, prior to a determination by the Board regarding the existence of “Cause”, and (B) there shall have been delivered to the Executive a copy of a resolution duly adopted by a vote of at least two-thirds (2/3) of the members of the Board, finding that in the good faith opinion of the Board, the Executive was guilty of conduct set forth in clause (a) or (b) of this Section 2.2 and specifying the particulars thereof. A determination of “Cause” made by the Board that is challenged by the Executive in a court of competent jurisdiction shall be subject to “de novo” standard of review by such court.

2.3 “Change in Control” means:

(a) any individual, partnership, firm, corporation, association, trust, unincorporated organization or other entity, or any persons acting jointly or in concert with the foregoing (each, a “Person”), is or becomes the beneficial owner directly or indirectly of 30% or more of either (A) the then-outstanding shares of common stock of the Corporation (the “Outstanding Corporation Common Stock”) or (B) the combined voting power of the then-outstanding voting securities of the Corporation entitled to vote generally in the election of directors (the “Outstanding Corporation Voting Securities”); provided, however, that, for purposes of this Section 2.3(a), the following acquisitions of shares or other voting securities of the Corporation shall not constitute a Change in Control: (i) any acquisition directly from the Corporation, (ii) any acquisition made by the Corporation, (iii) any acquisition by any employee plan (or related trust) sponsored or maintained by the Corporation or any of its subsidiaries, or (iv) any acquisition pursuant to a transaction that complies with Sections 2.3(b)(1), 2.3(b)(2) and 2.3(b)(3);

(b) consummation of a reorganization, merger, statutory share exchange or consolidation or similar transaction involving the Corporation or any of its subsidiaries, a sale or other disposition of all or substantially all of the assets of the Corporation, or the acquisition of

assets or securities of another entity by the Corporation or any of its subsidiaries (each, a “Business Combination”), in each case unless, following such Business Combination, (1) all or substantially all of the individuals and entities that were the beneficial owners of the Outstanding Corporation Common Stock and the Outstanding Corporation Voting Securities immediately prior to such Business Combination beneficially own, directly or indirectly, more than 50% of the then-outstanding shares of common stock (or, for a non-corporate entity, equivalent securities) and the combined voting power of the then-outstanding voting securities entitled to vote generally in the election of directors (or, for a non-corporate entity, equivalent governing body), as the case may be, of the entity resulting from such Business Combination (including, without limitation, an entity that, as a result of such transaction, owns the Corporation or all or substantially all of the Corporation’s assets either directly or through one or more subsidiaries) in substantially the same proportions as their ownership immediately prior to such Business Combination of the Outstanding Corporation Common Stock and the Outstanding Corporation Voting Securities, as the case may be, (2) no Person (excluding any entity resulting from such Business Combination or any employee plan (or related trust) of the Corporation or of such entity resulting from such Business Combination) beneficially owns, directly or indirectly, 30% or more of, respectively, the then-outstanding shares of common stock (or, for a non-corporate entity, equivalent securities) of the entity resulting from such Business Combination or the combined voting power of the then-outstanding voting securities of such entity, except to the extent that such ownership existed prior to the Business Combination, and (3) at least a majority of the members of the board of directors (or, for a non-corporate entity, equivalent governing body) of the entity resulting from such Business Combination were members of the Incumbent Board (as defined below) at the time of the execution of the initial agreement or of the action of the Board providing for such Business Combination;

(c) individuals who, as of the date hereof, constitute the Board (the "Incumbent Board") cease for any reason to constitute at least a majority of the Board; provided, however, that any individual becoming a director subsequent to the date hereof whose election, or nomination for election by the Corporation's shareholders, was approved by a vote of at least a majority of the directors then comprising the Incumbent Board shall be considered as though such individual was a member of the Incumbent Board, but excluding, for this purpose, any such individual whose initial assumption of office occurs as a result of an actual or threatened election contest with respect to the election or removal of directors or other actual or threatened solicitation of proxies or consents by or on behalf of a person or entity other than the Board; or

(d) approval by the shareholders of the Corporation of a complete liquidation or dissolution of the Corporation.

For purposes of this Section 2.3:

(i) the term “acting jointly or in concert” shall be interpreted in accordance with Section 159 of the Securities Act (Alberta), as amended; and

(ii) the term “beneficial ownership” shall be interpreted in accordance with Sections 5 and 6 of the Securities Act (Alberta) and “beneficial owner” shall have a

corresponding meaning, except that for purposes of this Agreement, options and convertible securities granted by the Corporation to employees, officers or directors shall not be included in determining the percentage of beneficial ownership of any Person.

2.4 “Effective Date” means the date of the occurrence of a Change in Control.

2.5 “Good Reason” means the occurrence of any of the following on or after a Change in Control, unless the Executive shall have given express written consent thereto:

(a) Changed Status, Position, Authorities, Duties or Responsibilities. The occurrence of any of the following:

(i) any adverse change to the Executive’s status or position as in effect immediately prior to the Change in Control, including, without limitation, the Executive ceasing to serve as an executive officer of a publicly traded company and the sole executive performing the Executive's role as of immediately prior to the Change in Control (or its equivalent), reporting directly and exclusively to the chief executive officer of a publicly traded company; and

(ii) assignment to the Executive of any authorities, duties or responsibilities materially inconsistent with the Executive’s position and status as of immediately prior to the Change in Control; and

(iii) any diminution in the Executive’s authorities, duties or responsibilities from those in effect immediately prior to the Change in Control; or

(b) Reduced Salary. A reduction by the Corporation in the Executive’s annual base salary as in effect immediately prior to the Change in Control; or

(c) Relocation. The Corporation requiring the Executive to be based more than 50 miles from where the Executive is based immediately prior to the Change in Control, except for: (i) required travel on the Corporation’s business to an extent substantially consistent with the Executive’s business travel obligations in the ordinary course of business immediately prior to the Change in Control; or (ii) if the Executive has been relocated or repatriated by the Corporation prior to the Change in Control, such relocation as may be required by applicable law or performed in accordance with an agreement (whether written or unwritten) entered into between the Corporation (or an Affiliate) and the Executive prior to the Change in Control; or

(d) Incentive Compensation Plans. The occurrence of any of the following: (i) a material reduction by the Corporation in the Executive’s (A) annual incentive compensation target or maximum opportunity, or (B) long-term incentive compensation target or maximum opportunity (measured based on grant date fair value of any equity-based awards), in each case, as in effect immediately prior to the Change in Control, or (ii) a change in the performance conditions, vesting, or other material terms and conditions applicable to annual and/or long-term incentive compensation awards granted to Executive after the Change in Control which would have the effect of materially reducing the Executive’s aggregate

potential incentive compensation from the level in effect immediately prior to the Change in Control; or

(e) Pension Plan, Benefit Plans and Perquisites. The failure by the Corporation to continue to provide the Executive:

(i) with pension and other retirement benefits substantially similar to those provided to the Executive under the applicable pension and retirement plans and arrangements of the Corporation as of immediately prior to the Change in Control; or

(ii) with benefits substantially similar to the benefits provided to the Executive as of immediately prior to the Change in Control under the Corporation’s life insurance, medical, health and accident, disability or investment plans; or

(iii) with executive perquisites substantially similar to the material perquisites provided to the Executive by the Corporation as of immediately prior to the Change in Control; or

(iv) with the number of paid vacation days to which the Executive is entitled in accordance with the normal vacation policy of the Corporation in effect in respect of the Executive as of immediately prior to the Change in Control; or

(f) Deferred Compensation. The failure by the Corporation to pay the Executive (i) any portion of the Executive’s then current compensation, except pursuant to an across-the-board compensation deferral similarly affecting all senior executives of the Corporation and required by applicable law or (ii) any installment of deferred compensation at the time such installment is due under any deferred compensation program of the Corporation; or

(g) No Assumption by Successor. The failure of the Corporation to obtain a satisfactory agreement from a successor to assume and agree to perform this Agreement as contemplated by Section 7.1 hereof.

3.0 Notice of Termination; Date of Termination

3.1 Notice of Termination. Any termination of the Executive’s employment either by the Executive for Good Reason or by the Corporation for Cause or without Cause, as applicable, shall be communicated by written Notice of Termination to the Executive or to the Corporation, as the case may be, in accordance with Section 8.0 hereof.

3.2 Content of Notice of Termination. The “Notice of Termination” shall mean a notice which shall indicate the specific termination provision in this Agreement relied upon by the Executive or the Corporation, as the case may be, and shall set forth in reasonable detail the facts and circumstances claimed as the basis for the Executive terminating the Executive’s employment or the Corporation terminating the Executive’s employment, as the case may be. The Executive’s failure to set forth in the Notice of Termination any fact or circumstance which contributes to a showing of “Good Reason” shall not result in a waiver of the Executive’s rights hereunder or preclude the Executive from subsequently asserting such fact or circumstance in enforcing the Executive’s rights hereunder.

3.3 Date of Termination.The “Date of Termination” shall mean (a) if the Executive’s employment is terminated by the Corporation without Cause or by the Executive for Good Reason, the date specified in the Notice of Termination (which, in the case of termination by the Executive for Good Reason, shall be not more than sixty (60) days following the date such Notice of Termination is given), or (b) if the Executive’s employment is terminated by the Corporation for Cause, the date on which the Board resolution referenced in Section 2.2 is delivered to the Executive.

3.4 Notice Required. For the purposes of this Agreement, any purported termination of the Executive’s employment which is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3.2 hereof shall not be effective.

4.0 Compensation and Benefits following Change in Control

Upon the termination of the Executive’s employment by the Corporation without Cause or by the Executive for Good Reason, in accordance with the terms of this Agreement, in each case, on or after the Effective Date and prior to the end of the Term, the Corporation shall cause to be provided to the Executive, the following payments and benefits:

(a) Accrued Obligations. The Corporation shall pay the Executive, in cash, in a lump sum, on the thirtieth (30^th) day following the Date of Termination (the “Payment Date”), the sum of (i) the Executive’s full base salary through the Date of Termination at the rate in effect at the time the Notice of Termination is given (disregarding any reduction thereto that constitutes Good Reason), (ii) all accrued but unused vacation determined as of the Date of Termination, determined based upon the Executive’s Severance Salary Rate (as defined below) and the Corporation’s vacation policy in effect on the Date of Termination (or, if more favorable to the Executive, the vacation policy in effect as of immediately prior to the Effective Date), (iii) the Executive’s annual bonus for the fiscal year immediately preceding the fiscal year in which the Date of Termination occurs, if such bonus has been determined but not paid as of the Date of Termination, and (iv) the Executive’s business expenses that are reimbursable pursuant to the applicable policy of the Corporation as in effect on the Date of Termination but have not been reimbursed by the Corporation as of the Date of Termination.

(b) Severance Payment, Severance Period and Severance Salary Rate. The Corporation shall pay to the Executive, on account of both compensation in lieu of notice and loss of office, on the Payment Date, in cash, in a lump sum, on the Payment Date, a severance payment (the “Severance Payment”) equal to the amount of base salary the Executive would have earned had he continued to be employed until the end of the twenty-fourth (24^th) full calendar month following the Date of Termination (the “Severance Period”) assuming that the Executive’s rate of monthly base salary during the Severance Period would be equal to the highest monthly rate of base salary which was payable to the Executive by the Corporation or an Affiliate during the twenty-four (24)-month period immediately preceding the Date of Termination (disregarding any reduction thereto that constitutes Good Reason) (the “Severance Salary Rate”).

(c) Annual Incentive Plans. The Corporation shall pay to the Executive, in cash, in a lump sum, on the Payment Date, a payment equal to: (i) two times the average of the annual bonuses

paid to the Executive by the Corporation in respect of the three complete fiscal years of the Corporation immediately preceding the Effective Date (or, for any such complete fiscal year for which the Executive was not paid an annual bonus, the Executive’s target bonus as in effect immediately prior to the Effective Date) (the “Average Bonus”), plus (ii) if the Date of Termination is not the last day of a fiscal year, a prorated bonus payment equal to the Average Bonus multiplied by a fraction, the numerator of which is the number of days which have elapsed in the fiscal year in which the Date of Termination occurs and the denominator of which is the total number of days in such fiscal year.

(d) Retirement and Investment Plans. The Corporation shall pay the Executive, in cash, in a lump sum, on the Payment Date, a payment equal to the maximum contribution that the Corporation or a subsidiary thereof would have been required to make on behalf of the Executive to the Corporation’s retirement or investment plans in which the Executive participates as of immediately prior to the Effective Date (other than any amount covered by Section 4.0(e)) if the Executive had remained fully employed during the Severance Period and elected to have the Corporation or a subsidiary thereof match the Executive’s contributions to such plans, determined as if the Executive continued to make contributions to such plans at a rate equal to the contributions actually made by the Executive under such plans in the last complete calendar year immediately preceding the Date of Termination.

(e) Pension Benefits. In addition to the benefits to which the Executive is entitled under any pension or retirement plan or arrangement established by the Corporation:

(i) The Executive will be credited with pensionable contributions in the Encana Corporation Canadian Defined Contribution Savings Plan (the “Supplemental Pension Plan”), as may be amended from time to time or any successor plan thereto, for each of the 24 months included in the Severance Period;

(ii) For purposes of Section 4.0(e)(i), the Executive’s pensionable earnings shall be calculated based on the lesser of: (i) 40% of the Executive’s Severance Salary Rate; and (ii) the Average Bonus; and

(iii) On or prior to the 15th business day following the Date of Termination, the Executive will receive a lump sum cash payment of her accrued entitlements under the Supplemental Pension Plan, payable on the Payment Date, such amount to be determined: (A) without any gross up or other adjustment for income tax and not taking in to account the non-registered status of the Supplemental Pension Plan, and (B) assuming the Executive’s accrued entitlement under the Supplemental Pension Plan is fully vested.

(f) Equity Awards. Each outstanding equity and equity-based compensation award granted by the Corporation to the Executive shall be treated in accordance with the terms of the plan and award agreement under which it was originally granted.

(g) Insurance Benefits. The Corporation shall continue to provide the Executive with the same level of life, disability, accident, dental and health insurance benefits the Executive was receiving or entitled to receive from the Corporation immediately prior to the Date of

Termination until the end of the Severance Period.The contributions or premiums required to be paid by the Executive under such programs shall be payable by the Executive to the Corporation or to the insurer, as applicable, on the same basis as if the Executive continued to be employed during the Severance Period.

(h) Career Counselling. At the Executive’s request, the Corporation shall provide the Executive with career counselling services, at a maximum cost to the Corporation of $15,000 per annum, until the Executive obtains subsequent employment or establishes the Executive’s own business activity or the end of the Severance Period, whichever is earliest. The Executive shall be entitled to obtain such services from the recognized professional career counselling firm of the Executive’s choice in the major metropolitan area in or nearest to where the Executive resides at the time the Executive begins to use such services.

(i) Annual Allowance. The Corporation shall pay to the Executive, in cash, in a lump sum, on the Payment Date an amount equal to two times the annual allowance to which the Executive is entitled as of the date of the Date of Termination (or, if higher, as of immediately prior to the Effective Date).

(j) Financial Counselling. The Corporation shall, during the Severance Period, continue to provide the Executive with the same financial counselling benefits as those to which the Executive was entitled as of immediately prior to the Date of Termination (or, if more favorable to the Executive, as of immediately prior to the Effective Date). Such services shall be provided throughout the Severance Period, including the preparation of the Executive’s tax return(s) for the tax year during which the Severance Period ends.

(k) Executive Medical. The Corporation shall continue to provide the Executive with the same executive physical examination benefits as those to which the Executive was entitled as of immediately prior to the Date of Termination (or, if more favorable to the Executive, as of immediately prior to the Effective Date). Such benefits shall be provided for the duration of the Severance Period.

(l) Professional Membership Fees. The Corporation shall pay the Executive, in cash, in a lump sum, on the Payment Date, an after-tax amount equal to two times the amount reimbursed or paid by the Corporation (separate from the annual allowance) in respect of membership fees for membership in professional organizations related to the Executive’s position and duties with the Corporation for the year preceding the year in which the Date of Termination occurs (or, if greater, preceding the year in which the Effective Date occurs).

5.0 Legal Fees and Expenses

The Corporation shall pay the Executive's actual legal or professional fees and expenses incurred by the Executive in seeking to obtain or enforce any right or benefit provided by this Agreement up to US$100,000 (and, if a court or other tribunal finds in favor of the Executive, any such fees or expenses that are in excess of US$100,000). Such fees or expenses shall be reimbursed by the Corporation reasonably promptly following receipt of a copy of any invoice from the Executive evidencing the payment by the Executive of such fees or expenses. If such fees or expenses are paid in Canadian dollars, the application of the US$100,000 cap under this Section 5.0 shall be

applied by converting the reimbursed amounts to U.S. dollars based on the spot exchange rate at the time of the reimbursement.

6.0 Entire Agreement

6.1 This Agreement constitutes the entire agreement between the Parties hereto concerning change in control benefits and obligations and supersedes all prior agreements or understandings, including the Prior Agreement, except that each outstanding equity and equity-based compensation award granted by the Corporation to the Executive shall be treated in accordance with the terms of the plan and award agreement under which it was granted, including any such terms that relate to change in control benefits.

7.0 Successors; Binding Agreement

7.1 Assumption by Successors. The Corporation will require any successor (whether direct or indirect, and whether by purchase, merger, consolidation or otherwise) to (a) all or substantially all of the business and/or assets of the Corporation in a transaction that constitutes a Change in Control, or (b) on or after the Effective Date and prior to the end of the Term, to the business in connection with which the Executive’s services are principally performed after a Change in Control in circumstances where the Executive’s employment is transferred to such successor, to expressly assume and to agree to perform this Agreement in the same manner and to the same extent as the Corporation, as if no such succession had taken place. Failure of the Corporation to obtain such assumption and agreement prior to the effectiveness of any such succession shall constitute Good Reason for purposes of this Agreement. As used in this Agreement, “Corporation” shall mean the Corporation as defined herein and any successor to its business and/or assets as aforesaid which assumes and agrees to perform this Agreement by operation of law, or otherwise.

7.2 Assignment; Binding Agreement.

(a) This Agreement is personal to the Executive, and, without the prior written consent of the Corporation, shall not be assignable by the Executive. This Agreement shall inure to the benefit of and be enforceable by the Executive and the Executive’s legal representatives and, and if the Executive should die while any amount remains due to the Executive under this Agreement, such amount shall be paid in accordance with the terms of this Agreement to the Executive’s legatee, if there is no such legatee, to the Executive’s estate.

(b) Except as provided in Section 7.1, without the prior written consent of the Executive, this Agreement shall not be assignable by the Corporation. This Agreement shall inure to the benefit of and be binding upon the Corporation and its successors and permitted assigns.

8.0 Notices

8.1 Notices. For purposes of this Agreement, notices and all other communications provided for in this Agreement shall be in writing and shall be deemed to have been duly given (a) when hand delivered, (b) upon confirmation of receipt when sent by facsimile or email, or (c) on the third business day after having been sent by registered mail, postage prepaid, as follows:

If to the Corporation:

Encana Corporation
500 Centre Street S.E.
Calgary, Alberta
T2P 2S5
Attention: Executive Vice-President, Corporate Services
Facsimile: (403) 645-4617

If to the Executive:

At the Executive’s most recent address, facsimile number, or email address, as applicable, on file with the Corporation.

Each of the Corporation and the Executive may from time to time change its contact information for notice by notice to the other Party given in the manner aforesaid.

9.0 Section 409A Compliance

9.1 To the extent that Section 409A of the U.S. Internal Revenue Code of 1986, as amended (the “Code”) (together with any related regulations or other guidance promulgated by the U.S. Department of the Treasury or the Internal Revenue Service, “Section 409A”) is applicable to the Executive, this Agreement and any payment, distribution or other benefit hereunder is intended to comply with the requirements of Section 409A or an applicable exemption or exclusion therefrom, and shall be interpreted and administered in accordance with such intent in all respects; provided, that for the avoidance of doubt, this provision shall not be construed to require a gross-up payment in respect of any taxes, interest or penalties imposed on Executive as a result of Section 409A.

9.2 To the extent Section 409A is applicable to the Executive:

(a) The Executive shall not be deemed to have terminated employment for purposes of any payment or benefit under this Agreement that constitutes non-qualified deferred compensation unless and until a separation from service (within the meaning of Treasury Regulation Section 1.409A-1(h)) has occurred. If the Executive is a “specified employee” under Section 409A, no payment, distribution or other benefit provided pursuant to this Agreement constituting non-qualified deferred compensation (within the meaning of Treasury Regulation Section 1.409A-1(b)) that is required to be delayed to comply with Section 409A(a)(2)(B)(i) shall be provided before the date that is six months after the date of the Executive’s separation from service (or, if earlier than the end of such six-month period, the date of death of the specified employee). Any payment, distribution or other benefit that is delayed pursuant to the prior sentence shall be paid on the first business day following the six-month anniversary of the separation from service.

(b) In no event may the Executive, directly or indirectly, designate the calendar year of any payment to be made under this Agreement.

(c) Each payment under this Agreement shall be treated as a separate payment for purposes of Section 409A.

(d) All reimbursements and in-kind benefits provided under this Agreement shall be made or provided in accordance with the requirements of Section 409A, including, where applicable, the requirement that (i) any reimbursement shall be for expenses incurred during the time period specified in this Agreement, (ii) the amount of expenses eligible for reimbursement, or in-kind benefits provided, during a calendar year may not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other calendar year, (iii) the reimbursement of an eligible expense will be made not later than the last day of the Executive’s taxable year following the taxable year in which such expense was incurred, and (iv) the right to reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit.Notwithstanding anything in this Agreement to the contrary, with respect to payment of legal fees and expenses pursuant to Section 5.0 hereof, if the court or other tribunal has not yet found in favor or against the Executive prior to the last day of the Executive’s taxable year following the taxable year in which such fees and expenses were incurred, such fees and expenses will be paid on the last day of such taxable year following the taxable year in which such fees and expenses were incurred.If such court or other tribunal does not ultimately find in favor of the Executive, the Executive will repay to the Corporation as soon as practicable, but in no event more than ninety (90) days after the court or other tribunal renders its ruling, any amounts paid or reimbursed pursuant to the prior sentence that would not have been paid or reimbursed pursuant to Section 5.0 but for the prior sentence.

10.0 Reduction of Certain Payments. This Section 10.0 shall apply to the Executive only if and to the extent that Section 4999 of the Code is applicable to the Executive.

10.1 Anything in this Agreement to the contrary notwithstanding, if the Accounting Firm (as defined below) shall determine that receipt of all Payments (as defined below) of the Executive would subject the Executive to the Excise Tax (as defined below), the Accounting Firm shall determine whether to reduce any of the Payments paid or payable pursuant to this Agreement (the “Agreement Payments”) so that the Parachute Value (as defined below) of all Payments, in the aggregate, equals the Safe Harbor Amount (as defined below). The Agreement Payments shall be so reduced only if the Accounting Firm determines that the Executive would have a greater Net After-Tax Receipt (as defined below) of aggregate Payments if the Agreement Payments were so reduced. If the Accounting Firm determines that the Executive would not have a greater Net After-Tax Receipt of aggregate Payments if the Agreement Payments were so reduced, the Executive shall receive all Agreement Payments to which the Executive is entitled hereunder.

10.2 If the Accounting Firm determines that aggregate Agreement Payments should be reduced so that the Parachute Value of all Payments, in the aggregate, equals the Safe Harbor Amount, the Corporation shall promptly give the Executive notice to that effect and a copy of the detailed calculation thereof.All determinations made by the Accounting Firm under this Section 10.0 shall be binding upon the Corporation, its Affiliates and the Executive.All reasonable fees and expenses of the Accounting Firm shall be borne solely by the Corporation.For purposes of reducing the Agreement Payments so that the Parachute Value of all Payments, in the aggregate, equals the Safe Harbor Amount, only amounts payable under the Agreement (and no other Payments) shall be reduced.The reduction of the amounts payable hereunder, if applicable, shall be made by reducing the Agreement Payments that have a Parachute Value in the following order:first, non-cash benefits that do not constitute non-qualified deferred compensation, second, cash benefits that constitute non-qualified deferred compensation, third, non-cash benefits that constitute non-qualified deferred compensation, and fourth, cash benefits that constitute non-qualified deferred compensation, with benefits within each category reduced in reverse chronological order beginning with those that are to be paid or provided the farthest in time from the Date of Termination, based on the Accounting Firm’s determination.

10.3 To the extent requested by the Executive, the Corporation and its Affiliates shall cooperate with the Executive in good faith in valuing, and the Accounting Firm shall take into account the value of, services provided or to be provided by the Executive (including, without limitation, the Executive’s agreeing to refrain from performing services pursuant to a covenant not to compete or similar covenant, before, on or after the date of a change in ownership or control of the Corporation (within the meaning of Q&A-2(b) of the final regulations under Section 280G of the Code)), such that payments in respect of such services may be considered reasonable compensation within the meaning of Q&A-9 and Q&A-40 to Q&A-44 of the Treasury Regulations under Section 280G of the Code and/or exempt from the definition of the term “parachute payment” within the meaning of Q&A-2(a) of the Treasury Regulations under Section 280G of the Code in accordance with Q&A-5(a) of the Treasury Regulations under Section 280G of the Code.

10.4 The following terms shall have the following meanings for purposes of this Section 9.0:

(a) “Accounting Firm” shall mean a nationally recognized certified public accounting firm or other professional organization that is a certified public accounting firm recognized as an expert in determinations and calculations for purposes of Section 280G of the Code that is selected by the Corporation prior to a Change in Control for purposes of making the applicable determinations hereunder.

(b) “Excise Tax” means any excise tax imposed under Section 4999 of the Code.

(c) “Net After-Tax Receipt” shall mean the present value (as determined in accordance with Sections 280G(b)(2)(A)(ii) and 280G(d)(4) of the Code) of a Payment net of all taxes imposed on the Executive with respect thereto under Sections 1 and 4999 of the Code and under applicable state and local laws, determined by applying the highest marginal rate under Section 1 of the Code and under state and local laws which applied to the Executive’s taxable income for the immediately preceding taxable year, or such other rate(s) as the Accounting Firm determines to be likely to apply to the Executive in the relevant tax year(s).

(d) “Parachute Value” of a Payment shall mean the present value as of the date of the change in control for purposes of Section 280G of the Code of the portion of such Payment that constitutes a “parachute payment” under Section 280G(b)(2) of the Code, as determined by the Accounting Firm for purposes of determining whether and to what extent the Excise Tax will apply to such Payment.

(e) “Payment” shall mean any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the Executive, whether paid or payable pursuant to this Agreement or otherwise.

(f) “Safe Harbor Amount” shall mean the maximum Parachute Value of all Payments that the Executive can receive without any Payments being subject to the Excise Tax.

11.0 Miscellaneous

11.1 Amendment and Waiver. No provision of this Agreement may be modified, waived or discharged unless such waiver, modification or discharge is agreed to in a writing signed by the Parties hereto. No waiver by either Party of, or in compliance with, any condition or provision of this Agreement to be performed by the other Party shall be deemed a waiver of similar or dissimilar provisions or conditions at the same or at any prior or subsequent time.

11.2 Deductions. The Executive agrees that benefits and payments to which the Executive is entitled pursuant to this Agreement are subject to deductions or other source withholdings as may be required by law.

11.3 No Mitigation. The Executive shall not be required to mitigate the amount of any payment provided for in this Agreement by seeking other employment or otherwise, nor shall the amount of any payment or benefit provided to the Executive by the Corporation referred to in this Agreement be reduced by any compensation earned by, or benefits paid to, the Executive as the result of employment, whether by another employer or self-employment, or by pension benefits after the Date of Termination, or otherwise, except as specifically provided in this Agreement.

11.4 Governing Law. This Agreement shall be construed and enforced in accordance with, and the rights of the Parties shall be governed by, the laws of the Province of Alberta.

11.5 Currency. All amounts due under this Agreement shall be paid calculated and paid in the currency in which the Executive’s base salary is paid as of immediately prior to the Date of Termination.

11.6 Validity. The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which shall remain in full force and effect.

11.7 Counterparts. This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original and all of which together shall constitute one and the same Agreement.

11.8 Headings. The division of this Agreement into sections, subsections and clauses, or other portions hereof and the insertion of headings or subheadings, are for convenience of reference only and shall not affect the construction or interpretation of this Agreement.

12.0 Survivorship

Upon the expiration or other termination of this Agreement or the Executive’s employment, the respective rights and obligations of the Parties shall survive to the extent necessary to carry out the intentions of the Parties under this Agreement.

IN WITNESS WHEREOF, the Executive and the Corporation have caused this Agreement to be duly executed effective as of the date first above written.

ENCANA CORPORATION

Per: /s/ Douglas J. Suttles

Name: Douglas J. Suttles
Title: Chief Executive Officer

Per: /s/ Mike Williams

Name: Mike Williams
Title: Executive Vice-President, Corporate Services

/s/ Brendan McCracken

BRENDAN MCCRACKEN

EX-10.2

Exhibit 10.2

CHANGE IN CONTROL AGREEMENT

This Change in Control Agreement (this “Agreement”) is made effective as of September 10, 2019 between Encana Corporation, a corporation amalgamated under the laws of Canada (the “Corporation”), and Gregory D. Givens of the City of Houston in the State of Texas (the “Executive”).

WHEREAS the Board of Directors of the Corporation (the “Board”) has determined that it is in the best interests of the Corporation and its shareholders to assure that the Corporation will have the continued dedication of the Executive, notwithstanding the possibility or threat of a Change in Control (as defined herein);

AND WHEREAS the Board believes it is imperative to diminish the inevitable distraction of the Executive by virtue of the personal uncertainties and risks created by a pending or threatened Change in Control and to encourage the Executive’s full attention and dedication to the Corporation in the event of any threatened or pending Change in Control, and to provide the Executive with compensation and benefits arrangements upon a Change in Control that ensure that the compensation and benefits expectations of the Executive will be satisfied and that provide the Executive with compensation and benefits arrangements that are competitive with those of other companies;

AND WHEREAS to accomplish these objectives, the Board has caused the Corporation to enter into this Agreement;

NOW THEREFORE, in consideration of the covenants and agreements hereinafter set forth and for other good and valuable consideration (the receipt and sufficiency whereof are hereby acknowledged by each of the Executive and the Corporation (each, a “Party” and collectively, the “Parties”), the Parties hereby mutually covenant and agree as follows:

1.0 Term of Agreement

1.1 Term. This Agreement shall commence on the date hereof and shall continue in effect during the Executive’s employment with the Corporation as an executive officer until such time as there shall occur a Change in Control of the Corporation and for a period of two years following the Effective Date (as defined below) of such Change in Control (the “Term”); provided, however, that the payment of compensation and benefits to the Executive under this Agreement may continue beyond the end of the Term in accordance with the applicable provisions of this Agreement.

2.0 Definitions

For purposes of this Agreement, the following definitions shall apply:

2.1 “Affiliate”: the term “Affiliate” shall be interpreted in accordance with the definition of such term as contained in Section 2 of the Canada Business Corporations Act (Canada).

2.2 “Cause” means:

(a) the willful and continued failure by the Executive to substantially perform his or her duties with the Corporation or an Affiliate after a written demand for substantial performance is delivered to the Executive by the Board, which demand specifically identifies the manner in

which the Board believes the Executive has not substantially performed his or her duties, and the Executive fails to correct such failure to perform his or her duties within thirty (30) days after such written demand is delivered to the Executive; provided, however, that if such failure occurs after the occurrence of an event or circumstance which would entitle the Executive to resign for Good Reason, such alleged failure shall not constitute the basis for “Cause”; or

(b) the willful engaging by the Executive in conduct which is demonstrably and materially injurious to the Corporation or an Affiliate, monetarily or otherwise.

For purposes of this Section 2.2, (i) any action by the Executive or any failure on the Executive’s part to act, shall be deemed “willful” only when done (or omitted to be done) by the Executive not in good faith and only if, when done (or omitted to be done), the Executive had or ought to have had the reasonable belief that the Executive’s action or omission would not be in the best interests of the Corporation or an Affiliate, and (ii) if the Corporation is not the ultimate parent corporation of the group that includes the Corporation and all of its Affiliates after a Change in Control, references to the “Board” shall mean the board of directors (or equivalent governing body) of the ultimate parent entity of such group.

Notwithstanding the foregoing, the Executive shall not be deemed to have been terminated for Cause unless and until (A) the Executive has been provided with the opportunity, after reasonable advance notice, to appear before the Board, together with the Executive’s legal counsel, prior to a determination by the Board regarding the existence of “Cause”, and (B) there shall have been delivered to the Executive a copy of a resolution duly adopted by a vote of at least two-thirds (2/3) of the members of the Board, finding that in the good faith opinion of the Board, the Executive was guilty of conduct set forth in clause (a) or (b) of this Section 2.2 and specifying the particulars thereof. A determination of “Cause” made by the Board that is challenged by the Executive in a court of competent jurisdiction shall be subject to “de novo” standard of review by such court.

2.3 “Change in Control” means:

(a) any individual, partnership, firm, corporation, association, trust, unincorporated organization or other entity, or any persons acting jointly or in concert with the foregoing (each, a “Person”), is or becomes the beneficial owner directly or indirectly of 30% or more of either (A) the then-outstanding shares of common stock of the Corporation (the “Outstanding Corporation Common Stock”) or (B) the combined voting power of the then-outstanding voting securities of the Corporation entitled to vote generally in the election of directors (the “Outstanding Corporation Voting Securities”); provided, however, that, for purposes of this Section 2.3(a), the following acquisitions of shares or other voting securities of the Corporation shall not constitute a Change in Control: (i) any acquisition directly from the Corporation, (ii) any acquisition made by the Corporation, (iii) any acquisition by any employee plan (or related trust) sponsored or maintained by the Corporation or any of its subsidiaries, or (iv) any acquisition pursuant to a transaction that complies with Sections 2.3(b)(1), 2.3(b)(2) and 2.3(b)(3);

(b) consummation of a reorganization, merger, statutory share exchange or consolidation or similar transaction involving the Corporation or any of its subsidiaries, a sale or other disposition of all or substantially all of the assets of the Corporation, or the acquisition of

assets or securities of another entity by the Corporation or any of its subsidiaries (each, a “Business Combination”), in each case unless, following such Business Combination, (1) all or substantially all of the individuals and entities that were the beneficial owners of the Outstanding Corporation Common Stock and the Outstanding Corporation Voting Securities immediately prior to such Business Combination beneficially own, directly or indirectly, more than 50% of the then-outstanding shares of common stock (or, for a non-corporate entity, equivalent securities) and the combined voting power of the then-outstanding voting securities entitled to vote generally in the election of directors (or, for a non-corporate entity, equivalent governing body), as the case may be, of the entity resulting from such Business Combination (including, without limitation, an entity that, as a result of such transaction, owns the Corporation or all or substantially all of the Corporation’s assets either directly or through one or more subsidiaries) in substantially the same proportions as their ownership immediately prior to such Business Combination of the Outstanding Corporation Common Stock and the Outstanding Corporation Voting Securities, as the case may be, (2) no Person (excluding any entity resulting from such Business Combination or any employee plan (or related trust) of the Corporation or of such entity resulting from such Business Combination) beneficially owns, directly or indirectly, 30% or more of, respectively, the then-outstanding shares of common stock (or, for a non-corporate entity, equivalent securities) of the entity resulting from such Business Combination or the combined voting power of the then-outstanding voting securities of such entity, except to the extent that such ownership existed prior to the Business Combination, and (3) at least a majority of the members of the board of directors (or, for a non-corporate entity, equivalent governing body) of the entity resulting from such Business Combination were members of the Incumbent Board (as defined below) at the time of the execution of the initial agreement or of the action of the Board providing for such Business Combination;

(c) individuals who, as of the date hereof, constitute the Board (the "Incumbent Board") cease for any reason to constitute at least a majority of the Board; provided, however, that any individual becoming a director subsequent to the date hereof whose election, or nomination for election by the Corporation's shareholders, was approved by a vote of at least a majority of the directors then comprising the Incumbent Board shall be considered as though such individual was a member of the Incumbent Board, but excluding, for this purpose, any such individual whose initial assumption of office occurs as a result of an actual or threatened election contest with respect to the election or removal of directors or other actual or threatened solicitation of proxies or consents by or on behalf of a person or entity other than the Board; or

(d) approval by the shareholders of the Corporation of a complete liquidation or dissolution of the Corporation.

For purposes of this Section 2.3:

(i) the term “acting jointly or in concert” shall be interpreted in accordance with Section 159 of the Securities Act (Alberta), as amended; and

(ii) the term “beneficial ownership” shall be interpreted in accordance with Sections 5 and 6 of the Securities Act (Alberta) and “beneficial owner” shall have a

corresponding meaning, except that for purposes of this Agreement, options and convertible securities granted by the Corporation to employees, officers or directors shall not be included in determining the percentage of beneficial ownership of any Person.

2.4 “Effective Date” means the date of the occurrence of a Change in Control.

2.5 “Good Reason” means the occurrence of any of the following on or after a Change in Control, unless the Executive shall have given express written consent thereto:

(a) Changed Status, Position, Authorities, Duties or Responsibilities. The occurrence of any of the following:

(i) any adverse change to the Executive’s status or position as in effect immediately prior to the Change in Control, including, without limitation, the Executive ceasing to serve as an executive officer of a publicly traded company and the sole executive performing the Executive's role as of immediately prior to the Change in Control (or its equivalent); and

(ii) assignment to the Executive of any authorities, duties or responsibilities materially inconsistent with the Executive’s position and status as of immediately prior to the Change in Control; and

(iii) any diminution in the Executive’s authorities, duties or responsibilities from those in effect immediately prior to the Change in Control; or

(b) Reduced Salary. A reduction by the Corporation in the Executive’s annual base salary as in effect immediately prior to the Change in Control; or

(c) Relocation. The Corporation requiring the Executive to be based more than 50 miles from where the Executive is based immediately prior to the Change in Control, except for: (i) required travel on the Corporation’s business to an extent substantially consistent with the Executive’s business travel obligations in the ordinary course of business immediately prior to the Change in Control; or (ii) if the Executive has been relocated or repatriated by the Corporation prior to the Change in Control, such relocation as may be required by applicable law or performed in accordance with an agreement (whether written or unwritten) entered into between the Corporation (or an Affiliate) and the Executive prior to the Change in Control; or

(d) Incentive Compensation Plans. The occurrence of any of the following: (i) a material reduction by the Corporation in the Executive’s (A) annual incentive compensation target or maximum opportunity, or (B) long-term incentive compensation target or maximum opportunity (measured based on grant date fair value of any equity-based awards), in each case, as in effect immediately prior to the Change in Control, or (ii) a change in the performance conditions, vesting, or other material terms and conditions applicable to annual and/or long-term incentive compensation awards granted to Executive after the Change in Control which would have the effect of materially reducing the Executive’s aggregate

potential incentive compensation from the level in effect immediately prior to the Change in Control; or

(e) Pension Plan, Benefit Plans and Perquisites. The failure by the Corporation to continue to provide the Executive:

(i) with pension and other retirement benefits substantially similar to those provided to the Executive under the applicable pension and retirement plans and arrangements of the Corporation as of immediately prior to the Change in Control; or

(ii) with benefits substantially similar to the benefits provided to the Executive as of immediately prior to the Change in Control under the Corporation’s life insurance, medical, health and accident, disability or investment plans; or

(iii) with executive perquisites substantially similar to the material perquisites provided to the Executive by the Corporation as of immediately prior to the Change in Control; or

(iv) with the number of paid vacation days to which the Executive is entitled in accordance with the normal vacation policy of the Corporation in effect in respect of the Executive as of immediately prior to the Change in Control; or

(f) Deferred Compensation. The failure by the Corporation to pay the Executive (i) any portion of the Executive’s then current compensation, except pursuant to an across-the-board compensation deferral similarly affecting all senior executives of the Corporation and required by applicable law or (ii) any installment of deferred compensation at the time such installment is due under any deferred compensation program of the Corporation; or

(g) No Assumption by Successor. The failure of the Corporation to obtain a satisfactory agreement from a successor to assume and agree to perform this Agreement as contemplated by Section 7.1 hereof.

3.0 Notice of Termination; Date of Termination

3.1 Notice of Termination. Any termination of the Executive’s employment either by the Executive for Good Reason or by the Corporation for Cause or without Cause, as applicable, shall be communicated by written Notice of Termination to the Executive or to the Corporation, as the case may be, in accordance with Section 8.0 hereof.

3.2 Content of Notice of Termination. The “Notice of Termination” shall mean a notice which shall indicate the specific termination provision in this Agreement relied upon by the Executive or the Corporation, as the case may be, and shall set forth in reasonable detail the facts and circumstances claimed as the basis for the Executive terminating the Executive’s employment or the Corporation terminating the Executive’s employment, as the case may be. The Executive’s failure to set forth in the Notice of Termination any fact or circumstance which contributes to a showing of “Good Reason” shall not result in a waiver of the Executive’s rights hereunder or preclude the Executive from subsequently asserting such fact or circumstance in enforcing the Executive’s rights hereunder.

3.3 Date of Termination.The “Date of Termination” shall mean (a) if the Executive’s employment is terminated by the Corporation without Cause or by the Executive for Good Reason, the date specified in the Notice of Termination (which, in the case of termination by the Executive for Good Reason, shall be not more than sixty (60) days following the date such Notice of Termination is given), or (b) if the Executive’s employment is terminated by the Corporation for Cause, the date on which the Board resolution referenced in Section 2.2 is delivered to the Executive.

3.4 Notice Required. For the purposes of this Agreement, any purported termination of the Executive’s employment which is not effected pursuant to a Notice of Termination satisfying the requirements of Section 3.2 hereof shall not be effective.

4.0 Compensation and Benefits following Change in Control

Upon the termination of the Executive’s employment by the Corporation without Cause or by the Executive for Good Reason, in accordance with the terms of this Agreement, in each case, on or after the Effective Date and prior to the end of the Term, the Corporation shall cause to be provided to the Executive, the following payments and benefits:

(a) Accrued Obligations. The Corporation shall pay the Executive, in cash, in a lump sum, on the thirtieth (30^th) day following the Date of Termination (the “Payment Date”), the sum of (i) the Executive’s full base salary through the Date of Termination at the rate in effect at the time the Notice of Termination is given (disregarding any reduction thereto that constitutes Good Reason), (ii) all accrued but unused vacation determined as of the Date of Termination, determined based upon the Executive’s Severance Salary Rate (as defined below) and the Corporation’s vacation policy in effect on the Date of Termination (or, if more favorable to the Executive, the vacation policy in effect as of immediately prior to the Effective Date), (iii) the Executive’s annual bonus for the fiscal year immediately preceding the fiscal year in which the Date of Termination occurs, if such bonus has been determined but not paid as of the Date of Termination, and (iv) the Executive’s business expenses that are reimbursable pursuant to the applicable policy of the Corporation as in effect on the Date of Termination but have not been reimbursed by the Corporation as of the Date of Termination.

(b) Severance Payment, Severance Period and Severance Salary Rate. The Corporation shall pay to the Executive, on account of both compensation in lieu of notice and loss of office, on the Payment Date, in cash, in a lump sum, on the Payment Date, a severance payment (the “Severance Payment”) equal to the amount of base salary the Executive would have earned had he continued to be employed until the end of the twenty-fourth (24^th) full calendar month following the Date of Termination (the “Severance Period”) assuming that the Executive’s rate of monthly base salary during the Severance Period would be equal to the highest monthly rate of base salary which was payable to the Executive by the Corporation or an Affiliate during the twenty-four (24)-month period immediately preceding the Date of Termination (disregarding any reduction thereto that constitutes Good Reason) (the “Severance Salary Rate”).

(c) Annual Incentive Plans. The Corporation shall pay to the Executive, in cash, in a lump sum, on the Payment Date, a payment equal to: (i) two times the average of the annual bonuses

paid to the Executive by the Corporation in respect of the three complete fiscal years of the Corporation immediately preceding the Effective Date (or, for any such complete fiscal year for which the Executive was not paid an annual bonus, the Executive’s target bonus as in effect immediately prior to the Effective Date) (the “Average Bonus”), plus (ii) if the Date of Termination is not the last day of a fiscal year, a prorated bonus payment equal to the Average Bonus multiplied by a fraction, the numerator of which is the number of days which have elapsed in the fiscal year in which the Date of Termination occurs and the denominator of which is the total number of days in such fiscal year.

(d) Retirement and Investment Plans. The Corporation shall pay the Executive, in cash, in a lump sum, on the Payment Date, a payment equal to the maximum contribution that the Corporation or a subsidiary thereof would have been required to make on behalf of the Executive to the Corporation’s retirement or investment plans in which the Executive participates as of immediately prior to the Effective Date (other than any amount covered by Section 4.0(e)) if the Executive had remained fully employed during the Severance Period and elected to have the Corporation or a subsidiary thereof match the Executive’s contributions to such plans, determined as if the Executive continued to make contributions to such plans at a rate equal to the contributions actually made by the Executive under such plans in the last complete calendar year immediately preceding the Date of Termination.

(e) PensionBenefits.TheCorporationshallpaytotheExecutivethemaximumcontributionthat the Corporation or a subsidiary thereof would have been required to make on behalf of the Executive under the Encana (USA) Retirement Plan at the percentage of salary specified therein in respect to the Severance Period basedon:

(i) The Executive’s annual base salary (using the Severance Salary Rate) if he were fully employed until the end of the 24th calendar month following the Date of Termination; and

(ii) ThelesseroftheAverageBonusand40%oftheamountoftheannualbasesalary (using the Severance Salary Rate) the Executive would have earned had he continuedtobeemployeduntiltheendofthe24thcalendarmonthfollowingtheDate of Termination.

This payment will be made to the Executive in a lump sum on the Payment Date.

(f) Equity Awards. Each outstanding equity and equity-based compensation award granted by the Corporation to the Executive shall be treated in accordance with the terms of the plan and award agreement under which it was originally granted.

(g) Insurance Benefits. The Corporation shall continue to provide the Executive with the same level of life, disability, accident, dental and health insurance benefits the Executive was receiving or entitled to receive from the Corporation immediately prior to the Date of Termination until the end of the Severance Period. The contributions or premiums required to be paid by the Executive under such programs shall be payable by the Executive to the Corporation or to the insurer, as applicable, on the same basis as if the Executive continued to be employed during the Severance Period.

(h) Career Counselling.At the Executive’s request, the Corporation shall provide the Executive with career counselling services, at a maximum cost to the Corporation of $15,000 per annum, until the Executive obtains subsequent employment or establishes the Executive’s own business activity or the end of the Severance Period, whichever is earliest.The Executive shall be entitled to obtain such services from the recognized professional career counselling firm of the Executive’s choice in the major metropolitan area in or nearest to where the Executive resides at the time the Executive begins to use such services.

(i) Annual Allowance. The Corporation shall pay to the Executive, in cash, in a lump sum, on the Payment Date an amount equal to two times the annual allowance to which the Executive is entitled as of the date of the Date of Termination (or, if higher, as of immediately prior to the Effective Date).

(j) Financial Counselling. The Corporation shall, during the Severance Period, continue to provide the Executive with the same financial counselling benefits as those to which the Executive was entitled as of immediately prior to the Date of Termination (or, if more favorable to the Executive, as of immediately prior to the Effective Date). Such services shall be provided throughout the Severance Period, including the preparation of the Executive’s tax return(s) for the tax year during which the Severance Period ends.

(k) Executive Medical. The Corporation shall continue to provide the Executive with the same executive physical examination benefits as those to which the Executive was entitled as of immediately prior to the Date of Termination (or, if more favorable to the Executive, as of immediately prior to the Effective Date). Such benefits shall be provided for the duration of the Severance Period.

(l) Professional Membership Fees. The Corporation shall pay the Executive, in cash, in a lump sum, on the Payment Date, an after-tax amount equal to two times the amount reimbursed or paid by the Corporation (separate from the annual allowance) in respect of membership fees for membership in professional organizations related to the Executive’s position and duties with the Corporation for the year preceding the year in which the Date of Termination occurs (or, if greater, preceding the year in which the Effective Date occurs).

5.0 Legal Fees and Expenses

The Corporation shall pay the Executive's actual legal or professional fees and expenses incurred by the Executive in seeking to obtain or enforce any right or benefit provided by this Agreement up to US$100,000 (and, if a court or other tribunal finds in favor of the Executive, any such fees or expenses that are in excess of US$100,000). Such fees or expenses shall be reimbursed by the Corporation reasonably promptly following receipt of a copy of any invoice from the Executive evidencing the payment by the Executive of such fees or expenses. If such fees or expenses are paid in Canadian dollars, the application of the US$100,000 cap under this Section 5.0 shall be

applied by converting the reimbursed amounts to U.S. dollars based on the spot exchange rate at the time of the reimbursement.

6.0 Entire Agreement

6.1 This Agreement constitutes the entire agreement between the Parties hereto concerning change in control benefits and obligations and supersedes all prior agreements or understandings, including the Prior Agreement, except that each outstanding equity and equity-based compensation award granted by the Corporation to the Executive shall be treated in accordance with the terms of the plan and award agreement under which it was granted, including any such terms that relate to change in control benefits.

7.0 Successors; Binding Agreement

7.1 Assumption by Successors. The Corporation will require any successor (whether direct or indirect, and whether by purchase, merger, consolidation or otherwise) to (a) all or substantially all of the business and/or assets of the Corporation in a transaction that constitutes a Change in Control, or (b) on or after the Effective Date and prior to the end of the Term, to the business in connection with which the Executive’s services are principally performed after a Change in Control in circumstances where the Executive’s employment is transferred to such successor, to expressly assume and to agree to perform this Agreement in the same manner and to the same extent as the Corporation, as if no such succession had taken place. Failure of the Corporation to obtain such assumption and agreement prior to the effectiveness of any such succession shall constitute Good Reason for purposes of this Agreement. As used in this Agreement, “Corporation” shall mean the Corporation as defined herein and any successor to its business and/or assets as aforesaid which assumes and agrees to perform this Agreement by operation of law, or otherwise.

7.2 Assignment; Binding Agreement.

(a) This Agreement is personal to the Executive, and, without the prior written consent of the Corporation, shall not be assignable by the Executive. This Agreement shall inure to the benefit of and be enforceable by the Executive and the Executive’s legal representatives and, and if the Executive should die while any amount remains due to the Executive under this Agreement, such amount shall be paid in accordance with the terms of this Agreement to the Executive’s legatee, if there is no such legatee, to the Executive’s estate.

(b) Except as provided in Section 7.1, without the prior written consent of the Executive, this Agreement shall not be assignable by the Corporation. This Agreement shall inure to the benefit of and be binding upon the Corporation and its successors and permitted assigns.

8.0 Notices

8.1 Notices. For purposes of this Agreement, notices and all other communications provided for in this Agreement shall be in writing and shall be deemed to have been duly given (a) when hand delivered, (b) upon confirmation of receipt when sent by facsimile or email, or (c) on the third business day after having been sent by registered mail, postage prepaid, as follows:

If to the Corporation:

Encana Corporation
500 Centre Street S.E.
Calgary, Alberta
T2P 2S5
Attention: Executive Vice-President, Corporate Services
Facsimile: (403) 645-4617

If to the Executive:

At the Executive’s most recent address, facsimile number, or email address, as applicable, on file with the Corporation.

Each of the Corporation and the Executive may from time to time change its contact information for notice by notice to the other Party given in the manner aforesaid.

9.0 Section 409A Compliance

9.1 To the extent that Section 409A of the U.S. Internal Revenue Code of 1986, as amended (the “Code”) (together with any related regulations or other guidance promulgated by the U.S. Department of the Treasury or the Internal Revenue Service, “Section 409A”) is applicable to the Executive, this Agreement and any payment, distribution or other benefit hereunder is intended to comply with the requirements of Section 409A or an applicable exemption or exclusion therefrom, and shall be interpreted and administered in accordance with such intent in all respects; provided, that for the avoidance of doubt, this provision shall not be construed to require a gross-up payment in respect of any taxes, interest or penalties imposed on Executive as a result of Section 409A.

9.2 To the extent Section 409A is applicable to the Executive:

(a) The Executive shall not be deemed to have terminated employment for purposes of any payment or benefit under this Agreement that constitutes non-qualified deferred compensation unless and until a separation from service (within the meaning of Treasury Regulation Section 1.409A-1(h)) has occurred. If the Executive is a “specified employee” under Section 409A, no payment, distribution or other benefit provided pursuant to this Agreement constituting non-qualified deferred compensation (within the meaning of Treasury Regulation Section 1.409A-1(b)) that is required to be delayed to comply with Section 409A(a)(2)(B)(i) shall be provided before the date that is six months after the date of the Executive’s separation from service (or, if earlier than the end of such six-month period, the date of death of the specified employee). Any payment, distribution or other benefit that is delayed pursuant to the prior sentence shall be paid on the first business day following the six-month anniversary of the separation from service.

(b) In no event may the Executive, directly or indirectly, designate the calendar year of any payment to be made under this Agreement.

(c) Each payment under this Agreement shall be treated as a separate payment for purposes of Section 409A.

(d) All reimbursements and in-kind benefits provided under this Agreement shall be made or provided in accordance with the requirements of Section 409A, including, where applicable, the requirement that (i) any reimbursement shall be for expenses incurred during the time period specified in this Agreement, (ii) the amount of expenses eligible for reimbursement, or in-kind benefits provided, during a calendar year may not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other calendar year, (iii) the reimbursement of an eligible expense will be made not later than the last day of the Executive’s taxable year following the taxable year in which such expense was incurred, and (iv) the right to reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit.Notwithstanding anything in this Agreement to the contrary, with respect to payment of legal fees and expenses pursuant to Section 5.0 hereof, if the court or other tribunal has not yet found in favor or againstthe Executive prior to the last day of the Executive’s taxable year following the taxable year in which such fees and expenses were incurred, such fees and expenses will be paid on the last day of such taxable year following the taxable year in which such fees and expenses were incurred.If such court or other tribunal does not ultimately find in favor of the Executive, the Executive will repay to the Corporation as soon as practicable, but in no event more than ninety (90) days after the court or other tribunal renders its ruling, any amounts paid or reimbursed pursuant to the prior sentence that would not have been paid or reimbursed pursuant to Section 5.0 but for the prior sentence.

10.0 Reduction of Certain Payments. This Section 10.0 shall apply to the Executive only if and to the extent that Section 4999 of the Code is applicable to the Executive.

10.1 Anything in this Agreement to the contrary notwithstanding, if the Accounting Firm (as defined below) shall determine that receipt of all Payments (as defined below) of the Executive would subject the Executive to the Excise Tax (as defined below), the Accounting Firm shall determine whether to reduce any of the Payments paid or payable pursuant to this Agreement (the “Agreement Payments”) so that the Parachute Value (as defined below) of all Payments, in the aggregate, equals the Safe Harbor Amount (as defined below). The Agreement Payments shall be so reduced only if the Accounting Firm determines that the Executive would have a greater Net After-Tax Receipt (as defined below) of aggregate Payments if the Agreement Payments were so reduced. If the Accounting Firm determines that the Executive would not have a greater Net After-Tax Receipt of aggregate Payments if the Agreement Payments were so reduced, the Executive shall receive all Agreement Payments to which the Executive is entitled hereunder.

10.2 If the Accounting Firm determines that aggregate Agreement Payments should be reduced so that the Parachute Value of all Payments, in the aggregate, equals the Safe Harbor Amount, the Corporation shall promptly give the Executive notice to that effect and a copy of the detailed calculation thereof.All determinations made by the Accounting Firm under this Section 10.0 shall be binding upon the Corporation, its Affiliates and the Executive.All reasonable fees and expenses of the Accounting Firm shall be borne solely by the Corporation.For purposes of reducing the Agreement Payments so that the Parachute Value of all Payments, in the aggregate, equals the Safe Harbor Amount, only amounts payable under the Agreement (and no other Payments) shall be reduced.The reduction of the amounts payable hereunder, if applicable, shall be made by reducing the Agreement Payments that have a Parachute Value in the following order:first, non-cash benefits that do not constitute non-qualified deferred compensation, second, cash benefits that constitute non-qualified deferred compensation, third, non-cash benefits that constitute non-qualified deferred compensation,and fourth, cash benefits that constitute non-qualified deferred compensation, with benefits within each category reduced in reverse chronological order beginning with those that are to be paid or provided the farthest in time from the Date of Termination, based on the Accounting Firm’s determination.

10.3 To the extent requested by the Executive, the Corporation and its Affiliates shall cooperate with the Executive in good faith in valuing, and the Accounting Firm shall take into account the value of, services provided or to be provided by the Executive (including, without limitation, the Executive’s agreeing to refrain from performing services pursuant to a covenant not to compete or similar covenant, before, on or after the date of a change in ownership or control of the Corporation (within the meaning of Q&A-2(b) of the final regulations under Section 280G of the Code)), such that payments in respect of such services may be considered reasonable compensation within the meaning of Q&A-9 and Q&A-40 to Q&A-44 of the Treasury Regulations under Section 280G of the Code and/or exempt from the definition of the term “parachute payment” within the meaning of Q&A-2(a) of the Treasury Regulations under Section 280G of the Code in accordance with Q&A-5(a) of the Treasury Regulations under Section 280G of the Code.

10.4 The following terms shall have the following meanings for purposes of this Section 9.0:

(a) “Accounting Firm” shall mean a nationally recognized certified public accounting firm or other professional organization that is a certified public accounting firm recognized as an expert in determinations and calculations for purposes of Section 280G of the Code that is selected by the Corporation prior to a Change in Control for purposes of making the applicable determinations hereunder.

(b) “Excise Tax” means any excise tax imposed under Section 4999 of the Code.

(c) “Net After-Tax Receipt” shall mean the present value (as determined in accordance with Sections 280G(b)(2)(A)(ii) and 280G(d)(4) of the Code) of a Payment net of all taxes imposed on the Executive with respect thereto under Sections 1 and 4999 of the Code and under applicable state and local laws, determined by applying the highest marginal rate under Section 1 of the Code and under state and local laws which applied to the Executive’s taxable income for the immediately preceding taxable year, or such other rate(s) as the Accounting Firm determines to be likely to apply to the Executive in the relevant tax year(s).

(d) “Parachute Value” of a Payment shall mean the present value as of the date of the change in control for purposes of Section 280G of the Code of the portion of such Payment that constitutes a “parachute payment” under Section 280G(b)(2) of the Code, as determined by the Accounting Firm for purposes of determining whether and to what extent the Excise Tax will apply to such Payment.

(e) “Payment” shall mean any payment or distribution in the nature of compensation (within the meaning of Section 280G(b)(2) of the Code) to or for the benefit of the Executive, whether paid or payable pursuant to this Agreement or otherwise.

(f) “Safe Harbor Amount” shall mean the maximum Parachute Value of all Payments that the Executive can receive without any Payments being subject to the Excise Tax.

11.0 Miscellaneous

11.1 Amendment and Waiver. No provision of this Agreement may be modified, waived or discharged unless such waiver, modification or discharge is agreed to in a writing signed by the Parties hereto. No waiver by either Party of, or in compliance with, any condition or provision of this Agreement to be performed by the other Party shall be deemed a waiver of similar or dissimilar provisions or conditions at the same or at any prior or subsequent time.

11.2 Deductions. The Executive agrees that benefits and payments to which the Executive is entitled pursuant to this Agreement are subject to deductions or other source withholdings as may be required by law.

11.3 No Mitigation. The Executive shall not be required to mitigate the amount of any payment provided for in this Agreement by seeking other employment or otherwise, nor shall the amount of any payment or benefit provided to the Executive by the Corporation referred to in this Agreement be reduced by any compensation earned by, or benefits paid to, the Executive as the result of employment, whether by another employer or self-employment, or by pension benefits after the Date of Termination, or otherwise, except as specifically provided in this Agreement.

11.4 Governing Law. This Agreement shall be construed and enforced in accordance with, and the rights of the Parties shall be governed by, the laws of the Province of Alberta.

11.5 Currency. All amounts due under this Agreement shall be paid calculated and paid in the currency in which the Executive’s base salary is paid as of immediately prior to the Date of Termination.

11.6 Validity. The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which shall remain in full force and effect.

11.7 Counterparts. This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original and all of which together shall constitute one and the same Agreement.

11.8 Headings. The division of this Agreement into sections, subsections and clauses, or other portions hereof and the insertion of headings or subheadings, are for convenience of reference only and shall not affect the construction or interpretation of this Agreement.

12.0 Survivorship

Upon the expiration or other termination of this Agreement or the Executive’s employment, the respective rights and obligations of the Parties shall survive to the extent necessary to carry out the intentions of the Parties under this Agreement.

IN WITNESS WHEREOF, the Executive and the Corporation have caused this Agreement to be duly executed effective as of the date first above written.

ENCANA CORPORATION

Per: /s/ Douglas J. Suttles

Name: Douglas J. Suttles
Title: Chief Executive Officer

Per: /s/ Mike Williams

Name: Mike Williams
Title: Executive Vice-President, Corporate Services

/s/ Gregory D. Givens

GREGORY D. GIVENS

EX-10.3

Exhibit 10.3

Fifth Amendment

to The

Encana (USA) Retirement Plan

(Amended and Restated Effective March 14, 2014)

1.Plan Sponsor:  Encana Services Company Ltd. (the “Plan Sponsor”).

2.Amendment of Plan:  Pursuant to the authority of the undersigned and the provisions of Section 13.1 of the Encana (USA) Retirement Plan (the “Plan”), the following Amendment to the Plan is adopted, effective as provided below.

A.Effective January 1, 2017, the following sentences are added to the end of Section 1.12 of the Plan as follows:

Notwithstanding the foregoing, for purposes of calculating Safe Harbor Matching Contributions under Section 3.2(a) during the 2017 Plan Year for Participants whose target bonus award under the Annual Bonus program was exactly 10% for the 2016 performance period, Compensation also includes the amount of such bonus actually paid to the Participant in 2017. Such bonuses will not be taken into account under Compensation for any other purpose, including, but not limited to, calculation of Deferral Contributions.

B.Effective January 1, 2018, the Plan is amended to remove the defined term “Highly Compensated Participant” by virtue of amending Section 1.36 to read as follows:

1.36 Reserved.

C.Effective January 1, 2018, the Plan is amended to remove the defined term “Non-Highly Compensated Participant” by virtue of amending Section 1.41 to read as follows:

1.41 Reserved.

D.Effective January 1, 2018, Section 1.51 is amended to read as follows:

1.51 Qualified Matching Contribution Account means the individual account established in the name of each Participant reflecting his qualified matching contributions, and the net earnings or losses thereon

E.Effective January 1, 2018, the Plan is amended to remove the defined term “Qualified Matching Contributions or QMACs” by virtue of amending Section 1.52 to read as follows:

1.52 Reserved.

F.Effective January 1, 2018, Section 1.54 is amended to read as follows:

1.54 Qualified Nonelective Contributions or QNECs means the contributions (other than qualifying matching contributions) to the Trust Fund that may be made by the

Employer on behalf of a Participant for the purpose of making corrections pursuant to the Employee Plans Compliance Resolution System.

G.Effective January 1, 2018, Section 3.5 is amended to read as follows:

3.5 Qualified Nonelective Contributions.  The Employer may, for any Plan Year, make QNECs on behalf of Participants in such amount when necessary.  QNECs are 100% vested and nonforfeitable when contributed to the Plan and are subject to the same “Distribution Restrictions” imposed on Deferral Contributions.  Distribution Restrictions means that the Participant may not receive a distribution of the specified contributions (nor earnings on those contributions) except in the event of: the Participant’s death, disability, termination of employment, or attainment of age 59½, financial hardship satisfying the requirements of Code Section 401(k) and applicable Regulations, and a Plan termination without establishment of a successor defined contribution plan (other than an ESOP). To the extent permitted by law, the Employer may designate which Participants are to receive allocations of QNECs, and the method by which they are intended to be allocated to Participants.

H.Effective January 1, 2018, Sections 6.1(a), 6.1(b), 6.1(d), 6.1(e), 6.1(g) and 6.1(h) are all revised to read as follows:

Reserved.

I.Effective January 1, 2018, Section 6.2 of the Plan is amended, to read as follows:

6.2 Average Deferral Percentage Limitations.  The ADP Test of Code Section 401(k)(3) will be deemed satisfied by virtue of the Plan’s design and operation as a Safe Harbor Plan.

J.Effective January 1, 2018, Section 6.3 of the Plan is amended, to read as follows:

6.3 Average Contribution Percentage Limitations.  The ACP Test of Code Section 401(m)(1) will be deemed satisfied by virtue of the Plan’s design and operation as a Safe Harbor Plan.

3.Terms and Conditions of Plan:  Except for the above amendment, all terms and conditions of the Plan are unamended and shall remain in full force and effect.

3.Execution:  This Amendment has been executed on the date set forth below.

Encana Services Company Ltd.

Plan Sponsor

By:  /s/ Christopher J. Casebolt

Title:  Member, Management Pension & Benefits Committee

Date:  10/08/2018

11460510_v4

EX-10.4

Exhibit 10.4

Sixth Amendment

to The

Encana (USA) Retirement Plan

(Amended and Restated Effective March 14, 2014)

1.Plan Sponsor:  Encana Services Company Ltd. (the “Plan Sponsor”).

2.Amendment of Plan:  Pursuant to the authority of the undersigned and the provisions of Section 13.1 of the Encana (USA) Retirement Plan (the “Plan”), the following Amendment to the Plan is adopted, effective as of the dates set forth below.

A.Effective with respect to hardship distributions on or after July 1, 2019 or as otherwise noted herein, Section 8.3 of the Plan is amended to read as follows:

8.3 Hardship Withdrawals.  In accordance with the limitations of this Section 8.3 and such other rules and restrictions imposed by the Administrator, prior to a Participant’s attainment of age 59½, a Participant will be permitted to withdraw for reasons of hardship all or a portion of the Participant’s previously undistributed Deferral Account, Qualified Nonelective Contribution Account, Qualified Matching Contribution Account and Safe Harbor Matching Contribution Account, including earnings on all such accounts (other than the portion of the Account used as security for a Plan loan) if the withdrawal is made on account of an immediate and heavy financial need of the Participant and the distribution is necessary to satisfy that financial need.  The Administrator will direct the Trustee to make the hardship distribution as soon as administratively practicable after the Participant makes a valid request for the hardship withdrawal in the manner required by the Administrator.

(a) Immediate and Heavy Financial Need.  A distribution will be deemed to be necessary to satisfy the immediate and heavy financial need of the Participant only if the distribution is made on account of any one of the following:

(1) expenses for medical care, or to obtain such medical care, for the Participant, the Participant’s Spouse, the Participant’s dependents (as defined in Code Section 152, without regard to Code Sections 152(b)(1), (b)(2) and (d)(1)(B)), or the Participant’s Beneficiary that would be deductible under Code Section 213(d) (determined without regard to whether the expenses exceed 7.5% of adjusted gross income);

(2) payments for tuition, related educational fees and room and board expenses, for the next 12 months of post-secondary education for the Participant, the Participant’s Spouse, children, dependents (as defined in Code Section 152, without regard to Code Sections 152(b)(1), (b)(2) and (d)(1)(B)), or Beneficiary;

(3) costs directly related to the purchase (excluding mortgage payments) of a principal residence for the Participant;

(4) payments needed to prevent either the eviction of the Participant from the Participant’s principal residence or the foreclosure on the mortgage of the Participant’s principal residence;

(5) payments for burial or funeral expenses of the Participant’s deceased parent, Spouse, children, dependents (as defined in Code Section 152, without regard to Code Section 152(d)(1)(B)), or Beneficiary;

(6) expenses for the repair of damage to the Participant’s principal residence that would qualify for the casualty deduction under Code Section 165 (determined without regard to whether the loss exceeds 10% of adjusted gross income), and for taxable years beginning on or after January 1, 2018, without regard to Code Section 165(h)(5));

(7) expenses and losses (including loss of income) incurred by the Participant on account of a disaster declared by the Federal Emergency Management Agency (“FEMA”) under the Robert T. Stafford Disaster Relief and Emergency Assistance Act, provided that the Participant’s principal residence or principal place of employment at the time of the disaster is located in the area designated by FEMA as eligible for assistance with respect to the disaster; or

(8) such other reasons as deemed by the Regulations to satisfy an immediate and heavy financial need of the Participant under the “safe harbor” standard.

(b) Satisfaction of Need.  Any hardship withdrawal from the Plan will be deemed to meet the requirement that the distribution is necessary to satisfy that financial need if:

(1) the amount of the hardship withdrawal does not exceed the amount of the immediate and heavy financial need of the Participant (including any amounts necessary to pay any federal, state or local income taxes or penalties reasonably anticipated to result from the distribution);

(2) for hardship withdrawals made prior to July 1, 2019, the Participant obtains all distributions (other than the hardship withdrawal) and all nontaxable loans available under all plans of the Employer before receiving a hardship withdrawal;

(3) for hardship withdrawals made on or after July 1, 2019, the Participant obtains all distributions (other than the hardship withdrawal) except for nontaxable loans available under all plans of the Employer before receiving a hardship withdrawal;

(4) for hardships withdrawals made prior to July 1, 2019, the Participant’s Deferral Contributions and any other employee contributions to all deferred compensation plans of the Employer are suspended for six months following the date the Participant receives the hardship withdrawal and requires an affirmative Participant election in order to be reinstated thereafter.  Notwithstanding the foregoing, effective July 1, 2019, any Participant in the midst of such a six-month hardship suspension will have the suspension lifted effective immediately, and such Participant may make an affirmative election to reinstate deferrals at any time; and

(5) for hardship withdrawals made on or after January 1, 2020, the Participant represents in writing (which may be electronic) that the Participant has insufficient cash or other liquid assets to satisfy the need.

B.Effective April 1, 2019, Schedule A of the Plan is amended to read as attached hereto.

C.Effective April 1, 2019, Schedule B of the Plan is amended to read as attached hereto.

D.Effective July 1, 2019, Schedule C of the Plan is amended to read as attached hereto.

3.Terms and Conditions of Plan:  Except for the above amendment, all terms and conditions of the Plan are unamended and shall remain in full force and effect.

3.Execution:  This Sixth Amendment has been executed on the date set forth below.

Encana Services Company Ltd.

Plan Sponsor

By:  /s/ Christopher J. Casebolt

          Christopher J. Casebolt, on behalf of the
          Management Pension & Benefits Committee

Date:  08/08/2019

Encana (USA) Retirement Plan

Schedule A -
Participating Employers

Employer	Effective Date of Participation (if after the Effective Date of this amendment and restatement)
Encana Oil & Gas (USA) Inc.	n/a
Encana Corporation (for the limited purposes specified in Section 1.22)	June 1, 2018
Newfield Exploration Company	April 1, 2019

* * * * End of Schedule A * * * *

Encana (USA) Retirement Plan

Schedule B -
Imputed Service for Predecessor and Related Employers

Employer: Imputed Service Credit

Newfield Exploration Company: Service performed for Newfield Exploration Company before April 1, 2019.

* * * * End of Schedule B * * * *

Encana (USA) Retirement Plan

Schedule C -

Protected Benefits

I.In-Service Withdrawal of After-Tax Contributions

Notwithstanding anything in the Plan to the contrary, if after-tax contributions were transferred to the Plan pursuant to a plan merger or trust-to-trust transfer, a Participant may request an in-service withdrawal of all or a portion of the Participant’s Account which represents such after-tax contributions.  For purposes of the preceding sentence, “after-tax contributions” do not include Roth Contributions.

II.Protected Benefits for Athlon Plan Accounts

This section applies to the accounts transferred to the Plan from the Athlon 401(k) Plan (the “Athlon Plan”) in connection with the merger of the Athlon Plan into the Plan effective as of December 31, 2015.  Any account(s) transferred from the Athlon Plan will be called the Participant’s “Athlon Account(s)” and will be entitled to the protected benefit features contained in this Section II of Schedule C.  The Athlon Accounts will be subject to the regular provisions of the Plan as modified by this Section II of Schedule C.

Participant Accounts

Pursuant to Section 5.1(h) of the Plan, an Athlon Account (defined above) also qualifies as a Participant Account for those Participants who have an Athlon Account as a result of the merger.

Optional Forms

In addition to the optional forms of distribution available under Section 7.3 of the Plan, Athlon Accounts may be distributed in the following optional forms:

Fixed Payment Installment Option.  The fixed payment installment option is an optional form of benefit under which the Participant elects to receive a specified dollar amount each year.  The annual payment may be paid in annual, semi-annual, quarterly, or monthly installments as elected by the Participant.  The Participant may elect to receive additional payments.  The amount payable must satisfy minimum distribution requirements.

In-Service Withdrawals

In addition to the in-service withdrawals available under Section 8.2 of the Plan, Athlon Accounts may be subject to the following additional in-service withdrawal option for qualified Participants:

Qualified Reservist Distribution.  A Participant who is called to active military duty and who is otherwise eligible, is entitled to an in-service withdrawal in the form of a Qualified Reservist Distribution as defined in Code Section 72(t)(2)(G)(iii).

III.Protected Benefits for Newfield Plan Accounts

This section applies to the accounts transferred to the Plan from the Newfield Exploration Company 401(k) Plan (the “Newfield Plan”) in connection with the merger of the Newfield Plan into the Plan effective as of July 1, 2019.  Any account(s) transferred from the Newfield Plan will be called the Participant’s “Newfield Account(s)” and will be entitled to the protected benefit features contained in this Section III of Schedule C.  The Newfield Accounts will be subject to the regular provisions of the Plan as modified by this Section III of Schedule C.

Participant Accounts

Pursuant to Section 5.1(h) of the Plan, a Newfield Account (defined above) also qualifies as a Participant Account for those Participants who have a Newfield Account as a result of the merger.

Pursuant to Section 5.1(h) of the Plan, a Participant’s Newfield Account may include an account containing non safe-harbor employer matching contributions (“Newfield Employer Match Account”).  Any Newfield Employer Match Account will qualify as a component of a Participant Account and will be maintained under the Plan, with no further contributions permitted as of April 1, 2019.

Pursuant to Section 5.1(h) of the Plan, a Participant’s Newfield Account may include an account containing voluntary after-tax employee contributions (“Newfield After-Tax Account”).  Such a Newfield After-Tax Account will qualify as a component of a Participant Account and will be maintained under the Plan, with no further contributions permitted as of April 1, 2019.

Optional Forms

In addition to the optional forms of distribution available under Section 7.3 of the Plan, Newfield Accounts may be distributed in the following optional form:

Partial Distributions.  Subject to the required minimum distribution rules and Administrator requirements, a Participant may request a distribution of any portion of the Participant’s Newfield Account.

In-Service Withdrawals

In addition to the in-service withdrawals available under Section 8.2 of the Plan, Newfield Accounts may be subject to the following additional in-service withdrawal option for qualified Participants:

Newfield After-Tax Account.  A Participant may withdraw all or any portion of the Participant’s Newfield After-Tax Account at any time.

Deemed Severance Distribution. A Participant who is called to active military duty and who is otherwise eligible, is entitled to an in-service withdrawal of his or her Newfield Account in the form of a deemed severance distribution as defined in Code Section 414(u)(12).

Qualified Reservist Distribution.  A Participant who is called to active military duty and who is otherwise eligible, is entitled to an in-service withdrawal of his or her Newfield Account in the form of a Qualified Reservist Distribution as defined in Code Section 72(t)(2)(G)(iii).

* * * * End of Schedule C * * * *

12030828_v4

EX-10.5

Exhibit 10.5

CERTIFICATE OF AMENDMENT

TO THE

ENCANA CORPORATION CANADIAN PENSION PLAN

AMENDED AND RESTATED EFFECTIVE JANUARY 1, 2011

WHEREAS Encana Corporation (the “Company”) sponsors the Encana Corporation Canadian Pension Plan (the “Plan”);

AND WHEREAS pursuant to Section 1.5.4, the Company reserves the right to amend the Plan;

AND WHEREAS the Company wishes to amend the Plan, effective December 3, 2017, to accommodate the changes to the parental benefit provided under the Employment Insurance Act (Canada);

NOW THEREFORE WE CERTIFY that the Plan is hereby amended as described in the attached Amendment Number 4.

CERTIFIED to be an approved amendment of the Plan on this 13 day of September, 2019.

/s/ Mike Williams	/s/ Rachel Moore
Signature	Signature
Mike Williams	Rachel Moore
Executive Vice-President, Corporate Services	Vice-President, Human Resources
ENCANA CORPORATION	ENCANA CORPORATION
Acting by and through its authorized agent	Acting by and through its authorized agent
ENCANA SERVICES COMPANY LTD.	ENCANA SERVICES COMPANY LTD.

AMENDMENT NUMBER 4

ENCANA CORPORATION CANADIAN PENSION PLAN

The Encana Corporation Canadian Pension Plan (the “Plan”) is hereby amended as follows:

Effective December 3, 2017:

1. Section 1.3.8 is amended by adding the following paragraph before the last paragraph:

“For greater certainty, when, as permitted under the Employment Insurance Act (Canada) the duration of a Participant’s parenting leave exceeds the 12 month limit set out in paragraph (b), above, the remaining period of parenting leave will be subject to, and reduce the limit set out in, paragraph (a), above.”

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO RULE 13a-14(a) OR 15d-14(a) OF THE

SECURITIES EXCHANGE ACT OF 1934, AS ADOPTED PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Douglas J. Suttles, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Encana Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated: November 4, 2019

/s/ Douglas J. Suttles

Douglas J. Suttles
Chief Executive Officer

(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION PURSUANT TO RULE 13a-14(a) OR 15d-14(a) OF THE

SECURITIES EXCHANGE ACT OF 1934, AS ADOPTED PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Corey D. Code, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Encana Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated: November 4, 2019

/s/ Corey D. Code

Corey D. Code
Executive Vice-President & Chief Financial Officer
(Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Encana Corporation (the “Company”) on Form 10-Q for the period ended September 30, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Douglas J. Suttles, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.  

By: /s/ Douglas J. Suttles

Douglas J. Suttles

Chief Executive Officer

Dated: November 4, 2019

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Encana Corporation (the “Company”) on Form 10-Q for the period ended September 30, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Corey D. Code, Executive Vice-President & Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.  

By: /s/ Corey D. Code

Corey D. Code

Executive Vice-President & Chief Financial Officer

Dated: November 4, 2019

XML

Condensed Consolidated Balance Sheet (Parenthetical) (unaudited) - shares shares in Millions	Sep. 30, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Common Stock, Shares, Issued	1,299.2	952.5
Common Stock, Shares, Outstanding	1,299.2	952.5

XML

Restructuring Charges

9 Months Ended

Sep. 30, 2019

Restructuring Charges [Abstract]

Restructuring Charges

18. Restructuring Charges

In February 2019, in conjunction with the Newfield business combination as described in Note 8, Encana announced workforce reductions to better align staffing levels and the organizational structure with the Company’s strategy. During the three and nine months ended September 30, 2019, the Company incurred total restructuring charges of $4 million and $134 million, respectively, before tax, primarily related to severance costs. As at September 30, 2019, $4 million remains accrued and is expected to be paid during the remainder of 2019 and in 2020.

Restructuring charges are included in administrative expense presented in the Corporate and Other segment in the Condensed Consolidated Statement of Earnings.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Severance and Benefits	$	4	$	-	$	132	$	-
Outplacement, Moving and Other Expenses		-		-		2		-
Restructuring Expenses	$	4	$	-	$	134	$	-

	As at			As at
	September 30,			December 31,
	2019			2018
Outstanding Restructuring Accrual, Beginning of Year	$	-		$	-
Restructuring Expenses Incurred		134			-
Restructuring Costs Paid		(130	)		-
Outstanding Restructuring Accrual, End of Period (1)	$	4		$	-

(1) Included in accounts payable and accrued liabilities in the Condensed Consolidated Balance Sheet.

XML

Asset Retirement Obligation

9 Months Ended

Sep. 30, 2019

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligation

14. Asset Retirement Obligation

	As at			As at
	September 30,			December 31,
	2019			2018
Asset Retirement Obligation, Beginning of Year	$	455		$	514
Liabilities Incurred		13			17
Liabilities Acquired (See Note 8)		184			-
Liabilities Settled and Divested		(100	)		(56	)
Change in Estimated Future Cash Outflows		-			(20	)
Accretion Expense		28			32
Foreign Currency Translation		10			(32	)
Asset Retirement Obligation, End of Period	$	590		$	455
Current Portion	$	176		$	90
Long-Term Portion		414			365
	$	590		$	455

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 25, 2019
Cover [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2019
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2019
Entity Registrant Name	ENCANA CORP
Entity Central Index Key	0001157806
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		1,299,112,236
Trading Symbol	ECA
Document Quarterly Report	true
Document Transition Report	false
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity File Number	1-15226
Entity Tax Identification Number	98-0355077
Entity Address, Address Line One	Suite 4400
Entity Address, Address Line Two	500 Centre Street S.E.
Entity Address, Address Line Three	P.O. Box 2850
Entity Address, City or Town	Calgary
Entity Address, State or Province	AB
Entity Address, Country	CA
Entity Address, Postal Zip Code	T2P 2S5
City Area Code	403
Local Phone Number	645-2000
Entity Incorporation, State or Country Code	Z4
Title of 12(b) Security	Common Shares
Security Exchange Name	NYSE

XML

Basis of Presentation and Principles of Consolidation

9 Months Ended

Sep. 30, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Basis of Presentation and Principles of Consolidation

1. Basis of Presentation and Principles of Consolidation

Encana is in the business of the exploration for, the development of, and the production and marketing of oil, NGLs and natural gas.

The interim Condensed Consolidated Financial Statements include the accounts of Encana and entities in which it holds a controlling interest. All intercompany balances and transactions are eliminated on consolidation. Undivided interests in oil and natural gas exploration and production joint ventures and partnerships are consolidated on a proportionate basis. Investments in non-controlled entities over which Encana has the ability to exercise significant influence are accounted for using the equity method.  

The interim Condensed Consolidated Financial Statements are prepared in conformity with U.S. GAAP and the rules and regulations of the SEC. Pursuant to these rules and regulations, certain information and disclosures normally required under U.S. GAAP have been condensed or have been disclosed on an annual basis only. Accordingly, the interim Condensed Consolidated Financial Statements should be read in conjunction with the annual audited Consolidated Financial Statements and the notes thereto for the year ended December 31, 2018, which are included in Item 8 of Encana’s 2018 Annual Report on Form 10-K.

The interim Condensed Consolidated Financial Statements have been prepared following the same accounting policies and methods of computation as the annual audited Consolidated Financial Statements for the year ended December 31, 2018, except as noted below in Note 2. The disclosures provided below are incremental to those included with the annual audited Consolidated Financial Statements.

These unaudited interim Condensed Consolidated Financial Statements reflect, in the opinion of Management, all normal and recurring adjustments necessary to present fairly the financial position and results of the Company as at and for the periods presented. Interim condensed consolidated financial results are not necessarily indicative of consolidated financial results expected for the fiscal year.

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Fair Value Measurements (Quantitative Information About Unobservable Inputs Used In Level 3) (Details) - WTI Options [Member] - Option Model	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Minimum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Fair Value Inputs Commodity Price Volatility	22.00%	29.00%
Maximum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Fair Value Inputs Commodity Price Volatility	61.00%	73.00%

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Financial Instruments and Risk Management (Earnings Impact of Realized and Unrealized Gains (Losses) On Risk Management Positions) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	$ 124	$ (76)	$ 302	$ (84)
Unrealized Gain (Loss) on Derivatives	(52)	(155)	(359)	(439)
Realized and Unrealized Gain (Loss) on Risk Management	72	(231)	(57)	(523)
Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	122	(77)	301	(95)
Unrealized Gain (Loss) on Derivatives	(41)	(164)	(385)	(422)
Realized and Unrealized Gain (Loss) on Risk Management	81	(241)	(84)	(517)
Foreign Currency Gain (Loss) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	2	1	1	11
Unrealized Gain (Loss) on Derivatives	(11)	9	26	(17)
Realized and Unrealized Gain (Loss) on Risk Management	$ (9)	$ 10	$ 27	$ (6)

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Leases (Tables)

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Summary of Operating and Finance Lease Costs

The tables below summarize Encana’s operating and finance lease costs and include ROU assets and lease liabilities, amounts recognized in net earnings during the period and other lease information.

(US$ millions, unless otherwise specified)	As at September 30, 2019
Condensed Consolidated Balance Sheet (1):
Operating Lease ROU Assets, in Other Assets	$	1,045
Finance Lease ROU Assets, in Other Property Plant and Equipment		39
Operating Lease Liabilities:
Current		79
Long-term		972
Finance Lease Liabilities:
Current, in accounts payable and accrued liabilities		88
Long-term, in other liabilities and provisions		144
Weighted Average Discount Rate
Operating leases	5.42%
Finance leases	5.97%
Weighted Average Remaining Lease Term
Operating leases	16.4 years
Finance leases	3.4 years

(1) Total ROU assets and liabilities are recorded at the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Lease Costs (1):
Operating Lease Costs, Excluding Short-Term Leases	$	45	$	133
Finance Lease Costs:
Amortization of ROU assets		1		3
Interest on lease liabilities		3		10
Total Finance Lease Costs		4		13
Short-Term Lease Costs		93		250
Variable Lease Costs		3		10
Sublease Income:
Operating lease income		15		41
Variable lease income		4		13
Other Information:
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating cash outflows from operating leases		57		157
Investing cash outflows from operating leases		80		220
Operating cash outflows from finance leases		3		10
Financing cash outflows from finance leases		22		63
Supplemental Non-Cash Information:
New ROU operating lease assets and liabilities		1		11

(1) Lease costs include amounts capitalized into property, plant and equipment on the Condensed Consolidated Balance Sheet and lease expense recognized in the Condensed Consolidated Statement of Earnings.

Schedule Operating Lease Expense

Operating lease expense is reflected in the Condensed Consolidated Statement of Earnings as follows:

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Operating Lease Expense
Transportation and processing	$	1	$	2
Operating		28		76
Administrative (1)		30		86
Total Operating Lease Expense	$	59	$	164

(1) Includes $23 million and $69 million for the three and nine months ended September 30, 2019, respectively, related to The Bow office building.

Schedule of Future Lease Payments and Lease Liabilities Related to Operating and Finance Leases

The following table outlines the Company’s future lease payments and lease liabilities related to the Company’s operating and finance leases as at September 30, 2019:

	2019			2020			2021			2022			2023			Thereafter			Total
Operating Leases (1)
Expected Future Lease Payments	$	37		$	128		$	112		$	97		$	85		$	1,165		$	1,624
Less: Discounting																				573
Present Value of Future Operating    Lease Payments																			$	1,051
Sublease Income (undiscounted)	$	(10	)	$	(41	)	$	(42	)	$	(37	)	$	(37	)	$	(566	)	$	(733	)
Finance Leases
Expected Future Lease Payments	$	25		$	99		$	87		$	8		$	8		$	30		$	257
Less: Discounting																				25
Present Value of Future Finance    Lease Payments																			$	232
Sublease Income (undiscounted) (2)	$	(2	)	$	(8	)	$	(8	)	$	(8	)	$	(7	)	$	(24	)	$	(57	)

(1) Lease payments are presented based on the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

(2) Classified as operating lease.

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Share Capital (Tables)

9 Months Ended

Sep. 30, 2019

Class Of Stock Disclosures [Abstract]

Schedule of Common Stock Issued and Outstanding

	As at September 30, 2019						As at December 31, 2018
	Number (millions)			Amount			Number (millions)			Amount
Common Shares Outstanding, Beginning of Year		952.5		$	4,656			973.1		$	4,757
Common Shares Purchased		(196.7	)		(1,073	)		(20.7	)		(102	)
Common Shares Issued		543.4			3,478			-			-
Common Shares Issued Under Dividend Reinvestment Plan		-			-			0.1			1
Common Shares Outstanding, End of Period		1,299.2		$	7,061			952.5		$	4,656

Earnings Per Common Share

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(US$ millions, except per share amounts)	2019		2018		2019		2018
Net Earnings (Loss)	$	149	$	39	$	240	$	39
Number of Common Shares:
Weighted average common shares outstanding - Basic		1,322.8		955.1		1,308.4		962.2
Effect of dilutive securities		-		-		-		-
Weighted Average Common Shares Outstanding - Diluted		1,322.8		955.1		1,308.4		962.2
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.11	$	0.04	$	0.18	$	0.04

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Pension and Other Post-Employment Benefits (Total Benefit Plan Expense Recognized) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Net Defined Periodic Benefit Cost	$ 14	$ 6
Defined Contribution Plan Expense	18	17
Total Benefit Plans Expense	32	23
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net Defined Periodic Benefit Cost	1	1
Defined Contribution Plan Expense	18	17
Total Benefit Plans Expense	19	18
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Net Defined Periodic Benefit Cost	13	5
Defined Contribution Plan Expense	0	0
Total Benefit Plans Expense	$ 13	$ 5

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Business Combination - Schedule of Preliminary Purchase Price Allocations (Details) - USD ($) $ in Millions		Feb. 13, 2019	Sep. 30, 2019	Dec. 31, 2018
Assets Acquired:
Goodwill			$ 2,595	$ 2,553
Newfield Exploration Company [Member]
Consideration:
Fair value of Encana's common shares issued	[1]	$ 3,478
Business acquisition, payment in cash	[2]	5
Total Consideration		3,483
Assets Acquired:
Cash and cash equivalents		46
Accounts receivable and accrued revenues		486
Other current assets		50
Restricted cash		53
Other assets		105
Goodwill	[3]	22
Liabilities Assumed:
Accounts payable and accrued liabilities	[3]	(795)
Long-term debt		(2,603)
Operating lease liabilities		(76)
Other long-term liabilities	[3]	(61)
Asset retirement obligation		(184)
Deferred income taxes	[3]	(323)
Total Purchase Price		3,483
Proved Properties [Member] | Newfield Exploration Company [Member]
Assets Acquired:
Property, plant and equipment, net		5,903
Unproved Properties [Member] | Newfield Exploration Company [Member]
Assets Acquired:
Property, plant and equipment, net		838
Other Property, Plant and Equipment [Member] | Newfield Exploration Company [Member]
Assets Acquired:
Property, plant and equipment, net		$ 22

[1] The fair value was based on the NYSE closing price of the Encana common shares of $6.40 on February 13, 2019.

[2] The fair value was based on a price of $6.50 per notional unit which was determined using a volume-weighted average of the trading price of Encana common shares on the NYSE on each of the five consecutive trading days ending on the trading day that was three trading days prior to February 13, 2019.

[3] Since the completion of the business combination on February 13, 2019, additional information related to pre-acquisition liabilities and contingencies was obtained resulting in a measurement period adjustment. Changes in the fair value estimates comprised an increase in other liabilities of $12 million, of which the total liability is presented in accounts payable and accrued liabilities, a decrease in deferred tax liabilities of $3 million and a corresponding increase in goodwill of $9 million.

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Foreign Exchange (Gain) Loss, Net (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	$ 49	$ (23)	$ (11)	$ 156
Foreign Exchange (Gain) Loss, Net	30	(23)	(62)	93
Translation Of U.S. Dollar Debt Issued From Canada [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	68	(74)	(117)	138
Foreign Exchange on Settlements	(10)	0	(22)	1
Translation Of U.S. Dollar Risk Management Contracts Issued From Canada [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	5	(3)	(13)	7
Foreign Exchange on Settlements	(2)	(1)	(1)	(11)
Translation of Intercompany Notes [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	(24)	54	119	11
Foreign Exchange on Settlements	(8)	(1)	(31)	(48)
Other Monetary Revaluations [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Foreign Exchange on Settlements	$ 1	$ 2	$ 3	$ (5)

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Compensation Plans (Amounts Recognized For Share-Based Payment Transactions) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Costs of Transactions Classified as Cash-Settled	$ 2	$ 36	$ 46	$ 118
Less: Total Share-Based Compensation Costs Capitalized	(1)	(11)	(16)	(33)
Total Share-Based Compensation Expense	1	25	30	85
Operating Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Share-Based Compensation Expense	0	8	12	24
Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Share-Based Compensation Expense	$ 1	$ 17	$ 18	$ 61

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Restructuring Charges (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended
	Feb. 28, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
Restructuring Charges [Abstract]
Restructuring Charges		$ 4	$ 0	$ 134	$ 0	$ 0
Restructuring and Related Activities, Initiation Date	Feb. 01, 2019
Restructuring Reserve		$ 4		$ 4		$ 0	$ 0

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Segmented Information (Goodwill, Property, Plant and Equipment and Total Assets By Segment) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	$ 2,595		$ 2,553
Property, Plant and Equipment	15,126	$ 7,839	8,972
Total Assets	21,356	$ 15,198	15,344
Operating Segments [Member] | Canadian Operations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	660		640
Property, Plant and Equipment	1,111		999
Total Assets	1,978		1,852
Operating Segments [Member] | USA Operations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	1,935		1,913
Property, Plant and Equipment	13,782		6,591
Total Assets	16,634		9,104
Operating Segments [Member] | Market Optimization [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	0		0
Property, Plant and Equipment	2		1
Total Assets	225		295
Corporate & Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	0		0
Property, Plant and Equipment	231		1,381
Total Assets	$ 2,519		$ 4,093

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Recent Accounting Pronouncements - Schedule of Impacts from Recognizing Operating Leases on Condensed Consolidated Balance Sheet (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jun. 30, 2019	Jan. 01, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Dec. 31, 2017
Oil and natural gas properties, based on full cost accounting
Proved properties	$ 50,094		$ 41,241	$ 41,241
Unproved properties	3,943		3,730	3,730
Other	892		861	2,122
Property, plant and equipment	54,929		45,832	47,093
Less: Accumulated depreciation, depletion and amortization	(39,803)		(37,993)	(38,121)
Property, plant and equipment, net	15,126		7,839	8,972
Other Assets	1,202		1,162	147
Deferred Income Taxes	521		807	835
Total Assets	21,356		15,198	15,344
Current Liabilities
Accounts payable and accrued liabilities	2,191		1,478	1,490
Current portion of operating lease liabilities	79		67	0
Income tax payable	1		1	1
Risk management	10		25	25
Current portion of long-term debt	0		500	500
Total Current Liabilities	2,281		2,071	2,016
Operating Lease Liabilities	972		948	0
Other Liabilities and Provisions	548		545	1,769
Total Liabilities	11,435		7,676	7,897
Retained Earnings	452		510	435
Total Shareholders’ Equity	9,921	$ 10,015	7,522	7,447	$ 6,494	$ 6,497	$ 6,728
Total Liabilities and Shareholders’ Equity	$ 21,356		15,198	$ 15,344
Impact of Adoption [Member] | Topic 842 [Member]
Oil and natural gas properties, based on full cost accounting
Proved properties			0
Unproved properties			0
Other			(1,261)
Property, plant and equipment			(1,261)
Less: Accumulated depreciation, depletion and amortization			128
Property, plant and equipment, net			(1,133)
Other Assets			1,015
Deferred Income Taxes			(28)
Total Assets			(146)
Current Liabilities
Accounts payable and accrued liabilities			(12)
Current portion of operating lease liabilities			67
Income tax payable			0
Risk management			0
Current portion of long-term debt			0
Total Current Liabilities			55
Operating Lease Liabilities			948
Other Liabilities and Provisions			(1,224)
Total Liabilities			(221)
Retained Earnings			75
Total Shareholders’ Equity			75
Total Liabilities and Shareholders’ Equity			$ (146)

XML

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis

Fair value changes and settlements for amounts related to risk management assets and liabilities are recognized in revenues and foreign exchange gains and losses according to their purpose.

As at September 30, 2019	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	256	$	92	$	348	$	(68	)	$	280
Long-term assets		-		59		22		81		(35	)		46
Foreign Currency Derivatives:
Current assets		-		4		-		4		-			4
Long-term assets		-		1		-		1		-			1
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	78	$	-	$	78	$	(68	)	$	10
Long-term liabilities		-		49		-		49		(35	)		14
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	2	$	-	$	2	$	-		$	2
Long-term in other liabilities and provisions		-		8		-		8		-			8

As at December 31, 2018	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	492	$	139	$	631	$	(77	)	$	554
Long-term assets		-		177		-		177		(16	)		161
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	81	$	-	$	81	$	(77	)	$	4
Long-term liabilities		-		38		-		38		(16	)		22
Foreign Currency Derivatives:
Current liabilities		-		21		-		21		-			21
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	4	$	-	$	4	$	-		$	4
Long-term in other liabilities and provisions		-		10		-		10		-			10

(1) Netting to offset derivative assets and liabilities where the legal right and intention to offset exists, or where counterparty master netting arrangements contain provisions for net settlement.

Summary Of Changes In Level 3 Fair Value Measurements

A summary of changes in Level 3 fair value measurements for the nine months ended September 30 is presented below:

	Risk Management
	2019			2018
Balance, Beginning of Year	$	139		$	(51	)
Total Gains (Losses)		24			(177	)
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances		-			-
Settlements		(49	)		80
Transfers Out of Level 3 (1)		-			-
Balance, End of Period	$	114		$	(148	)
Change in Unrealized Gains (Losses) Related to    Assets and Liabilities Held at End of Period	$	83		$	(136	)

(1) The Company’s policy is to recognize transfers out of Level 3 on the date of the event of change in circumstances that caused the transfer.

Quantitative Information About Unobservable Inputs Used In Level 3

Quantitative information about unobservable inputs used in Level 3 fair value measurements is presented below:

	Valuation Technique	Unobservable Input	As at September 30, 2019	As at December 31, 2018
Risk Management - WTI Options	Option Model	Implied Volatility	22% - 61%	29% - 73%

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Commitments and Contingencies (Details) $ in Millions	Sep. 30, 2019 USD ($)
Long-term Commitment [Line Items]
Building Leases, Future Minimum Payments, Remainder of Fiscal Year	$ 4
Building Leases, Future Minimum Payments, Due in Two Years	15
Building Leases, Future Minimum Payments, Due in Three Years	14
Building Leases, Future Minimum Payments, Due in Four Years	11
Building Leases, Future Minimum Payments, Due in Five Years	7
Building Leases, Future Minimum Payments, Due Thereafter	15
Building Leases, Future Minimum Payments Due	66
Total Commitment, Due Remainder of Fiscal Year	265
Total Commitment, Due in Second Year	770
Total Commitment, Due in Third Year	645
Total Commitment, Due in Fourth Year	605
Total Commitment, Due in Fifth Year	492
Total Commitment, Due Thereafter	2,422
Total Commitment	5,199
Transportation And Processing Commitments [Member]
Long-term Commitment [Line Items]
Purchase Obligation,Remainder of Fiscal Year	197
Purchase Obligation, Due in Second Year	731
Purchase Obligation, Due in Third Year	625
Purchase Obligation, Due in Fourth Year	594
Purchase Obligation, Due in Fifth Year	485
Purchase Obligation, Due Thereafter	2,407
Purchase Obligation	5,039
Drilling And Field Services Commitments [Member]
Long-term Commitment [Line Items]
Purchase Obligation,Remainder of Fiscal Year	64
Purchase Obligation, Due in Second Year	24
Purchase Obligation, Due in Third Year	6
Purchase Obligation, Due in Fourth Year	0
Purchase Obligation, Due in Fifth Year	0
Purchase Obligation, Due Thereafter	0
Purchase Obligation	$ 94

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Acquisitions and Divestitures (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Acquisitions and Divestitures [Line Items]
Acquisitions	$ 25	$ 15	$ 66	$ 17
Divestitures	(171)	(24)	(177)	(89)
Net Acquisitions and Divestitures	(146)	(9)	(111)	(72)
Operating Segments [Member] | Canadian Operations [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	0	15	0	17
Divestitures	0	2	0	(55)
Operating Segments [Member] | USA Operations [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	25	0	66	0
Divestitures	$ (171)	$ (26)	$ (177)	$ (34)

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Long-Term Debt (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term Debt Carrying Value	$ 7,024	$ 4,198
Long-term Debt, Fair Value	7,825	4,511
Outstanding commercial paper	$ 740	$ 0
Commercial Paper [Member]
Debt Instrument [Line Items]
Weighted average interest rate	2.63%
Expiration year	2022

XML

Share Capital (Narrative) (Details) $ / shares in Units, $ in Millions						3 Months Ended		9 Months Ended		12 Months Ended
	Oct. 30, 2019 $ / shares	Aug. 29, 2019 USD ($) $ / shares shares	Jun. 10, 2019 shares	Feb. 27, 2019 shares	Feb. 13, 2019 USD ($)	Sep. 30, 2019 USD ($) $ / shares shares	Sep. 30, 2018 USD ($) $ / shares	Sep. 30, 2019 USD ($) $ / shares shares	Sep. 30, 2018 USD ($) $ / shares shares	Dec. 31, 2018 USD ($) shares
Class Of Stock [Line Items]
Percentage of issued and outstanding shares equal to not more than authorized shares								20.00%
Preferred shares outstanding | shares						0		0
Common Shares Purchased, Shares | shares								196,700,000		20,700,000
Common Shares Purchased, value								$ 1,073.0		$ 102.0
Payments for Repurchase of Common Stock						$ 213.0	$ 50.0	$ 1,250.0	$ 250.0
Common Shares Issued under Dividend Reinvestment Plan, Shares | shares								0		69,329
Common Shares Issued Under Dividend Reinvestment Plan						0.0	0.0	$ 0.0	0.0	$ 0.6
Dividends on Common Shares						$ 24.0	$ 14.0	$ 77.0	$ 43.0
Common Stock, Dividends, Per Share, Paid | $ / shares						$ 0.01875	$ 0.015	$ 0.05625	$ 0.045
Dividends, Common Shares Issued In Lieu of Cash, Value						$ 0.1		$ 0.5
Common Stock, Dividends, Per Share, Declared | $ / shares						$ 0.01875	$ 0.015	$ 0.05625	$ 0.045
Subsequent Event [Member]
Class Of Stock [Line Items]
Dividends Payable, Date Declared	Oct. 30, 2019
Common Stock, Dividends, Per Share, Declared | $ / shares	$ 0.01875
Dividends Payable, Date to be Paid	Dec. 31, 2019
Dividends Payable, Date of Record	Dec. 13, 2019
Share Capital [Member]
Class Of Stock [Line Items]
Common Shares Issued Under Dividend Reinvestment Plan							$ 0.0		$ 0.0
Dividends on Common Shares						$ 0.0		$ 0.0
Retained Earnings (Accumulated Deficit) [Member]
Class Of Stock [Line Items]
Dividends on Common Shares						24.0	14.0	77.0	$ 43.0
Substantial Issuer Bid [Member]
Class Of Stock [Line Items]
Stock Repurchase Program, Number of Shares Authorized to be Repurchased | shares			213,000,000
Stock Repurchase Program Expiration Date			Aug. 29, 2019
Common Shares Purchased, Shares | shares		47,300,000
Common stock purchase price | $ / shares		$ 4.50
Common Shares Purchased, value		$ 213.0				213.0		213.0
Substantial Issuer Bid [Member] | Share Capital [Member]
Class Of Stock [Line Items]
Common Shares Purchased, value		257.0				257.0		257.0
Substantial Issuer Bid [Member] | Paid In Surplus [Member]
Class Of Stock [Line Items]
Common Shares Purchased, value		$ (44.0)				$ (44.0)		$ (44.0)
Normal Course Issuer Bid [Member]
Class Of Stock [Line Items]
Stock Repurchase Program, Number of Shares Authorized to be Repurchased | shares				149,400,000
Stock Repurchase Program Expiration Date				Mar. 03, 2020
Common Shares Purchased, Shares | shares								149,400,000	20,700,000	20,700,000
Common Shares Purchased, value							50.0	$ 1,037.0	$ 250.0
Payments for Repurchase of Common Stock								1,037.0	250.0	$ 250.0
Normal Course Issuer Bid [Member] | Share Capital [Member]
Class Of Stock [Line Items]
Common Shares Purchased, value							19.0	816.0	102.0	102.0
Normal Course Issuer Bid [Member] | Retained Earnings (Accumulated Deficit) [Member]
Class Of Stock [Line Items]
Common Shares Purchased, value							$ 31.0	$ 221.0	$ 148.0	$ 148.0
Newfield Exploration Company [Member]
Class Of Stock [Line Items]
Stock Issued During Period, Value, Acquisitions					$ 543.4
Business Acquisition Stock Exchange Ratio					2.6719

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Leases (Narrative) (Details)	Sep. 30, 2019
Maximum [Member]
Lessee Lease Description [Line Items]
Option to extend lease, term	10 years

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Leases (Schedule of Future Lease Payments and Lease Liabilities Related to Operating and Finance Leases) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($)
Operating Leases
Expected Future Operating Lease Payments 2019	$ 37
Expected Future Operating Lease Payments 2020	128
Expected Future Operating Lease Payments 2021	112
Expected Future Operating Lease Payments 2022	97
Expected Future Operating Lease Payments 2023	85
Expected Future Operating Lease Payments thereafter	1,165
Expected Future Operating Lease Payments,Total	1,624
Less: Discounting	573
Present Value of Future Operating Lease Payments Total	1,051
Sublease Income (undiscounted) 2019	(10)
Sublease Income (undiscounted) 2020	(41)
Sublease Income (undiscounted) 2021	(42)
Sublease Income (undiscounted) 2022	(37)
Sublease Income (undiscounted) 2023	(37)
Sublease Income (undiscounted) Thereafter	(566)
Sublease Income (undiscounted) Total	(733)
Finance Leases
Expected Future Finance Lease Payments, 2019	25
Expected Future Finance Lease Payments, 2020	99
Expected Future Finance Lease Payments, 2021	87
Expected Future Finance Lease Payments, 2022	8
Expected Future Finance Lease Payments, 2023	8
Expected Future Finance Lease Payments, Thereafter	30
Expected Future Finance Lease Payments, Total	257
Less: Discounting	25
Present Value of Future Finance Lease Payments Total	232
Sublease Income (undiscounted) 2019	(2)
Sublease Income (undiscounted) 2020	(8)
Sublease Income (undiscounted) 2021	(8)
Sublease Income (undiscounted) 2022	(8)
Sublease Income (undiscounted) 2023	(7)
Sublease Income (undiscounted) Thereafter	(24)
Sublease Income (undiscounted) Total	$ (57)

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Variable Interest Entities (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($) MMcf	Jan. 01, 2019 USD ($)	Dec. 31, 2018 USD ($)
Variable Interest Entity [Line Items]
Accounts Payable and Accrued Liabilities, Current	$ 2,191	$ 1,478	$ 1,490
Veresen Midstream Limited Partnership [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity, Financial Support, Term of Assessment	8 years
Variable Interest Entity, Reporting Entity Involvement, Maximum Loss Exposure, Amount	$ 2,359
Veresen Midstream Limited Partnership [Member] | Take or Pay Commitment [Member]
Variable Interest Entity [Line Items]
Accounts Payable and Accrued Liabilities, Current	$ 0
Veresen Midstream Limited Partnership [Member] | Natural gas gathering and compression [Member]
Variable Interest Entity [Line Items]
Contracted Capacity Volumes | MMcf	1,206
Veresen Midstream Limited Partnership [Member] | Natural gas processing [Member]
Variable Interest Entity [Line Items]
Contracted Capacity Volumes | MMcf	939
Veresen Midstream Limited Partnership [Member] | Minimum [Member]
Variable Interest Entity [Line Items]
Length of Remaining Terms, In Years	12 years
Veresen Midstream Limited Partnership [Member] | Maximum [Member]
Variable Interest Entity [Line Items]
Length of Remaining Terms, In Years	26 years
Length of Renewal Term, in Years	10 years

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Property, Plant And Equipment, Net

9 Months Ended

Sep. 30, 2019

Property Plant And Equipment [Abstract]

Property, Plant And Equipment, Net

10. Property, Plant and Equipment, Net

	As at September 30, 2019							As at December 31, 2018
			Accumulated							Accumulated
	Cost		DD&A			Net		Cost		DD&A			Net
Canadian Operations
Proved properties	$	14,817	$	(13,949	)	$	868	$	13,996	$	(13,261	)	$	735
Unproved properties		223		-			223		237		-			237
Other		20		-			20		27		-			27
		15,060		(13,949	)		1,111		14,260		(13,261	)		999
USA Operations
Proved properties		35,223		(25,186	)		10,037		27,189		(24,099	)		3,090
Unproved properties		3,720		-			3,720		3,493		-			3,493
Other		25		-			25		8		-			8
		38,968		(25,186	)		13,782		30,690		(24,099	)		6,591
Market Optimization		8		(6	)		2		7		(6	)		1
Corporate & Other		893		(662	)		231		2,136		(755	)		1,381
	$	54,929	$	(39,803	)	$	15,126	$	47,093	$	(38,121	)	$	8,972

Canadian and USA Operations property, plant and equipment include internal costs directly related to exploration, development and construction activities of $171 million, which have been capitalized during the nine months ended September 30, 2019 (2018 - $159 million).

Finance Lease Arrangements

The Company has two lease arrangements that are accounted for as finance leases, which include an office building and an offshore production platform. As at September 30, 2019, the total carrying value of assets under finance lease was $39 million ($41 million as at December 31, 2018), net of accumulated amortization of $667 million ($650 million as at December 31, 2018). Long-term liabilities for the finance lease arrangements are included in other liabilities and provisions in the Condensed Consolidated Balance Sheet and are disclosed in Note 13.

Other Arrangement

As at December 31, 2018, Corporate and Other property, plant and equipment and total assets included a carrying value of $1,133 million related to The Bow office building. Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease as discussed in Note 2. As at September 30, 2019, other assets included a ROU asset of $896 million related to The Bow office building.

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Foreign Exchange (Gain) Loss, Net

9 Months Ended

Sep. 30, 2019

Foreign Currency [Abstract]

Foreign Exchange (Gain) Loss, Net

6. Foreign Exchange (Gain) Loss, Net

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	68		$	(74	)	$	(117	)	$	138
Translation of U.S. dollar risk management contracts issued from Canada		5			(3	)		(13	)		7
Translation of intercompany notes		(24	)		54			119			11
		49			(23	)		(11	)		156
Foreign Exchange on Settlements of:
U.S. dollar financing debt issued from Canada		(10	)		-			(22	)		1
U.S. dollar risk management contracts issued from Canada		(2	)		(1	)		(1	)		(11	)
Intercompany notes		(8	)		(1	)		(31	)		(48	)
Other Monetary Revaluations		1			2			3			(5	)
	$	30		$	(23	)	$	(62	)	$	93

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Recent Accounting Pronouncements

9 Months Ended

Sep. 30, 2019

New Accounting Pronouncements And Changes In Accounting Principles [Abstract]

Recent Accounting Pronouncements

2. Recent Accounting Pronouncements

Changes in Accounting Policies and Practices

On January 1, 2019, Encana adopted ASC Topic 842, Leases (“Topic 842”) and related amendments, using the modified retrospective approach recognizing a cumulative effect adjustment at the beginning of the reporting period in which Topic 842 was applied. Results for reporting the periods beginning after January 1, 2019, are presented in accordance with Topic 842, while prior periods have not been restated and are reported in accordance with ASC Topic 840, Leases (“Topic 840”). On transition, Encana elected certain practical expedients permitted under Topic 842 which include:

• No reassessment of the classification of leases previously assessed under Topic 840, whether expired or existing contracts contain leases, or initial direct costs of existing leases; and

• Application of Topic 842 prospectively to all new or modified land easements after January 1, 2019.

Encana also elected the short-term lease exemption, which does not require a right-of-use (“ROU”) asset or lease liability to be recognized on the Consolidated Balance Sheet when the lease term is 12 months or less. The policy and disclosures required under Topic 842 are included in Note 11, Leases.  

In accordance with Topic 842, Encana recognized a ROU asset and corresponding lease liability for all operating leases on the Consolidated Balance Sheet, other than leases with lease terms of 12 months or less. Prior to the adoption of Topic 842, operating leases were not recognized on the Consolidated Balance Sheet. There was no impact to finance leases on transition to Topic 842. The impact from recognizing operating leases on Encana’s Condensed Consolidated Balance Sheet is as follows:

										Restated
	Reported as at			Impact of						Balances as at
(US$ millions)	December 31, 2018			Adoption						January 1, 2019
Property, Plant and Equipment, at cost:
Oil and natural gas properties, based on full cost accounting
Proved properties	$	41,241		$	-					$	41,241
Unproved properties		3,730			-						3,730
Other		2,122			(1,261	)					861
Property, plant and equipment		47,093			(1,261	)					45,832
Less: accumulated depreciation, depletion and amortization		(38,121	)		128						(37,993	)
Property, plant and equipment, net		8,972			(1,133	)		(1	)		7,839
Other Assets		147			1,015		(1), (2		)		1,162
Deferred Income Taxes		835			(28	)					807
Total Assets		15,344			(146	)					15,198
Current Liabilities
Accounts payable and accrued liabilities		1,490			(12	)		(1	)		1,478
Current portion of operating lease liabilities		-			67			(2	)		67
Income tax payable		1			-						1
Risk management		25			-						25
Current portion of long-term debt		500			-						500
		2,016			55						2,071
Operating Lease Liabilities		-			948			(2	)		948
Other Liabilities and Provisions		1,769			(1,224	)		(1	)		545
Total Liabilities		7,897			(221	)					7,676
Retained Earnings		435			75			(1	)		510
Total Shareholders’ Equity		7,447			75						7,522
Total Liabilities and Shareholders’ Equity	$	15,344		$	(146	)				$	15,198

(1) In accordance with Topic 840, Encana accounted for The Bow office building as a failed sales leaseback and at the effective date of January 1, 2019, The Bow office building remained as such. On transition to Topic 842, Encana re-assessed whether a sale would have occurred at the effective date and determined that a sale occurred. As a result, Encana derecognized the asset and financing liability resulting from the failed sale leaseback transaction measured under Topic 840, recognizing the difference as an adjustment to retained earnings in the Condensed Consolidated Balance Sheet. Upon transition to Topic 842, The Bow office building was determined to be an operating lease for which a ROU asset and corresponding liability was recorded at the present value of remaining minimum lease payments.

(2) ROU assets for operating leases were measured at the amount equal to the lease liability and the unamortized balance of any lease incentives prior to the transition date. The lease liabilities for operating leases were measured at the present value of the remaining minimum lease payments outstanding as at January 1, 2019.

Although Topic 842 did not have a material impact on the Condensed Consolidated Statements of Earnings or Cash Flows, the change in the accounting of The Bow office building resulted in: i) operating lease expense under Topic 842 reported in administrative expense, whereas for the comparative periods presented under Topic 840, Encana recorded depreciation and interest expense in the Condensed Consolidated Statement of Earnings; and ii) cash outflows presented in cash used in operating activities under Topic 842, whereas for the comparative periods presented under Topic 840, interest and financing cash outflows are presented in cash used in operating activities and cash used in financing activities, respectively, in the Condensed Consolidated Statement of Cash Flows.        

On January 1, 2019, Encana adopted ASU 2018-02 “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”. The amendments allow for a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act (“U.S. Tax Reform”). While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact was not material to the

Company’s Consolidated Financial Statements. As a result, the Company did not take the election provided in the amendment.

New Standards Issued Not Yet Adopted

As of January 1, 2020, Encana will be required to adopt ASU 2017-04, “Simplifying the Test for Goodwill Impairment”. The amendment eliminates the second step of the goodwill impairment test which requires the Company to measure the impairment based on the excess amount of the carrying value of the reporting unit’s goodwill over the implied fair value of its goodwill. Under this amendment, the goodwill impairment will be measured based on the excess amount of the reporting unit’s carrying value over its respective fair value. The amendment will be applied prospectively at the date of adoption. Encana does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

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Basis of Presentation and Principles of Consolidation (Policies)

9 Months Ended

Sep. 30, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Basis of Presentation and Principles of Consolidation

Encana is in the business of the exploration for, the development of, and the production and marketing of oil, NGLs and natural gas.

The interim Condensed Consolidated Financial Statements include the accounts of Encana and entities in which it holds a controlling interest. All intercompany balances and transactions are eliminated on consolidation. Undivided interests in oil and natural gas exploration and production joint ventures and partnerships are consolidated on a proportionate basis. Investments in non-controlled entities over which Encana has the ability to exercise significant influence are accounted for using the equity method.  

The interim Condensed Consolidated Financial Statements are prepared in conformity with U.S. GAAP and the rules and regulations of the SEC. Pursuant to these rules and regulations, certain information and disclosures normally required under U.S. GAAP have been condensed or have been disclosed on an annual basis only. Accordingly, the interim Condensed Consolidated Financial Statements should be read in conjunction with the annual audited Consolidated Financial Statements and the notes thereto for the year ended December 31, 2018, which are included in Item 8 of Encana’s 2018 Annual Report on Form 10-K.

The interim Condensed Consolidated Financial Statements have been prepared following the same accounting policies and methods of computation as the annual audited Consolidated Financial Statements for the year ended December 31, 2018, except as noted below in Note 2. The disclosures provided below are incremental to those included with the annual audited Consolidated Financial Statements.

These unaudited interim Condensed Consolidated Financial Statements reflect, in the opinion of Management, all normal and recurring adjustments necessary to present fairly the financial position and results of the Company as at and for the periods presented. Interim condensed consolidated financial results are not necessarily indicative of consolidated financial results expected for the fiscal year.

Recent Accounting Pronouncements

Changes in Accounting Policies and Practices

On January 1, 2019, Encana adopted ASC Topic 842, Leases (“Topic 842”) and related amendments, using the modified retrospective approach recognizing a cumulative effect adjustment at the beginning of the reporting period in which Topic 842 was applied. Results for reporting the periods beginning after January 1, 2019, are presented in accordance with Topic 842, while prior periods have not been restated and are reported in accordance with ASC Topic 840, Leases (“Topic 840”). On transition, Encana elected certain practical expedients permitted under Topic 842 which include:

• No reassessment of the classification of leases previously assessed under Topic 840, whether expired or existing contracts contain leases, or initial direct costs of existing leases; and

• Application of Topic 842 prospectively to all new or modified land easements after January 1, 2019.

Encana also elected the short-term lease exemption, which does not require a right-of-use (“ROU”) asset or lease liability to be recognized on the Consolidated Balance Sheet when the lease term is 12 months or less. The policy and disclosures required under Topic 842 are included in Note 11, Leases.  

In accordance with Topic 842, Encana recognized a ROU asset and corresponding lease liability for all operating leases on the Consolidated Balance Sheet, other than leases with lease terms of 12 months or less. Prior to the adoption of Topic 842, operating leases were not recognized on the Consolidated Balance Sheet. There was no impact to finance leases on transition to Topic 842. The impact from recognizing operating leases on Encana’s Condensed Consolidated Balance Sheet is as follows:

										Restated
	Reported as at			Impact of						Balances as at
(US$ millions)	December 31, 2018			Adoption						January 1, 2019
Property, Plant and Equipment, at cost:
Oil and natural gas properties, based on full cost accounting
Proved properties	$	41,241		$	-					$	41,241
Unproved properties		3,730			-						3,730
Other		2,122			(1,261	)					861
Property, plant and equipment		47,093			(1,261	)					45,832
Less: accumulated depreciation, depletion and amortization		(38,121	)		128						(37,993	)
Property, plant and equipment, net		8,972			(1,133	)		(1	)		7,839
Other Assets		147			1,015		(1), (2		)		1,162
Deferred Income Taxes		835			(28	)					807
Total Assets		15,344			(146	)					15,198
Current Liabilities
Accounts payable and accrued liabilities		1,490			(12	)		(1	)		1,478
Current portion of operating lease liabilities		-			67			(2	)		67
Income tax payable		1			-						1
Risk management		25			-						25
Current portion of long-term debt		500			-						500
		2,016			55						2,071
Operating Lease Liabilities		-			948			(2	)		948
Other Liabilities and Provisions		1,769			(1,224	)		(1	)		545
Total Liabilities		7,897			(221	)					7,676
Retained Earnings		435			75			(1	)		510
Total Shareholders’ Equity		7,447			75						7,522
Total Liabilities and Shareholders’ Equity	$	15,344		$	(146	)				$	15,198

(1) In accordance with Topic 840, Encana accounted for The Bow office building as a failed sales leaseback and at the effective date of January 1, 2019, The Bow office building remained as such. On transition to Topic 842, Encana re-assessed whether a sale would have occurred at the effective date and determined that a sale occurred. As a result, Encana derecognized the asset and financing liability resulting from the failed sale leaseback transaction measured under Topic 840, recognizing the difference as an adjustment to retained earnings in the Condensed Consolidated Balance Sheet. Upon transition to Topic 842, The Bow office building was determined to be an operating lease for which a ROU asset and corresponding liability was recorded at the present value of remaining minimum lease payments.

(2) ROU assets for operating leases were measured at the amount equal to the lease liability and the unamortized balance of any lease incentives prior to the transition date. The lease liabilities for operating leases were measured at the present value of the remaining minimum lease payments outstanding as at January 1, 2019.

Although Topic 842 did not have a material impact on the Condensed Consolidated Statements of Earnings or Cash Flows, the change in the accounting of The Bow office building resulted in: i) operating lease expense under Topic 842 reported in administrative expense, whereas for the comparative periods presented under Topic 840, Encana recorded depreciation and interest expense in the Condensed Consolidated Statement of Earnings; and ii) cash outflows presented in cash used in operating activities under Topic 842, whereas for the comparative periods presented under Topic 840, interest and financing cash outflows are presented in cash used in operating activities and cash used in financing activities, respectively, in the Condensed Consolidated Statement of Cash Flows.        

On January 1, 2019, Encana adopted ASU 2018-02 “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”. The amendments allow for a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act (“U.S. Tax Reform”). While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact was not material to the

Company’s Consolidated Financial Statements. As a result, the Company did not take the election provided in the amendment.

New Standards Issued Not Yet Adopted

As of January 1, 2020, Encana will be required to adopt ASU 2017-04, “Simplifying the Test for Goodwill Impairment”. The amendment eliminates the second step of the goodwill impairment test which requires the Company to measure the impairment based on the excess amount of the carrying value of the reporting unit’s goodwill over the implied fair value of its goodwill. Under this amendment, the goodwill impairment will be measured based on the excess amount of the reporting unit’s carrying value over its respective fair value. The amendment will be applied prospectively at the date of adoption. Encana does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

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Interest (Tables)

9 Months Ended

Sep. 30, 2019

Interest Expense [Abstract]

Schedule of Interest Expense

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Interest Expense on:
Debt	$	93	$	67	$	268	$	200
The Bow office building (See Note 2)		-		16		-		48
Finance leases (See Note 11)		3		3		10		12
Other		3		6		7		5
	$	99	$	92	$	285	$	265

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Commitments and Contingencies (Narrative) (Details) $ in Millions	Mar. 29, 2019 USD ($)
Newfield Exploration Company [Member]
Long-term Commitment [Line Items]
Litigation settlement paid to Sapura	$ 22.5

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Segmented Information (Segment and Geographical Information) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended		12 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Product and service revenues		$ 1,771	$ 1,488	$ 5,191	$ 4,025
Gains (losses) on risk management, net		81	(241)	(84)	(517)
Sublease revenues		19	15	54	50
Total Revenues		1,871	1,262	5,161	3,558
Production, mineral and other taxes		66	45	187	109
Transportation and processing		398	278	1,148	799
Operating		193	124	545	372
Purchased product		264	282	784	803
Depreciation, depletion and amortization		545	349	1,454	924
Accretion of asset retirement obligation		9	8	28	24	$ 32
Administrative		81	57	389	187
Total Operating Expenses		1,556	1,143	4,535	3,218
Operating Income (Loss)		315	119	626	340
Interest		99	92	285	265
Foreign exchange (gain) loss, net		30	(23)	(62)	93
(Gain) loss on divestitures, net		(5)	0	(4)	(4)
Other (gains) losses, net		(1)	5	24	2
Total Other (Income) Expenses		123	74	243	356
Net Earnings (Loss) Before Income Tax		192	45	383	(16)
Income tax expense (recovery)		43	6	143	(55)
Net Earnings (Loss)		149	39	240	39
Corporate & Other [Member]
Segment Reporting Information [Line Items]
Product and service revenues		0	0	0	0
Gains (losses) on risk management, net		(41)	(164)	(385)	(422)
Sublease revenues		19	15	54	50
Total Revenues		(22)	(149)	(331)	(372)
Production, mineral and other taxes		0	0	0	0
Transportation and processing		0	0	0	0
Operating		0	2	(2)	11
Purchased product		0	0	0	0
Depreciation, depletion and amortization		7	13	26	38
Accretion of asset retirement obligation		9	8	28	24
Administrative		81	57	389	187
Total Operating Expenses		97	80	441	260
Operating Income (Loss)		(119)	(229)	(772)	(632)
Canadian Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and service revenues		377	453	1,222	1,236
Gains (losses) on risk management, net		87	8	174	93
Sublease revenues		0	0	0	0
Total Revenues		464	461	1,396	1,329
Production, mineral and other taxes		3	4	11	12
Transportation and processing		211	211	640	608
Operating		32	34	96	98
Depreciation, depletion and amortization		100	95	287	257
Total Operating Expenses		346	344	1,034	975
Operating Income (Loss)		118	117	362	354
USA Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and service revenues		1,097	718	3,062	1,880
Gains (losses) on risk management, net		35	(84)	128	(185)
Sublease revenues		0	0	0	0
Total Revenues		1,132	634	3,190	1,695
Production, mineral and other taxes		63	41	176	97
Transportation and processing		125	34	340	92
Operating		151	80	414	238
Depreciation, depletion and amortization		438	241	1,141	628
Total Operating Expenses		777	396	2,071	1,055
Operating Income (Loss)		355	238	1,119	640
China Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and service revenues	[1]	3	0	37	0
Gains (losses) on risk management, net	[1]	0	0	0	0
Sublease revenues	[1]	0	0	0	0
Total Revenues	[1]	3	0	37	0
Production, mineral and other taxes	[1]	0	0	0	0
Transportation and processing	[1]	0	0	0	0
Operating	[1]	4	0	16	0
Depreciation, depletion and amortization	[1]	0	0	0	0
Total Operating Expenses	[1]	4	0	16	0
Operating Income (Loss)	[1]	(1)	0	21	0
Market Optimization [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and service revenues		294	317	870	909
Gains (losses) on risk management, net		0	(1)	(1)	(3)
Sublease revenues		0	0	0	0
Total Revenues		294	316	869	906
Production, mineral and other taxes		0	0	0	0
Transportation and processing		62	33	168	99
Operating		6	8	21	25
Purchased product		264	282	784	803
Depreciation, depletion and amortization		0	0	0	1
Accretion of asset retirement obligation		0	0	0	0
Administrative		0	0	0	0
Total Operating Expenses		332	323	973	928
Operating Income (Loss)		$ (38)	$ (7)	$ (104)	$ (22)

[1] The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

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Financial Instruments and Risk Management (Tables)

9 Months Ended

Sep. 30, 2019

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Risk Management Positions

	Notional Volumes	Term	Average Price		Fair Value
Crude Oil and NGL Contracts			US$/bbl
Fixed Price Contracts
WTI Fixed Price	45.0 Mbbls/d	2019		60.24	$	26
WTI Fixed Price	24.0 Mbbls/d	2020		60.05		74
Propane Fixed Price	3.8 Mbbls/d	2019		35.72		11
Propane Fixed Price	1.8 Mbbls/d	2020		21.00		1
Butane Fixed Price	6.5 Mbbls/d	2019		40.54		10
Ethane Fixed Price	5.3 Mbbls/d	2019		17.23		5
WTI Fixed Price Swaptions (1)	4.0 Mbbls/d	2021		58.00		(4	)
WTI Three-Way Options
Sold call / bought put / sold put	87.5 Mbbls/d	2019	67.72 / 56.47 / 45.86			27
Sold call / bought put / sold put	80.0 Mbbls/d	2020	61.68 / 53.44 / 43.44			54
WTI Costless Collars
Sold call / bought put	43.0 Mbbls/d	2019	65.57 / 56.28			13
Sold call / bought put	15.0 Mbbls/d	2020	68.71 / 50.00			20
Basis Contracts (2)		2019				(19	)
		2020				(34	)
Crude Oil and NGLs Fair Value Position						184
Natural Gas Contracts			US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	687 MMcf/d	2019		2.72		19
NYMEX Fixed Price	653 MMcf/d	2020		2.69		64
NYMEX Fixed Price Swaptions (3)	180 MMcf/d	2021		2.61		(9	)
NYMEX Three-Way Options
Sold call / bought put / sold put	330 MMcf/d	2020	2.72 / 2.60 / 2.25			7
NYMEX Costless Collars
Sold call / bought put	177 MMcf/d	2019	3.05 / 2.89			8
Sold call / bought put	55 MMcf/d	2020	2.88 / 2.50			4
NYMEX Call Options
Sold call	230 MMcf/d	2019		3.75		-
Bought call	230 MMcf/d	2019		3.75		(1	)
Sold call	230 MMcf/d	2020		3.25		4
Basis Contracts (4)		2019				10
		2020				30
		2021				(2	)
		2022 - 2025				(8	)
Other Financial Positions						(1	)
Natural Gas Fair Value Position						125
Net Premiums Received on Unexpired Options						(7	)
Other Derivative Contracts
Fair Value Position						(10	)
Foreign Currency Contracts
Fair Value Position (5)		2019 - 2020				5
Total Fair Value Position and Net Premiums Received					$	297

(1) WTI Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(2) Encana has entered into crude and NGL differential swaps associated with Midland, Magellan East Houston, Belvieu, Conway, Brent, Louisiana Light Sweet and WTI.

(3) NYMEX Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(4) Encana has entered into natural gas basis swaps associated with AECO, Dawn, Chicago, Malin, Waha, Houston Ship Channel and NYMEX.

(5) Encana has entered into U.S. dollar denominated fixed-for-floating average currency swaps to protect against fluctuations between the Canadian and U.S. dollars.

Earnings Impact of Realized and Unrealized Gains (Losses) On Risk Management Positions

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	122		$	(77	)	$	301		$	(95	)
Foreign Currency Derivatives:
Foreign exchange		2			1			1			11
	$	124		$	(76	)	$	302		$	(84	)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	(41	)	$	(164	)	$	(385	)	$	(422	)
Foreign Currency Derivatives:
Foreign exchange		(11	)		9			26			(17	)
	$	(52	)	$	(155	)	$	(359	)	$	(439	)
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	81		$	(241	)	$	(84	)	$	(517	)
Foreign Currency Derivatives:
Foreign exchange		(9	)		10			27			(6	)
	$	72		$	(231	)	$	(57	)	$	(523	)

(1) Includes realized gains of $2 million and $5 million for the three and nine months ended September 30, 2019, respectively, (2018 - gains of $2 million and $5 million, respectively) related to other derivative contracts.

(2) Includes unrealized losses of nil and $1 million for the three and nine months ended September 30, 2019, respectively, (2018 - losses of nil and $1 million, respectively) related to other derivative contracts.

Reconciliation of Unrealized Risk Management Positions

	2019						2018
	Fair Value			Total Unrealized Gain (Loss)			Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	654
Change in Fair Value of Contracts in Place at Beginning of Year    and Contracts Entered into During the Period		(57	)	$	(57	)	$	(523	)
Settlement of Other Derivative Contracts		5
Amortization of Option Premiums During the Period		(3	)
Fair Value of Contracts Realized During the Period		(302	)		(302	)		84
Fair Value of Contracts and Net Premiums Received, End of Period	$	297		$	(359	)	$	(439	)

Unrealized Risk Management Positions

	As at		As at
	September 30,		December 31,
	2019		2018
Risk Management Assets
Current	$	284	$	554
Long-term		47		161
		331		715
Risk Management Liabilities
Current		10		25
Long-term		14		22
		24		47
Other Derivative Contracts
Current in accounts payable and accrued liabilities		2		4
Long-term in other liabilities and provisions		8		10
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	297	$	654

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Leases (Schedule of Operating Lease Expense) (Parenthetical) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Operating Lease Expense [Line Items]
Total Operating Lease Expense	$ 59	$ 164
Administrative [Member]
Operating Lease Expense [Line Items]
Total Operating Lease Expense	30	86
Administrative [Member] | Bow Office Building [Member]
Operating Lease Expense [Line Items]
Total Operating Lease Expense	$ 23	$ 69

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Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Accumulated Other Comprehensive Income Loss Net Of Tax [Abstract]
Balance, Beginning of Period	$ 1,014	$ 1,028	$ 976	$ 1,029
Change in Foreign Currency Translation Adjustment	(6)	22	32	21
Balance, End of Period	1,008	1,050	1,008	1,050
Balance, Beginning of Period	(2)	12	22	13
Plan Amendment	0	0	(29)	0
Income Taxes	0	0	6	0
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings	0	0	(1)	(1)
Income Taxes	0	0	0	0
Balance, End of Period	(2)	12	(2)	12
Total Accumulated Other Comprehensive Income	$ 1,006	$ 1,062	$ 1,006	$ 1,062	$ 998

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Business Combination - Schedule of Unaudited Pro Forma Financial Information (Details) - Newfield Exploration Company [Member] - USD ($) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Business Acquisition [Line Items]
Revenues	$ 5,440	$ 5,215
Net Earnings (Loss)	$ 376	$ 369
Net Earnings (Loss) per Common Share
Basic & Diluted	$ 0.29	$ 0.25

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Long-Term Debt (Schedule Of Long-Term Debt) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018	Jan. 01, 2019
Debt Instrument [Line Items]
Revolving credit and term loan borrowings	$ 740	$ 0
Total Principal	6,901	4,211
Increase in Value of Debt Acquired	157	22
Unamortized Debt Discounts and Issuance Costs	(34)	(35)
Total Long-Term Debt	7,024	4,198
Current Portion	0	500	$ 500
Long-Term Debt	7,024	3,698
6.50% Unsecured Notes [Member] | Unsecured Notes, Due May 15, 2019 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 0	$ 500
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Debt Instrument, Maturity Date	May 15, 2019	May 15, 2019
6.50% Unsecured Notes [Member] | Unsecured Notes, Due August 15, 2034 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 750	$ 750
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Debt Instrument, Maturity Date	Aug. 15, 2034	Aug. 15, 2034
6.50% Unsecured Notes [Member] | Unsecured Notes, Due February 1, 2038 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 505	$ 505
Debt Instrument, Interest Rate, Stated Percentage	6.50%	6.50%
Debt Instrument, Maturity Date	Feb. 01, 2038	Feb. 01, 2038
3.90% Unsecured Notes [Member] | Unsecured Notes, Due November 15, 2021 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 600	$ 600
Debt Instrument, Interest Rate, Stated Percentage	3.90%	3.90%
Debt Instrument, Maturity Date	Nov. 15, 2021	Nov. 15, 2021
5.75% Unsecured Notes [Member] | Unsecured Notes, Due January 30, 2022 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 750	$ 0
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Debt Instrument, Maturity Date	Jan. 30, 2022
5.625% Unsecured Notes [Member] | Unsecured Notes, Due July 1, 2024 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 1,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Debt Instrument, Maturity Date	Jul. 01, 2024
5.375% Unsecured Notes [Member] | Unsecured Notes, Due Jan 1, 2026 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 700	0
Debt Instrument, Interest Rate, Stated Percentage	5.375%
Debt Instrument, Maturity Date	Jan. 01, 2026
8.125% Unsecured Notes [Member] | Unsecured Notes, Due September 15, 2030 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 300	$ 300
Debt Instrument, Interest Rate, Stated Percentage	8.125%	8.125%
Debt Instrument, Maturity Date	Sep. 15, 2030	Sep. 15, 2030
7.20% Unsecured Notes [Member] | Unsecured Notes, Due November 1, 2031 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 350	$ 350
Debt Instrument, Interest Rate, Stated Percentage	7.20%	7.20%
Debt Instrument, Maturity Date	Nov. 01, 2031	Nov. 01, 2031
7.375% Unsecured Notes [Member] | Unsecured Notes, Due November 1, 2031 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 500	$ 500
Debt Instrument, Interest Rate, Stated Percentage	7.375%	7.375%
Debt Instrument, Maturity Date	Nov. 01, 2031	Nov. 01, 2031
6.625% Unsecured Notes [Member] | Unsecured Notes, Due August 15, 2037 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 462	$ 462
Debt Instrument, Interest Rate, Stated Percentage	6.625%	6.625%
Debt Instrument, Maturity Date	Aug. 15, 2037	Aug. 15, 2037
5.15% Unsecured Notes [Member] | Unsecured Notes, Due November 15, 2041 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 244	$ 244
Debt Instrument, Interest Rate, Stated Percentage	5.15%	5.15%
Debt Instrument, Maturity Date	Nov. 15, 2041	Nov. 15, 2041

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Asset Retirement Obligation (Schedule Of Asset Retirement Obligation) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Current Portion	$ 176	$ 90
Long-Term Portion	414	365
Asset Retirement Obligation, Total	$ 590	$ 455	$ 514

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Property, Plant And Equipment, Net (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($) Lease	Sep. 30, 2018 USD ($)	Jan. 01, 2019 USD ($)	Dec. 31, 2018 USD ($)
Property, Plant and Equipment [Line Items]
Internal Costs Capitalized	$ 171	$ 159
Property, Plant and Equipment, Net	15,126		$ 7,839	$ 8,972
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	$ 39,803		$ 37,993	38,121
Number of finance lease arrangements | Lease	2
ROU assets	$ 1,045
Assets Held under Capital Leases [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net	39			41
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	667			650
Bow Office Building [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net				$ 1,133
ROU assets	$ 896

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Income Taxes

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Income Taxes

7. Income Taxes

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Current Tax
Canada	$	(2	)	$	-		$	-		$	(66	)
United States		1			-			3			2
Other Countries		-			-			-			3
Total Current Tax Expense (Recovery)		(1	)		-			3			(61	)
Deferred Tax
Canada		(12	)		19			22			(9	)
United States		56			(3	)		117			4
Other Countries		-			(10	)		1			11
Total Deferred Tax Expense (Recovery)		44			6			140			6
Income Tax Expense (Recovery)	$	43		$	6		$	143		$	(55	)
Effective Tax Rate		22.4	%		13.3	%		37.3	%		343.8	%

Encana’s interim income tax expense is determined using the estimated annual effective income tax rate applied to year-to-date net earnings before income tax plus the effect of legislative changes and amounts in respect of prior periods. The estimated annual effective income tax rate is impacted by expected annual earnings, income tax related to foreign operations, the effect of legislative changes, non-taxable capital gains and losses, tax differences on divestitures and transactions, and partnership tax allocations in excess of funding.

On June 28, 2019, Alberta Bill 3, the Job Creation Tax Cut (Alberta Corporate Tax Amendment) Act, was signed into law resulting in a reduction of the Alberta corporate tax rate from 12 percent to 11 percent effective July 1, 2019, with further one percent rate reductions to take effect every year on January 1 until the general corporate tax rate is eight percent on January 1, 2022. During the nine months ended September 30, 2019, the deferred tax expense of $140 million includes an adjustment of $55 million resulting from the re-measurement of the Company’s deferred tax position due to the Alberta tax rate reduction.

During the nine months ended September 30, 2018, the current income tax recovery was primarily due to the resolution of certain tax items relating to prior taxation years. During the three and nine months ended September 30, 2019, the deferred tax expense was primarily due to net earnings before income tax in the respective periods and the impact of the Alberta tax rate reduction discussed above. During the three months ended September 30, 2018, the deferred tax expense was primarily due to the changes in the estimated annual effective income tax rate.

The effective tax rate of 37.3 percent for the nine months ended September 30, 2019 is higher than the Canadian statutory tax rate of 26.6 percent primarily due to the re-measurement of the Company’s deferred tax position resulting from the Alberta tax rate reduction discussed above, partially offset by partnership tax allocations in excess of funding. The effective tax rate of 343.8 percent for the nine months ended September 30, 2018, was higher than the Canadian statutory tax rate of 27 percent primarily due to the resolution of certain tax items relating to prior taxation years.

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Segmented Information

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

Segmented Information

3. Segmented Information

Encana’s reportable segments are determined based on the Company’s operations and geographic locations as follows:

• Canadian Operations includes the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the Canadian cost center.    

• USA Operations includes the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the U.S. cost center.  

• China Operations included the exploration for, development of, and production of oil, NGLs and natural gas and other related activities within the China cost center. The Company terminated its production sharing contract with the China National Offshore Oil Corporation (“CNOOC”) and exited its China Operations effective July 31, 2019.  

• Market Optimization is primarily responsible for the sale of the Company’s proprietary production. These results are reported in the Canadian and USA Operations. Market optimization activities include third-party purchases and sales of product to provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification. These activities are reflected in the Market Optimization segment. Market Optimization sells substantially all of the Company’s upstream production to third-party customers. Transactions between segments are based on market values and are eliminated on consolidation.  

Corporate and Other mainly includes unrealized gains or losses recorded on derivative financial instruments. Once the instruments are settled, the realized gains and losses are recorded in the reporting segment to which the derivative instruments relate. Corporate and Other also includes amounts related to sublease rentals.

As of February 14, 2019, Encana’s segmented results reflect the business combination as discussed in Note 8.

Results of Operations (For the three months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019			2018
Revenues
Product and service revenues	$	377	$	453	$	1,097	$	718		$	3		$	-
Gains (losses) on risk management, net		87		8		35		(84	)		-			-
Sublease revenues		-		-		-		-			-			-
Total Revenues		464		461		1,132		634			3			-
Operating Expenses
Production, mineral and other taxes		3		4		63		41			-			-
Transportation and processing		211		211		125		34			-			-
Operating		32		34		151		80			4			-
Depreciation, depletion and amortization		100		95		438		241			-			-
Total Operating Expenses		346		344		777		396			4			-
Operating Income (Loss)	$	118	$	117	$	355	$	238		$	(1	)	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	294		$	317		$	-		$	-		$	1,771		$	1,488
Gains (losses) on risk management, net		-			(1	)		(41	)		(164	)		81			(241	)
Sublease revenues		-			-			19			15			19			15
Total Revenues		294			316			(22	)		(149	)		1,871			1,262
Operating Expenses
Production, mineral and other taxes		-			-			-			-			66			45
Transportation and processing		62			33			-			-			398			278
Operating		6			8			-			2			193			124
Purchased product		264			282			-			-			264			282
Depreciation, depletion and amortization		-			-			7			13			545			349
Accretion of asset retirement obligation		-			-			9			8			9			8
Administrative		-			-			81			57			81			57
Total Operating Expenses		332			323			97			80			1,556			1,143
Operating Income (Loss)	$	(38	)	$	(7	)	$	(119	)	$	(229	)		315			119
Other (Income) Expenses
Interest														99			92
Foreign exchange (gain) loss, net														30			(23	)
(Gain) loss on divestitures, net														(5	)		-
Other (gains) losses, net														(1	)		5
Total Other (Income) Expenses														123			74
Net Earnings (Loss) Before Income Tax														192			45
Income tax expense (recovery)														43			6
Net Earnings (Loss)													$	149		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

Results of Operations (For the nine months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues
Product and service revenues	$	1,222	$	1,236	$	3,062	$	1,880		$	37	$	-
Gains (losses) on risk management, net		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Total Revenues		1,396		1,329		3,190		1,695			37		-
Operating Expenses
Production, mineral and other taxes		11		12		176		97			-		-
Transportation and processing		640		608		340		92			-		-
Operating		96		98		414		238			16		-
Depreciation, depletion and amortization		287		257		1,141		628			-		-
Total Operating Expenses		1,034		975		2,071		1,055			16		-
Operating Income (Loss)	$	362	$	354	$	1,119	$	640		$	21	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	870		$	909		$	-		$	-		$	5,191		$	4,025
Gains (losses) on risk management, net		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Total Revenues		869			906			(331	)		(372	)		5,161			3,558
Operating Expenses
Production, mineral and other taxes		-			-			-			-			187			109
Transportation and processing		168			99			-			-			1,148			799
Operating		21			25			(2	)		11			545			372
Purchased product		784			803			-			-			784			803
Depreciation, depletion and amortization		-			1			26			38			1,454			924
Accretion of asset retirement obligation		-			-			28			24			28			24
Administrative		-			-			389			187			389			187
Total Operating Expenses		973			928			441			260			4,535			3,218
Operating Income (Loss)	$	(104	)	$	(22	)	$	(772	)	$	(632	)		626			340
Other (Income) Expenses
Interest														285			265
Foreign exchange (gain) loss, net														(62	)		93
(Gain) loss on divestitures, net														(4	)		(4	)
Other (gains) losses, net														24			2
Total Other (Income) Expenses														243			356
Net Earnings (Loss) Before Income Tax														383			(16	)
Income tax expense (recovery)														143			(55	)
Net Earnings (Loss)													$	240		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

Intersegment Information

							Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the three months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	2,088		$	1,513		$	(1,794	)	$	(1,197	)	$	294		$	316
Operating Expenses
Transportation and processing		173			120			(111	)		(87	)		62			33
Operating		6			8			-			-			6			8
Purchased product		1,947			1,392			(1,683	)		(1,110	)		264			282
Operating Income (Loss)	$	(38	)	$	(7	)	$	-		$	-		$	(38	)	$	(7	)

	Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the nine months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	5,459		$	4,203		$	(4,590	)	$	(3,297	)	$	869		$	906
Operating Expenses
Transportation and processing		465			335			(297	)		(236	)		168			99
Operating		21			25			-			-			21			25
Purchased product		5,078			3,864			(4,294	)		(3,061	)		784			803
Depreciation, depletion and amortization		-			1			-			-			-			1
Operating Income (Loss)	$	(105	)	$	(22	)	$	1		$	-		$	(104	)	$	(22	)

Capital Expenditures

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Canadian Operations	$	99	$	174	$	364	$	553
USA Operations		464		345		1,682		1,065
Market Optimization		2		-		2		-
Corporate & Other		1		4		4		8
	$	566	$	523	$	2,052	$	1,626

Goodwill, Property, Plant and Equipment and Total Assets by Segment

	Goodwill					Property, Plant and Equipment					Total Assets
	As at					As at					As at
	September 30,		December 31,			September 30,		December 31,			September 30,		December 31,
	2019			2018		2019			2018		2019			2018
Canadian Operations	$	660		$	640	$	1,111		$	999	$	1,978		$	1,852
USA Operations		1,935			1,913		13,782			6,591		16,634			9,104
Market Optimization		-			-		2			1		225			295
Corporate & Other		-			-		231			1,381		2,519			4,093
	$	2,595		$	2,553	$	15,126		$	8,972	$	21,356		$	15,344

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Leases

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Leases

11. Leases

Leases entered into for the right to use an asset are classified as either an operating or finance lease. Upon commencement of the lease, a ROU asset and corresponding lease liability are recognized on the Condensed Consolidated Balance Sheet for all operating and finance leases. Encana has elected the short-term lease exemption, which does not require a ROU asset or lease liability to be recognized on the Condensed Consolidated Balance Sheet when the lease term is 12 months or less and does not include an option to purchase the underlying asset that the lessee is reasonably certain to exercise.  

Upon commencement of the lease, ROU assets are recognized based on the initial measurement of the lease liability and adjusted for any lease payments made before commencement date of the lease, less any lease incentives and including any initial direct costs incurred. Lease liabilities are initially measured at the present value of future minimum lease payments over the lease term. The discount rate used to determine the present value is the rate implicit in the lease unless that rate cannot be determined, in which case Encana’s incremental borrowing rate is used.  

Rights to extend or terminate a lease are included in the lease term when there is reasonable certainty the right will be exercised. Factors used to assess reasonable certainty of rights to extend or terminate a lease include current and forecasted drillings plans, anticipated changes in development strategies, historical practice in extending similar contracts and current market conditions. Encana’s lease contracts include rights to extend leases after the initial term, ranging from month-to-month to less than 10 years.

Operating lease ROU assets and liabilities are subsequently measured at the present value of the lease payments not yet paid and discounted at the initial discount rate at commencement of the lease, less any impairments to the ROU asset. Operating lease expense and revenue from subleases are recognized in the Condensed Consolidated Statement of Earnings on a straight-line basis over the lease term. Finance lease ROU assets are amortized on a straight-line basis over the estimated useful life of the asset if the lessee is reasonably certain to exercise a purchase option or ownership of the leased asset transfers at the end of the lease term, otherwise the leased assets are amortized over the lease term. Amortization of finance lease ROU assets is included in depreciation, depletion and amortization in the Condensed Consolidated Statement of Earnings.

Variable lease payments include changes in index rates, mobilization and demobilization costs related to oil and gas equipment and certain costs associated with office and building leases. Variable lease payments are recognized when incurred. Lease and non-lease components are accounted for as a single lease component for compression, coolers and office subleases.

Operating leases include drilling rigs, compressors, marine vessels, camps, office and buildings, certain land easements and various equipment utilized in the development and production of oil, NGLs and natural gas. Finance leases include an office building and an offshore production platform. Subleases relate to office and building leases.

The tables below summarize Encana’s operating and finance lease costs and include ROU assets and lease liabilities, amounts recognized in net earnings during the period and other lease information.

(US$ millions, unless otherwise specified)	As at September 30, 2019
Condensed Consolidated Balance Sheet (1):
Operating Lease ROU Assets, in Other Assets	$	1,045
Finance Lease ROU Assets, in Other Property Plant and Equipment		39
Operating Lease Liabilities:
Current		79
Long-term		972
Finance Lease Liabilities:
Current, in accounts payable and accrued liabilities		88
Long-term, in other liabilities and provisions		144
Weighted Average Discount Rate
Operating leases	5.42%
Finance leases	5.97%
Weighted Average Remaining Lease Term
Operating leases	16.4 years
Finance leases	3.4 years

(1) Total ROU assets and liabilities are recorded at the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Lease Costs (1):
Operating Lease Costs, Excluding Short-Term Leases	$	45	$	133
Finance Lease Costs:
Amortization of ROU assets		1		3
Interest on lease liabilities		3		10
Total Finance Lease Costs		4		13
Short-Term Lease Costs		93		250
Variable Lease Costs		3		10
Sublease Income:
Operating lease income		15		41
Variable lease income		4		13
Other Information:
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating cash outflows from operating leases		57		157
Investing cash outflows from operating leases		80		220
Operating cash outflows from finance leases		3		10
Financing cash outflows from finance leases		22		63
Supplemental Non-Cash Information:
New ROU operating lease assets and liabilities		1		11

(1) Lease costs include amounts capitalized into property, plant and equipment on the Condensed Consolidated Balance Sheet and lease expense recognized in the Condensed Consolidated Statement of Earnings.

Operating lease expense is reflected in the Condensed Consolidated Statement of Earnings as follows:

	Three Months Ended		Nine Months Ended
	September 30, 2019		September 30, 2019
Operating Lease Expense
Transportation and processing	$	1	$	2
Operating		28		76
Administrative (1)		30		86
Total Operating Lease Expense	$	59	$	164

(1) Includes $23 million and $69 million for the three and nine months ended September 30, 2019, respectively, related to The Bow office building.

The following table outlines the Company’s future lease payments and lease liabilities related to the Company’s operating and finance leases as at September 30, 2019:

	2019			2020			2021			2022			2023			Thereafter			Total
Operating Leases (1)
Expected Future Lease Payments	$	37		$	128		$	112		$	97		$	85		$	1,165		$	1,624
Less: Discounting																				573
Present Value of Future Operating    Lease Payments																			$	1,051
Sublease Income (undiscounted)	$	(10	)	$	(41	)	$	(42	)	$	(37	)	$	(37	)	$	(566	)	$	(733	)
Finance Leases
Expected Future Lease Payments	$	25		$	99		$	87		$	8		$	8		$	30		$	257
Less: Discounting																				25
Present Value of Future Finance    Lease Payments																			$	232
Sublease Income (undiscounted) (2)	$	(2	)	$	(8	)	$	(8	)	$	(8	)	$	(7	)	$	(24	)	$	(57	)

(1) Lease payments are presented based on the gross contractual amount. A portion of the future lease payments will be recovered from other working interest owners based on their proportionate share when incurred.

(2) Classified as operating lease.

There are no commitments for leases with terms greater than one year that have not yet commenced at September 30, 2019.

Refer to Notes 14 and 25 under Item 8 of Encana’s 2018 Annual Report on Form 10-K for comparative period disclosure of future lease payments and sublease income related to capital and operating leases and The Bow office building. Operating leases in the table above includes The Bow office building which was determined to be an operating lease on transition to Topic 842 as disclosed in Note 2. Under Topic 840, The Bow was accounted for as a financing transaction under a failed sales leaseback.  

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2019

Commitments And Contingencies Disclosure [Abstract]

Commitments and Contingencies

24. Commitments and Contingencies

Commitments

The following table outlines the Company’s commitments as at September 30, 2019:

	Expected Future Payments
(undiscounted)	2019		2020		2021		2022		2023		Thereafter		Total
Transportation and Processing	$	197	$	731	$	625	$	594	$	485	$	2,407	$	5,039
Drilling and Field Services		64		24		6		-		-		-		94
Building Leases		4		15		14		11		7		15		66
Total	$	265	$	770	$	645	$	605	$	492	$	2,422	$	5,199

Associated with the adoption of Topic 842, all operating leases were recognized on the Condensed Consolidated Balance Sheet. Accordingly, operating leases with terms greater than one year are not included in the commitments table above. The table above includes short-term leases with contract terms less than 12 months, such as drilling rigs and field office leases, as well as non-lease operating cost components associated with building leases. See Notes 2 and 11 for additional disclosures on leases.

Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note 17. Divestiture transactions can reduce certain commitments disclosed above.

Contingencies

Encana is involved in various legal claims and actions arising in the normal course of the Company’s operations. Although the outcome of these claims cannot be predicted with certainty, the Company does not expect these matters to have a material adverse effect on Encana’s financial position, cash flows or results of operations. Management’s assessment of these matters may change in the future as certain of these matters are in early stages or are subject to a number of uncertainties. For material matters that the Company believes an unfavorable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures. If an unfavorable outcome were to occur, there exists the possibility of a material impact on the Company’s consolidated net earnings or loss for the period in which the effect becomes reasonably estimable. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. Such accruals are based on the Company’s information known about the matters, estimates of the outcomes of such matters and experience in handling similar matters.

In conjunction with the acquisition of Newfield as described in Note 8, various legal claims and actions arising in the normal course of Newfield’s operations were assumed by Encana. On March 29, 2019, Newfield and its wholly-owned subsidiary entered into an Agreement and Mutual Release with Sapura Energy Berhad, formerly known as SapuraKencana Petroleum Berhad, and Sapura Exploration and Production Inc., formerly known as SapuraKencana Energy Inc. (collectively, “Sapura”) to settle arbitration claims arising from Sapura’s purchase of Newfield’s Malaysian business in February 2014. Under the Agreement and Mutual Release, Newfield and its wholly-owned subsidiary paid Sapura $22.5 million. The settlement amount including legal fees was included in the purchase price allocation as part of the current liabilities assumed by Encana at the acquisition date. Although the outcome of any remaining legal claims and actions assumed by Encana following the acquisition of Newfield cannot be predicted with certainty, the Company does not expect these matters to have a material adverse effect on Encana’s financial position, cash flows or results of operations.

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Revenue from Contracts with Customers (Tables)

9 Months Ended

Sep. 30, 2019

Disaggregation Of Revenue [Abstract]

Disaggregation of Revenue

Revenues (For the three months ended September 30)

	Canadian Operations				USA Operations						China Operations (1)
	2019		2018		2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	3	$	1	$	905		$	590		$	3	$	-
NGLs		225		259		99			98			-		-
Natural gas		150		195		95			31			-		-
Service revenues
Gathering and processing		2		1		(1	)		4			-		-
Product and Service Revenues		380		456		1,098			723			3		-
Other Revenues
Gains (losses) on risk management, net (3)		87		8		35			(84	)		-		-
Sublease revenues		-		-		-			-			-		-
Other Revenues		87		8		35			(84	)		-		-
Total Revenues	$	467	$	464	$	1,133		$	639		$	3	$	-

	Market Optimization					Corporate & Other						Consolidated
	2019		2018			2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	107	$	34		$	-		$	-		$	1,018	$	625
NGLs		2		1			-			-			326		358
Natural gas		181		274			-			-			426		500
Service revenues
Gathering and processing		-		-			-			-			1		5
Product and Service Revenues		290		309			-			-			1,771		1,488
Other Revenues
Gains (losses) on risk management, net (3)		-		(1	)		(41	)		(164	)		81		(241	)
Sublease revenues		-		-			19			15			19		15
Other Revenues		-		(1	)		(22	)		(149	)		100		(226	)
Total Revenues	$	290	$	308		$	(22	)	$	(149	)	$	1,871	$	1,262

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

Revenues (For the nine months ended September 30)

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	6	$	6	$	2,461	$	1,579		$	37	$	-
NGLs		659		655		332		221			-		-
Natural gas		563		580		276		92			-		-
Service revenues
Gathering and processing		4		5		2		4			-		-
Product and Service Revenues		1,232		1,246		3,071		1,896			37		-
Other Revenues
Gains (losses) on risk management, net (3)		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Other Revenues		174		93		128		(185	)		-		-
Total Revenues	$	1,406	$	1,339	$	3,199	$	1,711		$	37	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues from Customers
Product revenues (2)
Oil	$	205		$	84		$	-		$	-		$	2,709		$	1,669
NGLs		6			6			-			-			997			882
Natural gas		640			793			-			-			1,479			1,465
Service revenues
Gathering and processing		-			-			-			-			6			9
Product and Service Revenues		851			883			-			-			5,191			4,025
Other Revenues
Gains (losses) on risk management, net (3)		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Other Revenues		(1	)		(3	)		(331	)		(372	)		(30	)		(467	)
Total Revenues	$	850		$	880		$	(331	)	$	(372	)	$	5,161		$	3,558

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

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Condensed Consolidated Statement Of Cash Flows (unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Operating Activities
Net Earnings (Loss)	$ 149	$ 39	$ 240	$ 39
Depreciation, depletion and amortization	545	349	1,454	924
Accretion of asset retirement obligation	9	8	28	24	$ 32
Deferred income taxes	44	6	140	6
Unrealized (gain) loss on risk management	41	164	385	422
Unrealized foreign exchange (gain) loss	49	(23)	(11)	156
Foreign exchange on settlements	(18)	(1)	(53)	(47)
(Gain) loss on divestitures, net	(5)	0	(4)	(4)
Other	3	47	(63)	55
Net change in other assets and liabilities	(29)	(17)	(55)	(33)
Net change in non-cash working capital	(32)	313	130	199
Cash From (Used in) Operating Activities	756	885	2,191	1,741
Investing Activities
Capital expenditures	(566)	(523)	(2,052)	(1,626)
Acquisitions	(25)	(15)	(66)	(17)
Corporate acquisition, net of cash and restricted cash acquired	0	0	94	0
Proceeds from divestitures	171	24	177	89
Net change in investments and other	(142)	(8)	(118)	72
Cash From (Used in) Investing Activities	(562)	(522)	(1,965)	(1,482)
Financing Activities
Net issuance (repayment) of revolving long-term debt	(21)	0	740	0
Repayment of long-term debt	0	0	(500)	0
Purchase of common shares	(213)	(50)	(1,250)	(250)
Dividends on common shares	(24)	(14)	(77)	(43)
Finance lease payments and other financing arrangements	(22)	(23)	(63)	(68)
Cash From (Used in) Financing Activities	(280)	(87)	(1,150)	(361)
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents and Restricted Cash Held in Foreign Currency	0	3	4	(2)
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(86)	279	(920)	(104)
Cash, Cash Equivalents and Restricted Cash, Beginning of Period	224	336	1,058	719	719
Cash, Cash Equivalents and Restricted Cash, End of Period	138	615	138	615	$ 1,058
Cash, End of Period	44	30	44	30
Cash Equivalents, End of Period	94	585	94	585
Restricted Cash, End of Period	$ 0	$ 0	$ 0	$ 0

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Condensed Consolidated Balance Sheet (unaudited) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents	$ 138	$ 1,058
Accounts receivable and accrued revenues	1,127	789
Risk management	284	554
Income tax receivable	316	275
Total Current Assets	1,865	2,676
Oil and natural gas properties, based on full cost accounting
Proved properties	50,094	41,241
Unproved properties	3,943	3,730
Other	892	2,122
Property, plant and equipment	54,929	47,093
Less: Accumulated depreciation, depletion and amortization	(39,803)	(38,121)
Property, plant and equipment, net	15,126	8,972
Other Assets	1,202	147
Risk Management	47	161
Deferred Income Taxes	521	835
Goodwill	2,595	2,553
Total Assets	21,356	15,344
Current Liabilities
Accounts payable and accrued liabilities	2,191	1,490
Current portion of operating lease liabilities	79	0
Income tax payable	1	1
Risk management	10	25
Current portion of long-term debt	0	500
Total Current Liabilities	2,281	2,016
Long-Term Debt	7,024	3,698
Operating Lease Liabilities	972	0
Other Liabilities and Provisions	548	1,769
Risk Management	14	22
Asset Retirement Obligation	414	365
Deferred Income Taxes	182	27
Total Liabilities	11,435	7,897
Commitments and Contingencies
Shareholders’ Equity
Share capital - authorized unlimited common shares 2019 issued and outstanding: 1,299.2 million shares (2018: 952.5 million shares)	7,061	4,656
Paid in surplus	1,402	1,358
Retained earnings	452	435
Accumulated other comprehensive income	1,006	998
Total Shareholders’ Equity	9,921	7,447
Total Liabilities and Shareholders' Equity	$ 21,356	$ 15,344

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Compensation Plans

9 Months Ended

Sep. 30, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Compensation Plans

19. Compensation Plans

Encana has a number of compensation arrangements under which the Company awards various types of long-term incentive grants to eligible employees and Directors. They may include TSARs, Performance TSARs, SARs, Performance Share Units (“PSUs”), Deferred Share Units (“DSUs”) and RSUs. These compensation arrangements are share-based.  

Encana accounts for TSARs, Performance TSARs, SARs, PSUs and RSUs as cash-settled share-based payment transactions and, accordingly, accrues compensation costs over the vesting period based on the fair value of the rights determined using the Black-Scholes-Merton and other fair value models.  

The following weighted average assumptions were used to determine the fair value of the share units outstanding:  

	As at September 30, 2019		As at September 30, 2018
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units
Risk Free Interest Rate	1.58%	1.58%	2.18%	2.18%
Dividend Yield	1.63%	1.64%	0.46%	0.46%
Expected Volatility Rate (1)	44.14%	42.77%	55.44%	51.90%
Expected Term	2.9 yrs	2.6 yrs	1.6 yrs	2.0 yrs
Market Share Price	US$4.60	C$6.07	US$13.11	C$16.93

(1) Volatility was estimated using historical rates.

The Company has recognized the following share-based compensation costs:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Total Compensation Costs of Transactions Classified as Cash-Settled	$	2		$	36		$	46		$	118
Less: Total Share-Based Compensation Costs Capitalized		(1	)		(11	)		(16	)		(33	)
Total Share-Based Compensation Expense (Recovery)	$	1		$	25		$	30		$	85
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	-		$	8		$	12		$	24
Administrative		1			17			18			61
	$	1		$	25		$	30		$	85

As at September 30, 2019, the liability for share-based payment transactions totaled $65 million ($165 million as at December 31, 2018), of which $36 million ($131 million as at December 31, 2018) is recognized in accounts payable and accrued liabilities and $29 million ($34 million as at December 31, 2018) is recognized in other liabilities and provisions in the Condensed Consolidated Balance Sheet.

	As at September 30, 2019			As at December 31, 2018
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested		$	53		$	148
Vested			12			17
		$	65		$	165

The following units were granted primarily in conjunction with the Company’s annual grant of long-term incentive awards. The TSARs, SARs, PSUs and RSUs were granted at the volume-weighted average trading price of Encana’s common shares for the five days prior to the grant date.

Nine Months Ended September 30, 2019 (thousands of units)
TSARs	1,244
SARs	1,718
PSUs	7,833
DSUs	111
RSUs	11,004

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Share Capital

9 Months Ended

Sep. 30, 2019

Class Of Stock Disclosures [Abstract]

Share Capital

15. Share Capital

Authorized

The Company is authorized to issue an unlimited number of no par value common shares and Class A Preferred Shares limited to a number equal to not more than 20 percent of the issued and outstanding number of common shares at the time of issuance. No Class A Preferred Shares are outstanding.

Issued and Outstanding

	As at September 30, 2019						As at December 31, 2018
	Number (millions)			Amount			Number (millions)			Amount
Common Shares Outstanding, Beginning of Year		952.5		$	4,656			973.1		$	4,757
Common Shares Purchased		(196.7	)		(1,073	)		(20.7	)		(102	)
Common Shares Issued		543.4			3,478			-			-
Common Shares Issued Under Dividend Reinvestment Plan		-			-			0.1			1
Common Shares Outstanding, End of Period		1,299.2		$	7,061			952.5		$	4,656

On February 13, 2019, Encana completed the acquisition of all the issued and outstanding shares of common stock of Newfield whereby Encana issued approximately 543.4 million common shares to Newfield shareholders, representing an exchange ratio of 2.6719 Encana common shares for each share of Newfield common stock held. See Note 8 for further information on the business combination.

Substantial Issuer Bid

On June 10, 2019, the Company announced its intention to purchase, for cancellation, up to $213 million of its common shares through a substantial issuer bid (“SIB”) which commenced on July 8, 2019. On August 29, 2019, the Company purchased approximately 47.3 million common shares at a price of $4.50 per share for an aggregate purchase price of approximately $213 million, of which $257 million was charged to share capital and $44 million was credited to paid in surplus.

The purchase was made in accordance with the terms and conditions of the SIB, with consideration allocated to share capital equivalent to the average carrying amount of the shares, with the excess of the carrying amount over the purchase consideration credited to paid in surplus.

Normal Course Issuer Bid

On February 27, 2019, the Company announced that the TSX accepted the Company’s notice of intention to purchase, for cancellation, up to approximately 149.4 million Encana common shares pursuant to a NCIB over a 12-month period from March 4, 2019 to March 3, 2020.

During the nine months ended September 30, 2019, the Company purchased approximately 149.4 million common shares under its current NCIB for total consideration of approximately $1,037 million. Of the amount paid, $816 million was charged to share capital and $221 million was charged to retained earnings.

All purchases were made in accordance with the NCIB at prevailing market prices plus brokerage fees, with consideration allocated to share capital up to the average carrying amount of the shares, with any excess allocated to retained earnings.

For the nine months ended September 30, 2018 and the twelve months ended December 31, 2018, the Company purchased approximately 20.7 million common shares under the previous NCIB which was in place from February 28, 2018 to February 27, 2019 for total consideration of approximately $250 million. Of the amount paid, $102 million was charged to share capital and $148 million was charged to retained earnings.

Dividend Reinvestment Plan

On February 28, 2019, Encana suspended its dividend reinvestment plan (“DRIP”). During the twelve months ended December 31, 2018, Encana issued 69,329 common shares totaling $0.6 million under the DRIP.

Dividends

During the three months ended September 30, 2019, Encana declared and paid dividends of $0.01875 per common share totaling $24 million (2018 - $0.015 per common share totaling $14 million). During the nine months ended September 30, 2019, Encana declared and paid dividends of $0.05625 per common share totaling $77 million (2018 - $0.045 per common share totaling $43 million).

For the three and nine months ended September 30, 2018, the dividends paid included $0.1 million and $0.5 million, respectively, in common shares issued in lieu of cash dividends under the DRIP.

On October 30, 2019, the Board of Directors declared a dividend of $0.01875 per common share payable on December 31, 2019 to common shareholders of record as of December 13, 2019.

Earnings Per Common Share

The following table presents the computation of net earnings (loss) per common share:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(US$ millions, except per share amounts)	2019		2018		2019		2018
Net Earnings (Loss)	$	149	$	39	$	240	$	39
Number of Common Shares:
Weighted average common shares outstanding - Basic		1,322.8		955.1		1,308.4		962.2
Effect of dilutive securities		-		-		-		-
Weighted Average Common Shares Outstanding - Diluted		1,322.8		955.1		1,308.4		962.2
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.11	$	0.04	$	0.18	$	0.04

Encana Stock Option Plan

Encana has share-based compensation plans that allow employees to purchase common shares of the Company. Option exercise prices are not less than the market value of the common shares on the date the options are granted. All options outstanding as at September 30, 2019 have associated Tandem Stock Appreciation Rights (“TSARs”) attached. In lieu of exercising the option, the associated TSARs give the option holder the right to receive a cash payment equal to the excess of the market price of Encana’s common shares at the time of the exercise over the original grant price. Historically, most holders of options with TSARs have elected to exercise their stock options as a Stock Appreciation Right (“SAR”) in exchange for a cash payment. As a result, outstanding TSARs are not considered potentially dilutive securities.

Encana Restricted Share Units

Encana has a share-based compensation plan whereby eligible employees and Directors are granted Restricted Share Units (“RSUs”). An RSU is a conditional grant to receive the equivalent of an Encana common share upon vesting of the RSUs and in accordance with the terms and conditions of the compensation plan and grant agreements. The Company currently settles vested RSUs in cash. As a result, RSUs are currently not considered potentially dilutive securities.  

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Property, Plant And Equipment, Net (Tables)

9 Months Ended

Sep. 30, 2019

Property Plant And Equipment [Abstract]

Schedule Of Property, Plant And Equipment

	As at September 30, 2019							As at December 31, 2018
			Accumulated							Accumulated
	Cost		DD&A			Net		Cost		DD&A			Net
Canadian Operations
Proved properties	$	14,817	$	(13,949	)	$	868	$	13,996	$	(13,261	)	$	735
Unproved properties		223		-			223		237		-			237
Other		20		-			20		27		-			27
		15,060		(13,949	)		1,111		14,260		(13,261	)		999
USA Operations
Proved properties		35,223		(25,186	)		10,037		27,189		(24,099	)		3,090
Unproved properties		3,720		-			3,720		3,493		-			3,493
Other		25		-			25		8		-			8
		38,968		(25,186	)		13,782		30,690		(24,099	)		6,591
Market Optimization		8		(6	)		2		7		(6	)		1
Corporate & Other		893		(662	)		231		2,136		(755	)		1,381
	$	54,929	$	(39,803	)	$	15,126	$	47,093	$	(38,121	)	$	8,972

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Asset Retirement Obligation (Tables)

9 Months Ended

Sep. 30, 2019

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Change In Asset Retirement Obligation

	As at			As at
	September 30,			December 31,
	2019			2018
Asset Retirement Obligation, Beginning of Year	$	455		$	514
Liabilities Incurred		13			17
Liabilities Acquired (See Note 8)		184			-
Liabilities Settled and Divested		(100	)		(56	)
Change in Estimated Future Cash Outflows		-			(20	)
Accretion Expense		28			32
Foreign Currency Translation		10			(32	)
Asset Retirement Obligation, End of Period	$	590		$	455
Current Portion	$	176		$	90
Long-Term Portion		414			365
	$	590		$	455

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Fair Value Measurements (Summary Of Changes In Level 3 Fair Value Measurements) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Balance, Beginning Balance	$ 139	$ (51)
Total Gains (Losses)	24	(177)
Purchases, sales and issuances	0	0
Settlements	(49)	80
Transfers Out of Level 3	0	0
Balance, Ending Balance	114	(148)
Change in Unrealized Gains (Losses) Related to Assets and Liabilities Held at End of Period	$ 83	$ (136)

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Financial Instruments and Risk Management (Risk Management Positions) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($) $ / bbl $ / Mcf MMcf MBbls
Derivative [Line Items]
Net Premiums Received on Unexpired Options	$ (7)
Other Derivative Contracts, Net	(10)
Foreign Currency Swaps, at Fair value, Net	5
Total Fair Value Position and Net Premiums Received	$ 297
Oil [Member] | WTI Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	45.0
Term	Dec. 31, 2019
Average Price, Fixed Price Contracts | $ / bbl	60.24
Price Risk Derivatives, at Fair Value, Net	$ 26
Oil [Member] | WTI Fixed Price, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	24.0
Term	Dec. 31, 2020
Average Price, Fixed Price Contracts | $ / bbl	60.05
Price Risk Derivatives, at Fair Value, Net	$ 74
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	87.5
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ 27
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	45.86
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	67.72
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	56.47
Oil [Member] | WTI Fixed Price Swaptions [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	4.0
Term	Dec. 31, 2021
Average Price, Fixed Price Contracts | $ / bbl	58.00
Price Risk Derivatives, at Fair Value, Net	$ (4)
Oil [Member] | WTI Three-Way Options, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	80.0
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 54
Oil [Member] | WTI Three-Way Options, Maturing In Two Years [Member] | Sold [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	43.44
Oil [Member] | WTI Three-Way Options, Maturing In Two Years [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	61.68
Oil [Member] | WTI Three-Way Options, Maturing In Two Years [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	53.44
Oil [Member] | Basis Contracts, Maturing Remainder of Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ (19)
Oil [Member] | West Texas Intermediate Costless Collars Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	43.0
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ 13
Oil [Member] | West Texas Intermediate Costless Collars Maturing Remainder of Fiscal Year [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	65.57
Oil [Member] | West Texas Intermediate Costless Collars Maturing Remainder of Fiscal Year [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	56.28
Oil [Member] | West Texas Intermediate Costless Collars, Maturing in Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	15.0
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 20
Oil [Member] | West Texas Intermediate Costless Collars, Maturing in Two Years [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	68.71
Oil [Member] | West Texas Intermediate Costless Collars, Maturing in Two Years [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	50.00
Oil [Member] | Basis Contracts, Maturing In Two Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ (34)
Natural Gas Liquids [Member] | Propane Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	3.8
Term	Dec. 31, 2019
Average Price, Fixed Price Contracts | $ / bbl	35.72
Price Risk Derivatives, at Fair Value, Net	$ 11
Natural Gas Liquids [Member] | Propane Fixed Price, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	1.8
Term	Dec. 31, 2020
Average Price, Fixed Price Contracts | $ / bbl	21.00
Price Risk Derivatives, at Fair Value, Net	$ 1
Natural Gas Liquids [Member] | Butane Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	6.5
Term	Dec. 31, 2019
Average Price, Fixed Price Contracts | $ / bbl	40.54
Price Risk Derivatives, at Fair Value, Net	$ 10
Natural Gas Liquids [Member] | Ethane Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MBbls	5.3
Term	Dec. 31, 2019
Average Price, Fixed Price Contracts | $ / bbl	17.23
Price Risk Derivatives, at Fair Value, Net	$ 5
Natural Gas [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 125
Natural Gas [Member] | NYMEX Costless Collars, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	177
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ 8
Natural Gas [Member] | NYMEX Costless Collars, Maturing Remainder of Fiscal Year [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	3.05
Natural Gas [Member] | NYMEX Costless Collars, Maturing Remainder of Fiscal Year [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.89
Natural Gas [Member] | Basis Contracts, Maturing Remainder of Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ 10
Natural Gas [Member] | NYMEX Fixed Price, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	687
Term	Dec. 31, 2019
Average Price, Fixed Price Contracts | $ / Mcf	2.72
Price Risk Derivatives, at Fair Value, Net	$ 19
Natural Gas [Member] | Basis Contracts, Maturing In Two Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 30
Natural Gas [Member] | NYMEX Fixed Price, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	653
Term	Dec. 31, 2020
Average Price, Fixed Price Contracts | $ / Mcf	2.69
Price Risk Derivatives, at Fair Value, Net	$ 64
Natural Gas [Member] | Basis Contracts, Maturing In Three Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2021
Price Risk Derivatives, at Fair Value, Net	$ (2)
Natural Gas [Member] | Basis Contracts, Maturing After Four Years [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ (8)
Natural Gas [Member] | NYMEX Fixed Price Swaptions [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	180
Term	Dec. 31, 2021
Average Price, Fixed Price Contracts | $ / Mcf	2.61
Price Risk Derivatives, at Fair Value, Net	$ (9)
Natural Gas [Member] | NYMEX Costless Collars, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	55
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 4
Natural Gas [Member] | NYMEX Costless Collars, Maturing In Two Years [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.88
Natural Gas [Member] | NYMEX Costless Collars, Maturing In Two Years [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.50
Natural Gas [Member] | NYMEX Three-Way Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	330
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 7
Natural Gas [Member] | NYMEX Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.25
Natural Gas [Member] | NYMEX Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member] | Call Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.72
Natural Gas [Member] | NYMEX Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Bought [Member] | Put Option [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	2.60
Natural Gas [Member] | NYMEX Call Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	230
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ 0
Average Price, Options/Collars | $ / Mcf	3.75
Natural Gas [Member] | NYMEX Call Options, Maturing Remainder Of Fiscal Year [Member] | Bought [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	230
Term	Dec. 31, 2019
Price Risk Derivatives, at Fair Value, Net	$ (1)
Average Price, Options/Collars | $ / Mcf	3.75
Natural Gas [Member] | NYMEX Call Options, Maturing In Two Years [Member] | Sold [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volumes/day | MMcf	230
Term	Dec. 31, 2020
Price Risk Derivatives, at Fair Value, Net	$ 4
Average Price, Options/Collars | $ / Mcf	3.25
Natural Gas [Member] | Other Financial Positions [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ (1)
Oil and NGLs [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 184
Minimum [Member] | Currency Swap [Member]
Derivative [Line Items]
Term	Oct. 01, 2019
Minimum [Member] | Natural Gas [Member] | Basis Contracts, Maturing After Four Years [Member]
Derivative [Line Items]
Term	Jan. 01, 2022
Maximum [Member] | Currency Swap [Member]
Derivative [Line Items]
Term	Dec. 31, 2020
Maximum [Member] | Natural Gas [Member] | Basis Contracts, Maturing After Four Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2025

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Income Taxes (Provision For Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Total Current Tax Expense (Recovery)	$ (1)	$ 0	$ 3	$ (61)
Total Deferred Tax Expense (Recovery)	44	6	140	6
Income Tax Expense (Recovery)	$ 43	$ 6	$ 143	$ (55)
Effective Tax Rate	22.40%	13.30%	37.30%	343.80%
Canada [Member]
Total Current Tax Expense (Recovery)	$ (2)	$ 0	$ 0	$ (66)
Total Deferred Tax Expense (Recovery)	(12)	19	22	(9)
United States [Member]
Total Current Tax Expense (Recovery)	1	0	3	2
Total Deferred Tax Expense (Recovery)	56	(3)	117	4
Other Countries [Member]
Total Current Tax Expense (Recovery)	0	0	0	3
Total Deferred Tax Expense (Recovery)	$ 0	$ (10)	$ 1	$ 11

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Compensation Plans (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Liability For Cash-Settled Share-Based Payment Transactions	$ 65	$ 165
Liability for share-based payment recognized in accounts payable and accrued liabilities	36	131
Liability for share-based payment recognized in other liabilities and provisions	$ 29	$ 34

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Restructuring Charges (Restructuring Costs Expensed) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Restructuring Charges [Abstract]
Severance and Benefits	$ 4	$ 0	$ 132	$ 0
Outplacement, Moving and Other Expenses	0	0	2	0
Restructuring Expenses	$ 4	$ 0	$ 134	$ 0	$ 0

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Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Product revenues	$ 1,771	$ 1,488	$ 5,191	$ 4,025
Gains (losses) on risk management, net	81	(241)	(84)	(517)
Sublease revenues	19	15	54	50
Other revenues	100	(226)	(30)	(467)
Total Revenues	1,871	1,262	5,161	3,558
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	380	456	1,232	1,246
Gains (losses) on risk management, net	87	8	174	93
Sublease revenues	0	0	0	0
Other revenues	87	8	174	93
Total Revenues	467	464	1,406	1,339
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	1,098	723	3,071	1,896
Gains (losses) on risk management, net	35	(84)	128	(185)
Sublease revenues	0	0	0	0
Other revenues	35	(84)	128	(185)
Total Revenues	1,133	639	3,199	1,711
Operating Segments [Member] | China Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	3	0	37	0
Gains (losses) on risk management, net	0	0	0	0
Sublease revenues	0	0	0	0
Other revenues	0	0	0	0
Total Revenues	3	0	37	0
Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	290	309	851	883
Gains (losses) on risk management, net	0	(1)	(1)	(3)
Sublease revenues	0	0	0	0
Other revenues	0	(1)	(1)	(3)
Total Revenues	290	308	850	880
Corporate & Other [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Gains (losses) on risk management, net	(41)	(164)	(385)	(422)
Sublease revenues	19	15	54	50
Other revenues	(22)	(149)	(331)	(372)
Total Revenues	(22)	(149)	(331)	(372)
Oil [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	1,018	625	2,709	1,669
Oil [Member] | Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	3	1	6	6
Oil [Member] | Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	905	590	2,461	1,579
Oil [Member] | Operating Segments [Member] | China Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	3	0	37	0
Oil [Member] | Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	107	34	205	84
Oil [Member] | Corporate & Other [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas Liquids [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	326	358	997	882
Natural Gas Liquids [Member] | Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	225	259	659	655
Natural Gas Liquids [Member] | Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	99	98	332	221
Natural Gas Liquids [Member] | Operating Segments [Member] | China Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas Liquids [Member] | Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	2	1	6	6
Natural Gas Liquids [Member] | Corporate & Other [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	426	500	1,479	1,465
Natural Gas [Member] | Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	150	195	563	580
Natural Gas [Member] | Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	95	31	276	92
Natural Gas [Member] | Operating Segments [Member] | China Operations Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas [Member] | Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	181	274	640	793
Natural Gas [Member] | Corporate & Other [Member] | Product Revenues Including Sale of Product Purchased from Third Parties [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas Gathering and Processing [Member]
Disaggregation of Revenue [Line Items]
Product revenues	1	5	6	9
Natural Gas Gathering and Processing [Member] | Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	2	1	4	5
Natural Gas Gathering and Processing [Member] | Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	(1)	4	2	4
Natural Gas Gathering and Processing [Member] | Operating Segments [Member] | China Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas Gathering and Processing [Member] | Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	0	0	0	0
Natural Gas Gathering and Processing [Member] | Corporate & Other [Member]
Disaggregation of Revenue [Line Items]
Product revenues	$ 0	$ 0	$ 0	$ 0

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Pension and Other Post-Employment Benefits (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	$ 32	$ 23
Operating Expense [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	20	17
Administrative Expense [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	6	6
Other Nonoperating Income (Expense) [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	$ 6	$ 0

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Business Combination - Schedule of Preliminary Purchase Price Allocations (Parenthetical) (Details) - Newfield Exploration Company [Member] $ / shares in Units, $ in Millions	Feb. 13, 2019 USD ($) $ / shares
Business Acquisition [Line Items]
Business acquisition price per share | $ / shares	$ 6.40
Business acquisition Fair value notional share price | $ / shares	$ 6.50
Business acquisition consecutive trading days	5 days
Increase in other liabilities	$ 12
Decrease in deferred tax liabilities	3
Increase in goodwill	$ 9

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Acquisitions and Divestitures (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Acquisitions and Divestitures [Line Items]
Divestitures	$ 171	$ 24	$ 177	$ 89
Canadian Operations [Member] | Operating Segments [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions			0	17
Divestitures	0	(2)	0	55
USA Operations [Member] | Operating Segments [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions			66	0
Divestitures	$ 171	$ 26	$ 177	$ 34

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Other Liabilities And Provisions (Schedule Of Other Liabilities And Provisions) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Other Liabilities And Provisions [Line Items]
The Bow Office Building	$ 0		$ 1,224
Obligation under Finance Lease	144		211
Pensions and Other Post-Employment Benefits	170		105
Long-Term Incentives	29		34
Other Derivative Contracts, Liabilities	10		14
Other	25		18
Other Liabilities and Provisions	548	$ 545	1,769
Other Liabilities and Provisions [Member]
Other Liabilities And Provisions [Line Items]
Unrecognized Tax Benefits	172		167
Other Derivative Contracts, Liabilities	$ 8		$ 10

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Share Capital (Schedule of Common Stock Issued and Outstanding) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Class Of Stock Disclosures [Abstract]
Common Shares Outstanding, Beginning of Year, Shares			952,500,000	973,100,000	973,100,000
Common Shares Purchased, Shares			(196,700,000)		(20,700,000)
Stock Issued During Period, Shares, New Issues			543,400,000		0
Common Shares Issued under Dividend Reinvestment Plan, Shares			0		69,329
Common Shares Outstanding, End of Period, Shares	1,299,200,000		1,299,200,000		952,500,000
Common Shares Outstanding, Beginning of Year			$ 4,656.0	$ 4,757.0	$ 4,757.0
Common Shares Purchased, Value			(1,073.0)		(102.0)
Stock Issued During Period, Value, New Issues			3,478.0		0.0
Common Shares Issued Under Dividend Reinvestment Plan	$ 0.0	$ 0.0	0.0	$ 0.0	0.6
Common Shares Outstanding, End of Period	$ 7,061.0		$ 7,061.0		$ 4,656.0

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Leases (Summary of Operating And Finance Lease Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 01, 2019	Dec. 31, 2018
Leases [Abstract]
Operating Lease ROU Assets, in Other Assets	$ 1,045		$ 1,045
Operating Lease Right Of Use Asset Statement Of Financial Position Extensible List	us-gaap:OtherAssetsNoncurrent		us-gaap:OtherAssetsNoncurrent
Finance Lease ROU Assets, in Other Property Plant and Equipment	$ 39		$ 39
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:PropertyPlantAndEquipmentOther		us-gaap:PropertyPlantAndEquipmentOther
Operating Lease Liabilities, Current	$ 79		$ 79		$ 67	$ 0
Operating Lease Liabilities, Long-term	972		972		$ 948	0
Finance Lease Liabilities, Current, in accounts payable and accrued liabilities	$ 88		$ 88
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:AccountsPayableAndAccruedLiabilitiesCurrent		us-gaap:AccountsPayableAndAccruedLiabilitiesCurrent
Finance Lease Liabilities, Long-term, in other liabilities and provisions	$ 144		$ 144			$ 211
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesNoncurrent		us-gaap:OtherLiabilitiesNoncurrent
Weighted Average Discount Rate
Operating leases	5.42%		5.42%
Finance leases	5.97%		5.97%
Weighted Average Remaining Lease Term
Operating leases	16 years 4 months 24 days		16 years 4 months 24 days
Finance leases	3 years 4 months 24 days		3 years 4 months 24 days
Lease Costs:
Operating Lease Costs, Excluding Short-Term Leases	$ 45		$ 133
Finance Lease Costs:
Amortization of ROU assets	1		3
Interest on lease liabilities	3	$ 3	10	$ 12
Total Finance Lease Costs	4		13
Short-Term Lease Costs	93		250
Variable Lease Costs	3		10
Sublease Income:
Operating lease income	15		41
Variable lease income	4		13
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating cash outflows from operating leases	57		157
Investing cash outflows from operating leases	80		220
Operating cash outflows from finance leases	3		10
Financing cash outflows from finance leases	22	23	63	68
Supplemental Non-Cash Information:
New ROU operating lease assets and liabilities	$ 1	$ 0	$ 11	$ 0

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Segmented Information (Capital Expenditures) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Capital Expenditures	$ 566	$ 523	$ 2,052	$ 1,626
Operating Segments [Member] | Canadian Operations [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	99	174	364	553
Operating Segments [Member] | USA Operations [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	464	345	1,682	1,065
Operating Segments [Member] | Market Optimization [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	2	0	2	0
Corporate & Other [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	$ 1	$ 4	$ 4	$ 8

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Supplementary Information (Non-Cash Activity) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Asset retirement obligation incurred	$ 2.0	$ 3.0	$ 13.0	$ 13.0	$ 17.0
Property, plant and equipment accruals	(80.0)	(20.0)	(33.0)	61.0
Capitalized long-term incentives	1.0	11.0	(31.0)	6.0
Property additions/dispositions	63.0	55.0	66.0	195.0
New ROU operating lease assets and liabilities (See Note 11)	(1.0)	0.0	(11.0)	0.0
Common shares issued under dividend reinvestment plan	0.0	0.0	0.0	0.0	$ 0.6
Newfield Exploration Company [Member]
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Common shares issued in conjunction with the Newfield business combination (See Note 8)	$ 0.0	$ 0.0	$ (3,478.0)	$ 0.0

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2019

Commitments And Contingencies Disclosure [Abstract]

Commitments

The following table outlines the Company’s commitments as at September 30, 2019:

	Expected Future Payments
(undiscounted)	2019		2020		2021		2022		2023		Thereafter		Total
Transportation and Processing	$	197	$	731	$	625	$	594	$	485	$	2,407	$	5,039
Drilling and Field Services		64		24		6		-		-		-		94
Building Leases		4		15		14		11		7		15		66
Total	$	265	$	770	$	645	$	605	$	492	$	2,422	$	5,199

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Pension and Other Post-Employment Benefits (Tables)

9 Months Ended

Sep. 30, 2019

General Discussion Of Pension And Other Postretirement Benefits [Abstract]

Total Benefit Plans Expense Recognized

The Company has recognized total benefit plans expense which includes pension benefits and other post-employment benefits (“OPEB”) for the nine months ended September 30 as follows:

	Pension Benefits				OPEB				Total
	2019		2018		2019		2018		2019		2018
Net Defined Periodic Benefit Cost	$	1	$	1	$	13	$	5	$	14	$	6
Defined Contribution Plan Expense		18		17		-		-		18		17
Total Benefit Plans Expense	$	19	$	18	$	13	$	5	$	32	$	23

Schedule of Net Defined Periodic Benefit Cost

The net defined periodic benefit cost for the nine months ended September 30 is as follows:

	Defined Benefits						OPEB						Total
	2019			2018			2019			2018			2019			2018
Service Cost	$	1		$	1		$	7		$	5		$	8		$	6
Interest Cost		5			5			3			2			8			7
Expected Return on Plan Assets		(5	)		(6	)		-			-			(5	)		(6	)
Amounts Reclassified from Accumulated Other     Comprehensive Income:
Amortization of net actuarial (gains) and losses		-			1			(1	)		(2	)		(1	)		(1	)
Curtailment		-			-			4			-			4			-
Total Net Defined Periodic Benefit Cost (1)	$	1		$	1		$	13		$	5		$	14		$	6

(1) The components of total net defined periodic benefit cost, excluding the service cost component, are included in other (gains) losses, net.

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Financial Instruments and Risk Management

9 Months Ended

Sep. 30, 2019

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Financial Instruments and Risk Management

22. Financial Instruments and Risk Management

A)  Financial Instruments

Encana’s financial assets and liabilities are recognized in cash and cash equivalents, accounts receivable and accrued revenues, other assets, accounts payable and accrued liabilities, risk management assets and liabilities, long-term debt, and other liabilities and provisions.

B)  Risk Management Activities

Encana uses derivative financial instruments to manage its exposure to cash flow variability from commodity prices and fluctuating foreign currency exchange rates. The Company does not apply hedge accounting to any of its derivative financial instruments. As a result, gains and losses from changes in the fair value are recognized in net earnings.

Commodity Price Risk

Commodity price risk arises from the effect that fluctuations in future commodity prices may have on future cash flows. To partially mitigate exposure to commodity price risk, the Company has entered into various derivative financial instruments.  The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors. The Company’s policy is to not use derivative financial instruments for speculative purposes.  

Crude Oil and NGLs - To partially mitigate crude oil and NGL commodity price risk, the Company uses WTI-based contracts such as fixed price contracts, fixed price swaptions, options and costless collars. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

Natural Gas - To partially mitigate natural gas commodity price risk, the Company uses NYMEX-based contracts such as fixed price contracts, fixed price swaptions, options and costless collars. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

Foreign Exchange Risk

Foreign exchange risk arises from changes in foreign currency exchange rates that may affect the fair value or future cash flows of the Company’s financial assets or liabilities. To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts. As at September 30, 2019, Encana has entered into $250 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7516 to C$1, which mature monthly through the remainder of 2019 and $425 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7483 to C$1, which mature monthly throughout 2020.

Risk Management Positions as at September 30, 2019

	Notional Volumes	Term	Average Price		Fair Value
Crude Oil and NGL Contracts			US$/bbl
Fixed Price Contracts
WTI Fixed Price	45.0 Mbbls/d	2019		60.24	$	26
WTI Fixed Price	24.0 Mbbls/d	2020		60.05		74
Propane Fixed Price	3.8 Mbbls/d	2019		35.72		11
Propane Fixed Price	1.8 Mbbls/d	2020		21.00		1
Butane Fixed Price	6.5 Mbbls/d	2019		40.54		10
Ethane Fixed Price	5.3 Mbbls/d	2019		17.23		5
WTI Fixed Price Swaptions (1)	4.0 Mbbls/d	2021		58.00		(4	)
WTI Three-Way Options
Sold call / bought put / sold put	87.5 Mbbls/d	2019	67.72 / 56.47 / 45.86			27
Sold call / bought put / sold put	80.0 Mbbls/d	2020	61.68 / 53.44 / 43.44			54
WTI Costless Collars
Sold call / bought put	43.0 Mbbls/d	2019	65.57 / 56.28			13
Sold call / bought put	15.0 Mbbls/d	2020	68.71 / 50.00			20
Basis Contracts (2)		2019				(19	)
		2020				(34	)
Crude Oil and NGLs Fair Value Position						184
Natural Gas Contracts			US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	687 MMcf/d	2019		2.72		19
NYMEX Fixed Price	653 MMcf/d	2020		2.69		64
NYMEX Fixed Price Swaptions (3)	180 MMcf/d	2021		2.61		(9	)
NYMEX Three-Way Options
Sold call / bought put / sold put	330 MMcf/d	2020	2.72 / 2.60 / 2.25			7
NYMEX Costless Collars
Sold call / bought put	177 MMcf/d	2019	3.05 / 2.89			8
Sold call / bought put	55 MMcf/d	2020	2.88 / 2.50			4
NYMEX Call Options
Sold call	230 MMcf/d	2019		3.75		-
Bought call	230 MMcf/d	2019		3.75		(1	)
Sold call	230 MMcf/d	2020		3.25		4
Basis Contracts (4)		2019				10
		2020				30
		2021				(2	)
		2022 - 2025				(8	)
Other Financial Positions						(1	)
Natural Gas Fair Value Position						125
Net Premiums Received on Unexpired Options						(7	)
Other Derivative Contracts
Fair Value Position						(10	)
Foreign Currency Contracts
Fair Value Position (5)		2019 - 2020				5
Total Fair Value Position and Net Premiums Received					$	297

(1) WTI Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(2) Encana has entered into crude and NGL differential swaps associated with Midland, Magellan East Houston, Belvieu, Conway, Brent, Louisiana Light Sweet and WTI.

(3) NYMEX Fixed Price Swaptions give the counterparty the option to extend certain 2020 Fixed Price swaps to 2021.

(4) Encana has entered into natural gas basis swaps associated with AECO, Dawn, Chicago, Malin, Waha, Houston Ship Channel and NYMEX.

(5) Encana has entered into U.S. dollar denominated fixed-for-floating average currency swaps to protect against fluctuations between the Canadian and U.S. dollars.

Earnings Impact of Realized and Unrealized Gains (Losses) on Risk Management Positions

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	122		$	(77	)	$	301		$	(95	)
Foreign Currency Derivatives:
Foreign exchange		2			1			1			11
	$	124		$	(76	)	$	302		$	(84	)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	(41	)	$	(164	)	$	(385	)	$	(422	)
Foreign Currency Derivatives:
Foreign exchange		(11	)		9			26			(17	)
	$	(52	)	$	(155	)	$	(359	)	$	(439	)
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	81		$	(241	)	$	(84	)	$	(517	)
Foreign Currency Derivatives:
Foreign exchange		(9	)		10			27			(6	)
	$	72		$	(231	)	$	(57	)	$	(523	)

(1) Includes realized gains of $2 million and $5 million for the three and nine months ended September 30, 2019, respectively, (2018 - gains of $2 million and $5 million, respectively) related to other derivative contracts.

(2) Includes unrealized losses of nil and $1 million for the three and nine months ended September 30, 2019, respectively, (2018 - losses of nil and $1 million, respectively) related to other derivative contracts.

Reconciliation of Unrealized Risk Management Positions from January 1 to September 30

	2019						2018
	Fair Value			Total Unrealized Gain (Loss)			Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	654
Change in Fair Value of Contracts in Place at Beginning of Year    and Contracts Entered into During the Period		(57	)	$	(57	)	$	(523	)
Settlement of Other Derivative Contracts		5
Amortization of Option Premiums During the Period		(3	)
Fair Value of Contracts Realized During the Period		(302	)		(302	)		84
Fair Value of Contracts and Net Premiums Received, End of Period	$	297		$	(359	)	$	(439	)

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value.  See Note 21 for a discussion of fair value measurements.

Unrealized Risk Management Positions

	As at		As at
	September 30,		December 31,
	2019		2018
Risk Management Assets
Current	$	284	$	554
Long-term		47		161
		331		715
Risk Management Liabilities
Current		10		25
Long-term		14		22
		24		47
Other Derivative Contracts
Current in accounts payable and accrued liabilities		2		4
Long-term in other liabilities and provisions		8		10
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	297	$	654

C)  Credit Risk

Credit risk arises from the potential that the Company may incur a loss if a counterparty to a financial instrument fails to meet its obligation in accordance with agreed terms. While exchange-traded contracts are subject to nominal credit risk due to the financial safeguards established by the NYSE and the TSX, over-the-counter traded contracts expose Encana to counterparty credit risk. This credit risk exposure is mitigated through the use of credit policies approved by the Board of Directors governing the Company’s credit portfolio including credit practices that limit transactions according to counterparties’ credit quality. Mitigation strategies may include master netting arrangements, requesting collateral and/or transacting credit derivatives. The Company executes commodity derivative financial instruments under master agreements that have netting provisions that provide for offsetting payables against receivables. As a result of netting provisions, the Company’s maximum exposure to loss under derivative financial instruments due to credit risk is limited to the net amounts due from the counterparties under the derivative contracts, as disclosed in Note 21. As at September 30, 2019, the Company had no significant credit derivatives in place and held no collateral.

As at September 30, 2019, cash equivalents include high-grade, short-term securities, placed primarily with financial institutions and companies with strong investment grade ratings. Any foreign currency agreements entered into are with major financial institutions that have investment grade credit ratings.  

A substantial portion of the Company’s accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risks. As at September 30, 2019, approximately 96 percent (97 percent as at December 31, 2018) of Encana’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

As at September 30, 2019, Encana had three counterparties whose net settlement position individually accounted for more than 10 percent of the fair value of the outstanding in-the-money net risk management contracts by counterparty. These counterparties accounted for 20 percent, 13 percent and 13 percent of the fair value of the outstanding in-the-money net risk management contracts. As at December 31, 2018, Encana had four counterparties whose net settlement position accounted for 30 percent, 13 percent, 12 percent and 10 percent of the fair value of the outstanding in-the-money net risk management contracts.

During 2015 and 2017, Encana entered into agreements resulting from divestitures, which may require Encana to fulfill certain payment obligations on the take or pay volume commitments assumed by the purchasers. The circumstances that would require Encana to perform under the agreements include events where a purchaser fails to make payment to the guaranteed party and/or a purchaser is subject to an insolvency event. The agreements have remaining terms from two to five years with a fair value recognized of $10 million as at September 30, 2019 ($14 million as at December 31, 2018). The

maximum potential amount of undiscounted future payments is $154 million as at September 30, 2019, and is considered unlikely.

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Recent Accounting Pronouncements (Tables)

9 Months Ended

Sep. 30, 2019

New Accounting Pronouncements And Changes In Accounting Principles [Abstract]

Schedule of Impacts from Recognizing Operating Leases on Condensed Consolidated Balance Sheet

The impact from recognizing operating leases on Encana’s Condensed Consolidated Balance Sheet is as follows:

										Restated
	Reported as at			Impact of						Balances as at
(US$ millions)	December 31, 2018			Adoption						January 1, 2019
Property, Plant and Equipment, at cost:
Oil and natural gas properties, based on full cost accounting
Proved properties	$	41,241		$	-					$	41,241
Unproved properties		3,730			-						3,730
Other		2,122			(1,261	)					861
Property, plant and equipment		47,093			(1,261	)					45,832
Less: accumulated depreciation, depletion and amortization		(38,121	)		128						(37,993	)
Property, plant and equipment, net		8,972			(1,133	)		(1	)		7,839
Other Assets		147			1,015		(1), (2		)		1,162
Deferred Income Taxes		835			(28	)					807
Total Assets		15,344			(146	)					15,198
Current Liabilities
Accounts payable and accrued liabilities		1,490			(12	)		(1	)		1,478
Current portion of operating lease liabilities		-			67			(2	)		67
Income tax payable		1			-						1
Risk management		25			-						25
Current portion of long-term debt		500			-						500
		2,016			55						2,071
Operating Lease Liabilities		-			948			(2	)		948
Other Liabilities and Provisions		1,769			(1,224	)		(1	)		545
Total Liabilities		7,897			(221	)					7,676
Retained Earnings		435			75			(1	)		510
Total Shareholders’ Equity		7,447			75						7,522
Total Liabilities and Shareholders’ Equity	$	15,344		$	(146	)				$	15,198

(1) In accordance with Topic 840, Encana accounted for The Bow office building as a failed sales leaseback and at the effective date of January 1, 2019, The Bow office building remained as such. On transition to Topic 842, Encana re-assessed whether a sale would have occurred at the effective date and determined that a sale occurred. As a result, Encana derecognized the asset and financing liability resulting from the failed sale leaseback transaction measured under Topic 840, recognizing the difference as an adjustment to retained earnings in the Condensed Consolidated Balance Sheet. Upon transition to Topic 842, The Bow office building was determined to be an operating lease for which a ROU asset and corresponding liability was recorded at the present value of remaining minimum lease payments.

(2) ROU assets for operating leases were measured at the amount equal to the lease liability and the unamortized balance of any lease incentives prior to the transition date. The lease liabilities for operating leases were measured at the present value of the remaining minimum lease payments outstanding as at January 1, 2019.

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Foreign Exchange (Gain) Loss, Net (Tables)

9 Months Ended

Sep. 30, 2019

Foreign Currency [Abstract]

Foreign Exchange (Gain) Loss, Net

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	68		$	(74	)	$	(117	)	$	138
Translation of U.S. dollar risk management contracts issued from Canada		5			(3	)		(13	)		7
Translation of intercompany notes		(24	)		54			119			11
		49			(23	)		(11	)		156
Foreign Exchange on Settlements of:
U.S. dollar financing debt issued from Canada		(10	)		-			(22	)		1
U.S. dollar risk management contracts issued from Canada		(2	)		(1	)		(1	)		(11	)
Intercompany notes		(8	)		(1	)		(31	)		(48	)
Other Monetary Revaluations		1			2			3			(5	)
	$	30		$	(23	)	$	(62	)	$	93

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Acquisitions And Divestitures

9 Months Ended

Sep. 30, 2019

Acquisitions And Divestitures [Abstract]

Acquisitions And Divestitures

9. Acquisitions and Divestitures

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Acquisitions
Canadian Operations	$	-		$	15		$	-		$	17
USA Operations		25			-			66			-
Total Acquisitions		25			15			66			17
Divestitures
Canadian Operations		-			2			-			(55	)
USA Operations		(171	)		(26	)		(177	)		(34	)
Total Divestitures		(171	)		(24	)		(177	)		(89	)
Net Acquisitions & (Divestitures)	$	(146	)	$	(9	)	$	(111	)	$	(72	)

Acquisitions

For the nine months ended September 30, 2019, acquisitions in the Canadian and USA Operations were nil (2018 - $17 million) and $66 million (2018 - nil), respectively, which primarily included seismic purchases, water rights and purchases with oil and liquids rich potential.

Divestitures

For the three and nine months ended September 30, 2019, divestitures in the USA Operations were $171 million and $177 million, respectively, which primarily included the sale of the Company’s Arkoma natural gas assets. For the three and nine months ended September 30, 2018, divestitures in the USA Operations were $26 million and $34 million, respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

During the nine months ended September 30, 2018, divestitures in the Canadian Operations were $55 million, which primarily included the sale of certain Pipestone assets located in Alberta.

Amounts received from the Company’s divestiture transactions have been deducted from the respective Canadian and U.S. full cost pools.

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Interest

9 Months Ended

Sep. 30, 2019

Interest Expense [Abstract]

Interest

5. Interest

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Interest Expense on:
Debt	$	93	$	67	$	268	$	200
The Bow office building (See Note 2)		-		16		-		48
Finance leases (See Note 11)		3		3		10		12
Other		3		6		7		5
	$	99	$	92	$	285	$	265

Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease with lease costs recognized in administrative expense. Previously, payments related to The Bow were recognized as interest expense and principal repayments. See Notes 2 and 11 for further information.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

Fair Value Measurements

21. Fair Value Measurements

The fair values of cash and cash equivalents, accounts receivable and accrued revenues, and accounts payable and accrued liabilities approximate their carrying amounts due to the short-term maturity of those instruments. The fair values of restricted cash and marketable securities included in other assets approximate their carrying amounts due to the nature of the instruments held.

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note 22. These items are carried at fair value in the Condensed Consolidated Balance Sheet and are classified within the three levels of the fair value hierarchy in the following tables. There have been no significant transfers between the hierarchy levels during the period.

Fair value changes and settlements for amounts related to risk management assets and liabilities are recognized in revenues and foreign exchange gains and losses according to their purpose.

As at September 30, 2019	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	256	$	92	$	348	$	(68	)	$	280
Long-term assets		-		59		22		81		(35	)		46
Foreign Currency Derivatives:
Current assets		-		4		-		4		-			4
Long-term assets		-		1		-		1		-			1
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	78	$	-	$	78	$	(68	)	$	10
Long-term liabilities		-		49		-		49		(35	)		14
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	2	$	-	$	2	$	-		$	2
Long-term in other liabilities and provisions		-		8		-		8		-			8

As at December 31, 2018	Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting (1)			Carrying Amount
Risk Management Assets
Commodity Derivatives:
Current assets	$	-	$	492	$	139	$	631	$	(77	)	$	554
Long-term assets		-		177		-		177		(16	)		161
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	81	$	-	$	81	$	(77	)	$	4
Long-term liabilities		-		38		-		38		(16	)		22
Foreign Currency Derivatives:
Current liabilities		-		21		-		21		-			21
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	4	$	-	$	4	$	-		$	4
Long-term in other liabilities and provisions		-		10		-		10		-			10

(1) Netting to offset derivative assets and liabilities where the legal right and intention to offset exists, or where counterparty master netting arrangements contain provisions for net settlement.

The Company’s Level 1 and Level 2 risk management assets and liabilities consist of commodity fixed price contracts, fixed price swaptions, NYMEX costless collars, NYMEX call options, NYMEX three-way options, foreign currency swaps and basis swaps with terms to 2025. Level 2 also includes financial guarantee contracts as discussed in Note 22. The fair values of these contracts are based on a market approach and are estimated using inputs which are either directly or indirectly observable from active markets, such as exchange and other published prices, broker quotes and observable trading activity throughout the term of the instruments.  

Level 3 Fair Value Measurements

As at September 30, 2019, the Company’s Level 3 risk management assets and liabilities consist of WTI three-way options and WTI costless collars with terms to 2020. The WTI three-way options are a combination of a sold call, bought put and a sold put. The WTI costless collars are a combination of a sold call and a bought put. These contracts allow the Company to participate in the upside of commodity prices to the ceiling of the call option and provide the Company with complete (collars) or partial (three-way) downside price protection through the put options. The fair values of the WTI three-way options and WTI costless collars are based on the income approach and are modelled using observable and unobservable inputs such as implied volatility. The unobservable inputs are obtained from third parties whenever possible and reviewed by the Company for reasonableness.

A summary of changes in Level 3 fair value measurements for the nine months ended September 30 is presented below:

	Risk Management
	2019			2018
Balance, Beginning of Year	$	139		$	(51	)
Total Gains (Losses)		24			(177	)
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances		-			-
Settlements		(49	)		80
Transfers Out of Level 3 (1)		-			-
Balance, End of Period	$	114		$	(148	)
Change in Unrealized Gains (Losses) Related to    Assets and Liabilities Held at End of Period	$	83		$	(136	)

(1) The Company’s policy is to recognize transfers out of Level 3 on the date of the event of change in circumstances that caused the transfer.

Quantitative information about unobservable inputs used in Level 3 fair value measurements is presented below:

	Valuation Technique	Unobservable Input	As at September 30, 2019	As at December 31, 2018
Risk Management - WTI Options	Option Model	Implied Volatility	22% - 61%	29% - 73%

A 10 percent increase or decrease in implied volatility for the WTI options would cause an approximate corresponding $9 million ($6 million as at December 31, 2018) increase or decrease to net risk management assets and liabilities.

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Condensed Consolidated Statement Of Changes In Shareholders' Equity (unaudited) - USD ($) $ in Millions	Total	Substantial Issuer Bid [Member]	Normal Course Issuer Bid [Member]	Share Capital [Member]	Share Capital [Member] Substantial Issuer Bid [Member]	Share Capital [Member] Normal Course Issuer Bid [Member]	Paid In Surplus [Member]	Paid In Surplus [Member] Substantial Issuer Bid [Member]	Retained Earnings (Accumulated Deficit) [Member]	Retained Earnings (Accumulated Deficit) [Member] Normal Course Issuer Bid [Member]	Accumulated Other Comprehensive Income [Member]
Balance, Beginning of Period at Dec. 31, 2017	$ 6,728.0			$ 4,757.0			$ 1,358.0		$ (429.0)		$ 1,042.0
Net Earnings (Loss)	39.0								39.0
Dividends on Common Shares	(43.0)								(43.0)
Common Shares Purchased			$ (250.0)			$ (102.0)				$ (148.0)
Common Shares Issued Under Dividend Reinvestment Plan	0.0			0.0
Other Comprehensive Income (Loss)	20.0										20.0
Balance, End of Period at Sep. 30, 2018	6,494.0			4,655.0			1,358.0		(581.0)		1,062.0
Balance, Beginning of Period at Dec. 31, 2017	6,728.0			4,757.0			1,358.0		(429.0)		1,042.0
Common Shares Purchased	(102.0)					(102.0)				(148.0)
Common Shares Issued Under Dividend Reinvestment Plan	0.6
Common Shares Issued	0.0
Balance, End of Period at Dec. 31, 2018	7,447.0			4,656.0			1,358.0		435.0		998.0
Balance, Beginning of Period at Jun. 30, 2018	6,497.0			4,674.0			1,358.0		(575.0)		1,040.0
Net Earnings (Loss)	39.0								39.0
Dividends on Common Shares	(14.0)								(14.0)
Common Shares Purchased			(50.0)			(19.0)				(31.0)
Common Shares Issued Under Dividend Reinvestment Plan	0.0			0.0
Other Comprehensive Income (Loss)	22.0										22.0
Balance, End of Period at Sep. 30, 2018	6,494.0			4,655.0			1,358.0		(581.0)		1,062.0
Balance, Beginning of Period at Dec. 31, 2018	7,447.0			4,656.0			1,358.0		435.0		998.0
Net Earnings (Loss)	240.0								240.0
Dividends on Common Shares	(77.0)			0.0					(77.0)
Common Shares Purchased	(1,073.0)	$ (213.0)	$ (1,037.0)		$ (257.0)	$ (816.0)		$ 44.0		$ (221.0)
Common Shares Issued Under Dividend Reinvestment Plan	0.0
Common Shares Issued	3,478.0			3,478.0
Other Comprehensive Income (Loss)	8.0										8.0
Impact of Adoption of Topic 842	75.0								75.0
Balance, End of Period at Sep. 30, 2019	9,921.0			7,061.0			1,402.0		452.0		1,006.0
Balance, Beginning of Period at Jun. 30, 2019	10,015.0			7,318.0			1,358.0		327.0		1,012.0
Net Earnings (Loss)	149.0								149.0
Dividends on Common Shares	(24.0)			0.0					(24.0)
Common Shares Purchased		$ (213.0)			$ (257.0)			$ 44.0
Common Shares Issued Under Dividend Reinvestment Plan	0.0
Other Comprehensive Income (Loss)	(6.0)										(6.0)
Balance, End of Period at Sep. 30, 2019	$ 9,921.0			$ 7,061.0			$ 1,402.0		$ 452.0		$ 1,006.0

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Variable Interest Entities

9 Months Ended

Sep. 30, 2019

Variable Interest Entity Not Primary Beneficiary Disclosures [Abstract]

Variable Interest Entities

17. Variable Interest Entities

Veresen Midstream Limited Partnership

Veresen Midstream Limited Partnership (“VMLP”) provides gathering, compression and processing services under various agreements related to the Company’s development of liquids and natural gas production in the Montney play. As at September 30, 2019, VMLP provides approximately 1,206 MMcf/d of natural gas gathering and compression and 939 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from up to 12 to 26 years and have various renewal terms providing up to a potential maximum of 10 years.

Encana has determined that VMLP is a VIE and that Encana holds variable interests in VMLP. Encana is not the primary beneficiary as the Company does not have the power to direct the activities that most significantly impact VMLP’s economic performance. These key activities relate to the construction, operation, maintenance and marketing of the assets owned by VMLP. The variable interests arise from certain terms under the various long-term service agreements and include: i) a take or pay for volumes in certain agreements; ii) an operating fee of which a portion can be converted into a fixed fee once

VMLP assumes operatorship of certain assets; and iii) a potential payout of minimum costs in certain agreements. The potential payout of minimum costs will be assessed in the eighth year of the assets’ service period and is based on whether there is an overall shortfall of total system cash flows from natural gas gathered and compressed under certain agreements. The potential payout amount can be reduced in the event VMLP markets unutilized capacity to third-party users. Encana is not required to provide any financial support or guarantees to VMLP.

As a result of Encana’s involvement with VMLP, the maximum total exposure, which represents the potential exposure to Encana in the event the assets under the agreements are deemed worthless, is estimated to be $2,359 million as at September 30, 2019. The estimate comprises the take or pay volume commitments and the potential payout of minimum costs. The take or pay volume commitments associated with certain gathering and processing assets are included in Note 24 under Transportation and Processing. The potential payout requirement is highly uncertain as the amount is contingent on future production estimates, pace of development and the amount of capacity contracted to third parties. As at September 30, 2019, there were no accounts payable and accrued liabilities outstanding related to the take or pay commitment.

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Other Liabilities And Provisions

9 Months Ended

Sep. 30, 2019

Other Liabilities Disclosure [Abstract]

Other Liabilities And Provisions

13. Other Liabilities and Provisions

	As at		As at
	September 30,		December 31,
	2019		2018
The Bow Office Building	$	-	$	1,224
Finance Lease Obligations (See Note 11)		144		211
Unrecognized Tax Benefits		172		167
Pensions and Other Post-Employment Benefits		170		105
Long-Term Incentive Costs (See Note 19)		29		34
Other Derivative Contracts (See Notes 21, 22)		8		10
Other		25		18
	$	548	$	1,769

Upon adoption of Topic 842 on January 1, 2019, The Bow office building was determined to be an operating lease. See Notes 2 and 11 for further information.

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Condensed Consolidated Statement Of Earnings (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues
Product and service revenues	$ 1,771	$ 1,488	$ 5,191	$ 4,025
Gains (losses) on risk management, net	81	(241)	(84)	(517)
Sublease revenues	19	15	54	50
Total Revenues	1,871	1,262	5,161	3,558
Operating Expenses
Production, mineral and other taxes	66	45	187	109
Transportation and processing	398	278	1,148	799
Operating	193	124	545	372
Purchased product	264	282	784	803
Depreciation, depletion and amortization	545	349	1,454	924
Accretion of asset retirement obligation	9	8	28	24
Administrative	81	57	389	187
Total Operating Expenses	1,556	1,143	4,535	3,218
Operating Income (Loss)	315	119	626	340
Other (Income) Expenses
Interest	99	92	285	265
Foreign exchange (gain) loss, net	30	(23)	(62)	93
(Gain) loss on divestitures, net	(5)	0	(4)	(4)
Other (gains) losses, net	(1)	5	24	2
Total Other (Income) Expenses	123	74	243	356
Net Earnings (Loss) Before Income Tax	192	45	383	(16)
Income tax expense (recovery)	43	6	143	(55)
Net Earnings (Loss)	$ 149	$ 39	$ 240	$ 39
Net Earnings (Loss) per Common Share
Basic & Diluted	$ 0.11	$ 0.04	$ 0.18	$ 0.04
Weighted Average Common Shares Outstanding (millions)
Basic & Diluted	1,322.8	955.1	1,308.4	962.2

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Business Combination (Narrative) (Details) - Newfield Exploration Company [Member] shares in Millions, $ in Millions			8 Months Ended	9 Months Ended
		Feb. 13, 2019 USD ($) shares	Sep. 30, 2019 USD ($)	Sep. 30, 2019 USD ($)
Business Acquisition [Line Items]
Business acquisition completed date		Feb. 13, 2019
Business Acquisition Stock Exchange Ratio		2.6719
Payments to acquire businesses		$ 3,483
Business acquisition, number of shares issued | shares		543.4
Business acquisition, payment in cash	[1]	$ 5
Business acquisition transaction costs		33
Business acquisition assets acquired generated revenues			$ 1,485
Business acquisition, assets acquired net earnings			$ 69
Business acquisition related costs				$ 71
Business acquisition severance payments				$ 134
Senior Notes [Member]
Business Acquisition [Line Items]
Business acquisition, senior notes remain outstanding		$ 2,450

[1] The fair value was based on a price of $6.50 per notional unit which was determined using a volume-weighted average of the trading price of Encana common shares on the NYSE on each of the five consecutive trading days ending on the trading day that was three trading days prior to February 13, 2019.

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Compensation Plans (Schedule of Share-based Compensation, Activity) (Details) shares in Thousands	9 Months Ended
	Sep. 30, 2019 shares
Tandem Stock Appreciation Rights (TSARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	1,244
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	1,718
Performance Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	7,833
Deferred Share Units (DSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	111
Restricted Share Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	11,004

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Compensation Plans (Schedule of Weighted Average Assumptions Used to Fair Value Share Units) (Details)	9 Months Ended
	Sep. 30, 2019 $ / shares	Sep. 30, 2018 $ / shares	Sep. 30, 2019 $ / shares	Sep. 30, 2018 $ / shares
United States Of America Dollars [Member]
Fair Value Assumptions, Risk Free Interest Rate	1.58%	2.18%
Fair Value Assumption Dividend Yield	1.63%	0.46%
Fair Value Assumptions, Expected Volatility Rate	44.14%	55.44%
Fair Value Assumptions, Expected Term	2 years 10 months 24 days	1 year 7 months 6 days
Market Share Price	$ 4.60	$ 13.11
Canadian Dollar [Member]
Fair Value Assumptions, Risk Free Interest Rate	1.58%	2.18%
Fair Value Assumption Dividend Yield	1.64%	0.46%
Fair Value Assumptions, Expected Volatility Rate	42.77%	51.90%
Fair Value Assumptions, Expected Term	2 years 7 months 6 days	2 years
Market Share Price			$ 6.07	$ 16.93

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Interest (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Interest Expense [Abstract]
Interest Expense on Debt	$ 93	$ 67	$ 268	$ 200
The Bow office building (See Note 2)	0	16	0	48
Finance leases (See Note 11)	3	3	10	12
Other	3	6	7	5
Interest	$ 99	$ 92	$ 285	$ 265

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Business Combination (Tables) - Newfield Exploration Company [Member]

9 Months Ended

Sep. 30, 2019

Schedule of Preliminary Purchase Price Allocations

The transaction was accounted for under the acquisition method, which requires that the assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date, with any excess of the purchase price over the estimated fair value of identified net assets acquired recorded as goodwill. The purchase price allocation represents the consideration paid and the fair values of the assets acquired, and liabilities assumed as of the acquisition date. The purchase price allocation is subject to change based on information that may not yet be available, including, the valuation of any pre-acquisition contingencies, final appraisals and tax returns that provide the underlying tax basis of the net assets and liabilities acquired and uncertain tax positions. The Company expects the purchase price allocation to be completed within 12 months following the acquisition date, during which time the value of the net assets and liabilities acquired may be revised as appropriate.

Preliminary Purchase Price Allocation
Consideration:
Fair value of Encana's common shares issued (1)	$	3,478
Fair value of Newfield liability awards paid in cash (2)		5
Total Consideration	$	3,483
Assets Acquired:
Cash and cash equivalents	$	46
Accounts receivable and accrued revenues		486
Other current assets		50
Proved properties		5,903
Unproved properties		838
Other property, plant and equipment		22
Restricted cash		53
Other assets		105
Goodwill (3)		22
Liabilities Assumed:
Accounts payable and accrued liabilities (3)		(795	)
Long-term debt		(2,603	)
Operating lease liabilities		(76	)
Other long-term liabilities (3)		(61	)
Asset retirement obligation		(184	)
Deferred income taxes (3)		(323	)
Total Purchase Price	$	3,483

(1) The fair value was based on the NYSE closing price of the Encana common shares of $6.40 on February 13, 2019.

(2) The fair value was based on a price of $6.50 per notional unit which was determined using a volume-weighted average of the trading price of Encana common shares on the NYSE on each of the five consecutive trading days ending on the trading day that was three trading days prior to February 13, 2019.

(3) Since the completion of the business combination on February 13, 2019, additional information related to pre-acquisition liabilities and contingencies was obtained resulting in a measurement period adjustment. Changes in the fair value estimates comprised an increase in other liabilities of $12 million, of which the total liability is presented in accounts payable and accrued liabilities, a decrease in deferred tax liabilities of $3 million and a corresponding increase in goodwill of $9 million.

Schedule of Unaudited Pro Forma Financial Information

The following unaudited pro forma financial information combines the historical financial results of Encana with Newfield and has been prepared as though the acquisition had occurred on January 1, 2018. The pro forma information is not intended to reflect the actual results of operations that would have occurred if the business combination had been completed at the date indicated. In addition, the pro forma information is not intended to be a projection of Encana’s results of operations for any future period.

Additionally, pro forma earnings were adjusted to exclude acquisition-related costs incurred of approximately $71 million and severance payments made to employees which totaled $134 million for the nine months ended September 30, 2019. The pro forma financial information does not include any cost savings or other synergies that may result from the Merger or any estimated costs that have been or will be incurred to integrate the assets.

For the nine months ended September 30, (US$ millions, except per share amounts)	2019		2018
Revenues	$	5,440	$	5,215
Net Earnings (Loss)	$	376	$	369
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.29	$	0.25

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Financial Instruments and Risk Management (Reconciliation of Unrealized Risk Management Positions) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative [Line Items]
Fair Value of Contracts, Beginning of Year			$ 654
Amortization of Option Premiums During the Period			(3)
Fair Value of Contracts Realized During the Period	$ (124)	$ 76	(302)	$ 84
Fair Value of Contracts and Net Premiums Received, End of Period	297		297
Unrealized Gain (Loss) on Derivatives	$ (52)	$ (155)	(359)	(439)
Commodity Contract [Member]
Derivative [Line Items]
Increase (Decrease) in Derivative Assets and Liabilities			(57)	$ (523)
Other Derivative Contracts [Member]
Derivative [Line Items]
Increase (Decrease) in Derivative Assets and Liabilities			$ 5

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Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2019

Debt Disclosure [Abstract]

Schedule Of Long-Term Debt

	As at			As at
	September 30,			December 31,
	2019			2018
U.S. Dollar Denominated Debt
Revolving credit and term loan borrowings	$	740		$	-
U.S. Unsecured Notes:
6.50% due May 15, 2019		-			500
3.90% due November 15, 2021		600			600
5.75% due January 30, 2022 (See Note 8)		750			-
5.625% due July 1, 2024  (See Note 8)		1,000			-
5.375% due January 1, 2026  (See Note 8)		700			-
8.125% due September 15, 2030		300			300
7.20% due November 1, 2031		350			350
7.375% due November 1, 2031		500			500
6.50% due August 15, 2034		750			750
6.625% due August 15, 2037		462			462
6.50% due February 1, 2038		505			505
5.15% due November 15, 2041		244			244
Total Principal		6,901			4,211
Increase in Value of Debt Acquired		157			22
Unamortized Debt Discounts and Issuance Costs		(34	)		(35	)
Total Long-Term Debt	$	7,024		$	4,198
Current Portion	$	-		$	500
Long-Term Portion		7,024			3,698
	$	7,024		$	4,198

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Pension and Other Post-Employment Benefits (Defined Periodic Pension And OPEB Expense) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Service Cost	$ 8	$ 6
Interest Cost	8	7
Expected Return on Plan Assets	(5)	(6)
Amortization of net actuarial (gains) and losses	(1)	(1)
Curtailment	4	0
Total Net Defined Periodic Benefit Cost	14	6
Defined Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost	1	1
Interest Cost	5	5
Expected Return on Plan Assets	(5)	(6)
Amortization of net actuarial (gains) and losses	0	1
Curtailment	0	0
Total Net Defined Periodic Benefit Cost	1	1
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost	7	5
Interest Cost	3	2
Expected Return on Plan Assets	0	0
Amortization of net actuarial (gains) and losses	(1)	(2)
Curtailment	4	0
Total Net Defined Periodic Benefit Cost	$ 13	$ 5

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Accumulated Other Comprehensive Income (Tables)

9 Months Ended

Sep. 30, 2019

Accumulated Other Comprehensive Income Loss Net Of Tax [Abstract]

Schedule of Accumulated Other Comprehensive Income

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019			2018		2019			2018
Foreign Currency Translation Adjustment
Balance, Beginning of Period	$	1,014		$	1,028	$	976		$	1,029
Change in Foreign Currency Translation Adjustment		(6	)		22		32			21
Balance, End of Period	$	1,008		$	1,050	$	1,008		$	1,050
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Period	$	(2	)	$	12	$	22		$	13
Plan Amendment		-			-		(29	)		-
Income Taxes		-			-		6			-
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 20)		-			-		(1	)		(1	)
Income Taxes		-			-		-			-
Balance, End of Period	$	(2	)	$	12	$	(2	)	$	12
Total Accumulated Other Comprehensive Income	$	1,006		$	1,062	$	1,006		$	1,062

During the nine months ended September 30, 2019, Encana amended the other post-employment benefits arrangements in conjunction with the integration of the Newfield business acquired. The plan amendment resulted in an increase to pension liabilities with a corresponding loss recognized in other comprehensive income.

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Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Ten Percent Change in Implied Volatility [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Increase (Decrease) in Risk Management Assets and Liabilities	$ 9	$ 6

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Condensed Consolidated Statement Of Changes In Shareholders' Equity (Parenthetical) (unaudited) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement Of Stockholders Equity [Abstract]
Dividends on Common Shares, per share	$ 0.01875	$ 0.015	$ 0.05625	$ 0.045

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Accumulated Other Comprehensive Income

9 Months Ended

Sep. 30, 2019

Accumulated Other Comprehensive Income Loss Net Of Tax [Abstract]

Accumulated Other Comprehensive Income

16. Accumulated Other Comprehensive Income

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019			2018		2019			2018
Foreign Currency Translation Adjustment
Balance, Beginning of Period	$	1,014		$	1,028	$	976		$	1,029
Change in Foreign Currency Translation Adjustment		(6	)		22		32			21
Balance, End of Period	$	1,008		$	1,050	$	1,008		$	1,050
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Period	$	(2	)	$	12	$	22		$	13
Plan Amendment		-			-		(29	)		-
Income Taxes		-			-		6			-
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 20)		-			-		(1	)		(1	)
Income Taxes		-			-		-			-
Balance, End of Period	$	(2	)	$	12	$	(2	)	$	12
Total Accumulated Other Comprehensive Income	$	1,006		$	1,062	$	1,006		$	1,062

During the nine months ended September 30, 2019, Encana amended the other post-employment benefits arrangements in conjunction with the integration of the Newfield business acquired. The plan amendment resulted in an increase to pension liabilities with a corresponding loss recognized in other comprehensive income.

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Long-Term Debt

9 Months Ended

Sep. 30, 2019

Debt Disclosure [Abstract]

Long-Term Debt

12. Long-Term Debt

	As at			As at
	September 30,			December 31,
	2019			2018
U.S. Dollar Denominated Debt
Revolving credit and term loan borrowings	$	740		$	-
U.S. Unsecured Notes:
6.50% due May 15, 2019		-			500
3.90% due November 15, 2021		600			600
5.75% due January 30, 2022 (See Note 8)		750			-
5.625% due July 1, 2024  (See Note 8)		1,000			-
5.375% due January 1, 2026  (See Note 8)		700			-
8.125% due September 15, 2030		300			300
7.20% due November 1, 2031		350			350
7.375% due November 1, 2031		500			500
6.50% due August 15, 2034		750			750
6.625% due August 15, 2037		462			462
6.50% due February 1, 2038		505			505
5.15% due November 15, 2041		244			244
Total Principal		6,901			4,211
Increase in Value of Debt Acquired		157			22
Unamortized Debt Discounts and Issuance Costs		(34	)		(35	)
Total Long-Term Debt	$	7,024		$	4,198
Current Portion	$	-		$	500
Long-Term Portion		7,024			3,698
	$	7,024		$	4,198

As at September 30, 2019, total long-term debt had a carrying value of $7,024 million and a fair value of $7,825 million (as at December 31, 2018 - carrying value of $4,198 million and a fair value of $4,511 million). The estimated fair value of long-term borrowings is categorized within Level 2 of the fair value hierarchy and has been determined based on market information of long-term debt with similar terms and maturity, or by discounting future payments of interest and principal at interest rates expected to be available to the Company at period end.

As at September 30, 2019, the Company had outstanding commercial paper of $740 million maturing at various dates with a weighted average interest rate of approximately 2.63 percent. These amounts are supported, and Management expects that they will continue to be supported, by revolving credit facilities that have no repayment requirements within the next year and which expire in 2022.

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Condensed Consolidated Statement Of Comprehensive Income (unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement Of Income And Comprehensive Income [Abstract]
Net Earnings (Loss)	$ 149	$ 39	$ 240	$ 39
Other Comprehensive Income (Loss), Net of Tax
Foreign currency translation adjustment	(6)	22	32	21
Pension and other post-employment benefit plans	0	0	(24)	(1)
Other Comprehensive Income (Loss)	(6)	22	8	20
Comprehensive Income (Loss)	$ 143	$ 61	$ 248	$ 59

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Pension and Other Post-Employment Benefits

9 Months Ended

Sep. 30, 2019

General Discussion Of Pension And Other Postretirement Benefits [Abstract]

Pension and Other Post-Employment Benefits

20. Pension and Other Post-Employment Benefits

The Company has recognized total benefit plans expense which includes pension benefits and other post-employment benefits (“OPEB”) for the nine months ended September 30 as follows:

	Pension Benefits				OPEB				Total
	2019		2018		2019		2018		2019		2018
Net Defined Periodic Benefit Cost	$	1	$	1	$	13	$	5	$	14	$	6
Defined Contribution Plan Expense		18		17		-		-		18		17
Total Benefit Plans Expense	$	19	$	18	$	13	$	5	$	32	$	23

Of the total benefit plans expense, $20 million (2018 - $17 million) was included in operating expense and $6 million (2018 - $6 million) was included in administrative expense. Excluding service costs, net defined periodic benefit costs of $6 million (2018 - nil) were recorded in other (gains) losses, net.

The net defined periodic benefit cost for the nine months ended September 30 is as follows:

	Defined Benefits						OPEB						Total
	2019			2018			2019			2018			2019			2018
Service Cost	$	1		$	1		$	7		$	5		$	8		$	6
Interest Cost		5			5			3			2			8			7
Expected Return on Plan Assets		(5	)		(6	)		-			-			(5	)		(6	)
Amounts Reclassified from Accumulated Other     Comprehensive Income:
Amortization of net actuarial (gains) and losses		-			1			(1	)		(2	)		(1	)		(1	)
Curtailment		-			-			4			-			4			-
Total Net Defined Periodic Benefit Cost (1)	$	1		$	1		$	13		$	5		$	14		$	6

(1) The components of total net defined periodic benefit cost, excluding the service cost component, are included in other (gains) losses, net.

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Income Taxes (Narrative) (Details) - USD ($) $ in Millions				3 Months Ended		6 Months Ended		9 Months Ended
	Jan. 01, 2022	Jan. 01, 2021	Jan. 01, 2020	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Jun. 30, 2019	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Line Items]
Deferred income taxes				$ 44	$ 6			$ 140	$ 6
Effective Tax Rates				22.40%	13.30%			37.30%	343.80%
Alberta [Member]
Income Tax Disclosure [Line Items]
Statutory Tax Rate							12.00%
Effect of legislative changes								$ 55
Alberta [Member] | Scenario Plan [Member]
Income Tax Disclosure [Line Items]
Statutory Tax Rate	8.00%					11.00%
Provincial tax rate reduction from Job Creation Tax Cut	1.00%	1.00%	1.00%
Canada [Member]
Income Tax Disclosure [Line Items]
Deferred income taxes				$ (12)	$ 19			$ 22	$ (9)
Statutory Tax Rate								26.60%	27.00%

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Compensation Plans (Liability For Share-Based Payment Transactions) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Liability for Unvested Cash-Settled Share-Based Payment Transactions	$ 53	$ 148
Liability for Vested Cash-Settled Share-Based Payment Transactions	12	17
Liability for Cash-Settled Share-Based Payment Transactions	$ 65	$ 165

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Restructuring Charges (Schedule of Change in Restructuring Accrual) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Restructuring Charges [Abstract]
Outstanding Restructuring Accrual, Beginning of Year			$ 0	$ 0	$ 0
Restructuring Expenses Incurred	$ 4	$ 0	134	$ 0	0
Restructuring Costs Paid			(130)		0
Outstanding Restructuring Accrual, End of Period	$ 4		$ 4		$ 0

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Revenue from Contracts with Customers (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Revenue From Contract With Customer [Abstract]
Contract with Customer, Asset, Net	$ 0	$ 0
Contract with Customer, Liability	0	0
Receivables & Accrued Revenues from Contracts with Customers	980	$ 662
Revenue, Remaining Performance Obligation	$ 0

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Fair Value Measurements (Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Net, Current	$ 284		$ 554
Risk Management Assets, Net, Long-term	47		161
Risk Management Liabilities, Net, Current	10	$ 25	25
Risk Management Liabilities, Net, Long-term	14		22
Guarantor Obligations, Current Carrying Value	10		14
Accounts Payable and Accrued Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	2		4
Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	8		10
Commodity Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	348		631
Risk Management Assets, Gross Liabilities	(68)		(77)
Risk Management Assets, Net, Current	280		554
Commodity Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	81		177
Risk Management Assets, Gross Liabilities	(35)		(16)
Risk Management Assets, Net, Long-term	46		161
Commodity Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	78		81
Risk Management Liabilities, Gross Assets	(68)		(77)
Risk Management Liabilities, Net, Current	10		4
Commodity Derivatives [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	49		38
Risk Management Liabilities, Gross Assets	(35)		(16)
Risk Management Liabilities, Net, Long-term	14		22
Foreign Currency Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	4
Risk Management Assets, Gross Liabilities	0
Risk Management Assets, Net, Current	4
Foreign Currency Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	1
Risk Management Assets, Gross Liabilities	0
Risk Management Assets, Net, Long-term	1
Foreign Currency Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities			21
Risk Management Liabilities, Gross Assets			0
Risk Management Liabilities, Net, Current			21
Level 1 [Member] | Accounts Payable and Accrued Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	0		0
Level 1 [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	0		0
Level 1 [Member] | Commodity Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	0		0
Level 1 [Member] | Commodity Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	0		0
Level 1 [Member] | Commodity Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	0		0
Level 1 [Member] | Commodity Derivatives [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	0		0
Level 1 [Member] | Foreign Currency Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	0
Level 1 [Member] | Foreign Currency Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	0
Level 1 [Member] | Foreign Currency Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities			0
Level 2 [Member] | Accounts Payable and Accrued Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	2		4
Level 2 [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	8		10
Level 2 [Member] | Commodity Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	256		492
Level 2 [Member] | Commodity Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	59		177
Level 2 [Member] | Commodity Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	78		81
Level 2 [Member] | Commodity Derivatives [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	49		38
Level 2 [Member] | Foreign Currency Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	4
Level 2 [Member] | Foreign Currency Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	1
Level 2 [Member] | Foreign Currency Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities			21
Level 3 [Member] | Accounts Payable and Accrued Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	0		0
Level 3 [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	0		0
Level 3 [Member] | Commodity Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	92		139
Level 3 [Member] | Commodity Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	22		0
Level 3 [Member] | Commodity Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	0		0
Level 3 [Member] | Commodity Derivatives [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	0		0
Level 3 [Member] | Foreign Currency Derivatives [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	0
Level 3 [Member] | Foreign Currency Derivatives [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	$ 0
Level 3 [Member] | Foreign Currency Derivatives [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities			$ 0

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Restructuring Charges (Tables)

9 Months Ended

Sep. 30, 2019

Restructuring Charges [Abstract]

Restructuring Costs Expensed

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Severance and Benefits	$	4	$	-	$	132	$	-
Outplacement, Moving and Other Expenses		-		-		2		-
Restructuring Expenses	$	4	$	-	$	134	$	-

Schedule of Change in Restructuring Accrual

	As at			As at
	September 30,			December 31,
	2019			2018
Outstanding Restructuring Accrual, Beginning of Year	$	-		$	-
Restructuring Expenses Incurred		134			-
Restructuring Costs Paid		(130	)		-
Outstanding Restructuring Accrual, End of Period (1)	$	4		$	-

(1) Included in accounts payable and accrued liabilities in the Condensed Consolidated Balance Sheet.

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Financial Instruments and Risk Management (Narrative) (Details)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019 USD ($) contract Counterparty $ / $	Sep. 30, 2018 USD ($)	Sep. 30, 2019 USD ($) contract Counterparty $ / $	Sep. 30, 2018 USD ($)	Dec. 31, 2018 USD ($) Counterparty
Derivative [Line Items]
Realized Gain (Loss) on Derivatives	$ 124,000,000	$ (76,000,000)	$ 302,000,000	$ (84,000,000)
Unrealized Gain (Loss) on Derivatives	$ (52,000,000)	(155,000,000)	$ (359,000,000)	(439,000,000)
Number of Credit Risk Derivatives | contract	0		0
Collateral balances	$ 0		$ 0
Percent of Accounts Receivable and Financial Derivative credit exposures with investment grade counterparties			96.00%		97.00%
Number Of Counterparties With More Than Ten Percent Of The Fair Value Of The Outstanding Risk Management Contracts | Counterparty	3		3		4
Guarantor Obligations, Term			two to five years
Guarantor Obligations, Current Carrying Value	$ 10,000,000		$ 10,000,000		$ 14,000,000
Maximum [Member]
Derivative [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	154,000,000		$ 154,000,000
Counterparty One [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts			20.00%		30.00%
Counterparty Two [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts			13.00%		13.00%
Counterparty Three [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts			13.00%		12.00%
Counterparty Four [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts					10.00%
Revenue [Member]
Derivative [Line Items]
Realized Gain (Loss) on Derivatives	122,000,000	(77,000,000)	$ 301,000,000	(95,000,000)
Unrealized Gain (Loss) on Derivatives	(41,000,000)	(164,000,000)	(385,000,000)	(422,000,000)
Currency Swaps, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Foreign currency swap, contract amount outstanding	$ 250,000,000		$ 250,000,000
Derivative, Average Forward Exchange Rate | $ / $	0.7516		0.7516
Currency Swaps, Maturing In Two Years [Member]
Derivative [Line Items]
Foreign currency swap, contract amount outstanding	$ 425,000,000		$ 425,000,000
Derivative, Average Forward Exchange Rate | $ / $	0.7483		0.7483
Other Derivative Contracts [Member] | Revenue [Member]
Derivative [Line Items]
Realized Gain (Loss) on Derivatives	$ 2,000,000	2,000,000	$ 5,000,000	5,000,000
Unrealized Gain (Loss) on Derivatives	$ 0	$ 0	$ (1,000,000)	$ (1,000,000)

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Acquisitions And Divestitures (Tables)

9 Months Ended

Sep. 30, 2019

Acquisitions And Divestitures [Abstract]

Schedule of Net Acquisitions & (Divestitures)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Acquisitions
Canadian Operations	$	-		$	15		$	-		$	17
USA Operations		25			-			66			-
Total Acquisitions		25			15			66			17
Divestitures
Canadian Operations		-			2			-			(55	)
USA Operations		(171	)		(26	)		(177	)		(34	)
Total Divestitures		(171	)		(24	)		(177	)		(89	)
Net Acquisitions & (Divestitures)	$	(146	)	$	(9	)	$	(111	)	$	(72	)

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Financial Instruments and Risk Management (Unrealized Risk Management Positions) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Risk Management, Current asset	$ 284		$ 554
Risk Management, Long-term asset	47		161
Risk Management, Total asset	331		715
Risk Management, Current liability	10	$ 25	25
Risk Management, Long-term liability	14		22
Risk Management, Total liability	24		47
Guarantor Obligations, Current Carrying Value	10		14
Risk Management and Other Derivative Guarantee, at Fair Value, Net	297		654
Accounts Payable and Accrued Liabilities [Member]
Derivatives, Fair Value [Line Items]
Guarantor Obligations, Current Carrying Value	2		4
Other Liabilities and Provisions [Member]
Derivatives, Fair Value [Line Items]
Guarantor Obligations, Current Carrying Value	$ 8		$ 10

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Other Liabilities And Provisions (Tables)

9 Months Ended

Sep. 30, 2019

Other Liabilities Disclosure [Abstract]

Schedule of Other Liabilities and Provisions

	As at		As at
	September 30,		December 31,
	2019		2018
The Bow Office Building	$	-	$	1,224
Finance Lease Obligations (See Note 11)		144		211
Unrecognized Tax Benefits		172		167
Pensions and Other Post-Employment Benefits		170		105
Long-Term Incentive Costs (See Note 19)		29		34
Other Derivative Contracts (See Notes 21, 22)		8		10
Other		25		18
	$	548	$	1,769

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Property, Plant And Equipment, Net (Schedule Of Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	$ 54,929	$ 45,832	$ 47,093
Less: Accumulated depreciation, depletion and amortization	(39,803)	(37,993)	(38,121)
Property, plant and equipment, net	15,126	$ 7,839	8,972
Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	15,060		14,260
Less: Accumulated depreciation, depletion and amortization	(13,949)		(13,261)
Property, plant and equipment, net	1,111		999
Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	38,968		30,690
Less: Accumulated depreciation, depletion and amortization	(25,186)		(24,099)
Property, plant and equipment, net	13,782		6,591
Operating Segments [Member] | Market Optimization [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	2		1
Corporate & Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	231		1,381
Proved Properties [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	14,817		13,996
Less: Accumulated depreciation, depletion and amortization	(13,949)		(13,261)
Property, plant and equipment, net	868		735
Proved Properties [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	35,223		27,189
Less: Accumulated depreciation, depletion and amortization	(25,186)		(24,099)
Property, plant and equipment, net	10,037		3,090
Unproved Properties [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	223		237
Less: Accumulated depreciation, depletion and amortization	0		0
Property, plant and equipment, net	223		237
Unproved Properties [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	3,720		3,493
Less: Accumulated depreciation, depletion and amortization	0		0
Property, plant and equipment, net	3,720		3,493
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	20		27
Less: Accumulated depreciation, depletion and amortization	0		0
Property, plant and equipment, net	20		27
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	25		8
Less: Accumulated depreciation, depletion and amortization	0		0
Property, plant and equipment, net	25		8
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | Market Optimization [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	8		7
Less: Accumulated depreciation, depletion and amortization	(6)		(6)
Property, plant and equipment, net	2		1
Other Capitalized Property Plant and Equipment [Member] | Corporate & Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	893		2,136
Less: Accumulated depreciation, depletion and amortization	(662)		(755)
Property, plant and equipment, net	$ 231		$ 1,381

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Asset Retirement Obligation (Schedule of Change In Asset Retirement Obligation) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation, Beginning of Year			$ 455	$ 514	$ 514
Liabilities Incurred	$ 2	$ 3	13	13	17
Liabilities Acquired (See Note 8)			184		0
Liabilities Settled and Divested			(100)		(56)
Change in Estimated Future Cash Outflows			0		(20)
Accretion of asset retirement obligation	9	$ 8	28	$ 24	32
Foreign Currency Translation			10		(32)
Asset Retirement Obligation, End of Period	$ 590		$ 590		$ 455

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Share Capital (Earnings Per Common Share) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Class Of Stock Disclosures [Abstract]
Net Earnings (Loss)	$ 149	$ 39	$ 240	$ 39
Weighted average common shares outstanding - Basic	1,322.8	955.1	1,308.4	962.2
Effect of dilutive securities	0.0	0.0	0.0	0.0
Weighted Average Common Shares Outstanding - Diluted	1,322.8	955.1	1,308.4	962.2
Net Earnings (Loss) per Common Share Basic & Diluted	$ 0.11	$ 0.04	$ 0.18	$ 0.04

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Leases (Schedule of Operating Lease Expense) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Operating Lease Expense
Total Operating Lease Expense	$ 59	$ 164
Transportation and Processing [Member]
Operating Lease Expense
Total Operating Lease Expense	1	2
Operating [Member]
Operating Lease Expense
Total Operating Lease Expense	28	76
Administrative [Member]
Operating Lease Expense
Total Operating Lease Expense	$ 30	$ 86

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Supplementary Information (Tables)

9 Months Ended

Sep. 30, 2019

Supplemental Cash Flow Elements [Abstract]

Net Change in Non-Cash Working Capital

A) Net Change in Non-Cash Working Capital

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Operating Activities
Accounts receivable and accrued revenues	$	61		$	(8	)	$	178		$	(152	)
Accounts payable and accrued liabilities		(82	)		59			(66	)		99
Current portion of operating lease liabilities		(9	)		-			52			-
Income tax receivable and payable		(2	)		262			(34	)		252
	$	(32	)	$	313		$	130		$	199

Non-Cash Activities

B) Non-Cash Activities

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 14)	$	2		$	3		$	13		$	13
Property, plant and equipment accruals		(80	)		(20	)		(33	)		61
Capitalized long-term incentives		1			11			(31	)		6
Property additions/dispositions (swaps)		63			55			66			195
New ROU operating lease assets and liabilities (See Note 11)		(1	)		-			(11	)		-
Non-Cash Financing Activities
Common shares issued in conjunction with the Newfield business    combination (See Note 8)	$	-		$	-		$	(3,478	)	$	-
Common shares issued under dividend reinvestment plan (See Note 15)		-			-			-			-

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Compensation Plans (Tables)

9 Months Ended

Sep. 30, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Schedule of Weighted Average Assumptions Used to Fair Value Share Units

	As at September 30, 2019		As at September 30, 2018
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units
Risk Free Interest Rate	1.58%	1.58%	2.18%	2.18%
Dividend Yield	1.63%	1.64%	0.46%	0.46%
Expected Volatility Rate (1)	44.14%	42.77%	55.44%	51.90%
Expected Term	2.9 yrs	2.6 yrs	1.6 yrs	2.0 yrs
Market Share Price	US$4.60	C$6.07	US$13.11	C$16.93

(1) Volatility was estimated using historical rates.

Amounts Recognized For Share-Based Payment Transactions

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Total Compensation Costs of Transactions Classified as Cash-Settled	$	2		$	36		$	46		$	118
Less: Total Share-Based Compensation Costs Capitalized		(1	)		(11	)		(16	)		(33	)
Total Share-Based Compensation Expense (Recovery)	$	1		$	25		$	30		$	85
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	-		$	8		$	12		$	24
Administrative		1			17			18			61
	$	1		$	25		$	30		$	85

Liability for Share-Based Payment Transactions

	As at September 30, 2019			As at December 31, 2018
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested		$	53		$	148
Vested			12			17
		$	65		$	165

Schedule of Share-based Compensation Activity

Nine Months Ended September 30, 2019 (thousands of units)
TSARs	1,244
SARs	1,718
PSUs	7,833
DSUs	111
RSUs	11,004

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Segmented Information (Schedule of Marketing Intersegment Eliminations) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Product Information [Line Items]
Revenues	$ 1,871	$ 1,262	$ 5,161	$ 3,558
Transportation and processing	398	278	1,148	799
Operating	193	124	545	372
Purchased product	264	282	784	803
Depreciation, depletion and amortization	545	349	1,454	924
Operating Income (Loss)	315	119	626	340
Market Optimization [Member] | Operating Segments [Member]
Product Information [Line Items]
Revenues	294	316	869	906
Transportation and processing	62	33	168	99
Operating	6	8	21	25
Purchased product	264	282	784	803
Depreciation, depletion and amortization	0	0	0	1
Operating Income (Loss)	(38)	(7)	(104)	(22)
Market Optimization [Member] | Reportable Subsegments [Member] | Marketing Sales [Member]
Product Information [Line Items]
Revenues	2,088	1,513	5,459	4,203
Transportation and processing	173	120	465	335
Operating	6	8	21	25
Purchased product	1,947	1,392	5,078	3,864
Depreciation, depletion and amortization			0	1
Operating Income (Loss)	(38)	(7)	(105)	(22)
Market Optimization [Member] | Intersubsegment Eliminations [Member]
Product Information [Line Items]
Revenues	(1,794)	(1,197)	(4,590)	(3,297)
Transportation and processing	(111)	(87)	(297)	(236)
Operating	0	0	0	0
Purchased product	(1,683)	(1,110)	(4,294)	(3,061)
Depreciation, depletion and amortization			0	0
Operating Income (Loss)	$ 0	$ 0	$ 1	$ 0

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Supplementary Information (Net Change in Non-Cash Working Capital) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Accounts receivable and accrued revenues	$ 61	$ (8)	$ 178	$ (152)
Accounts payable and accrued liabilities	(82)	59	(66)	99
Current portion of operating lease liabilities	(9)	0	52	0
Income tax receivable and payable	(2)	262	(34)	252
Net change in non-cash working capital	$ (32)	$ 313	$ 130	$ 199

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Income Taxes (Tables)

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Provision For Income Taxes

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Current Tax
Canada	$	(2	)	$	-		$	-		$	(66	)
United States		1			-			3			2
Other Countries		-			-			-			3
Total Current Tax Expense (Recovery)		(1	)		-			3			(61	)
Deferred Tax
Canada		(12	)		19			22			(9	)
United States		56			(3	)		117			4
Other Countries		-			(10	)		1			11
Total Deferred Tax Expense (Recovery)		44			6			140			6
Income Tax Expense (Recovery)	$	43		$	6		$	143		$	(55	)
Effective Tax Rate		22.4	%		13.3	%		37.3	%		343.8	%

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Supplementary Information

9 Months Ended

Sep. 30, 2019

Supplemental Cash Flow Elements [Abstract]

Supplementary Information

23. Supplementary Information

Supplemental disclosures to the Condensed Consolidated Statement of Cash Flows are presented below:

A) Net Change in Non-Cash Working Capital

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Operating Activities
Accounts receivable and accrued revenues	$	61		$	(8	)	$	178		$	(152	)
Accounts payable and accrued liabilities		(82	)		59			(66	)		99
Current portion of operating lease liabilities		(9	)		-			52			-
Income tax receivable and payable		(2	)		262			(34	)		252
	$	(32	)	$	313		$	130		$	199

B) Non-Cash Activities

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2019			2018
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 14)	$	2		$	3		$	13		$	13
Property, plant and equipment accruals		(80	)		(20	)		(33	)		61
Capitalized long-term incentives		1			11			(31	)		6
Property additions/dispositions (swaps)		63			55			66			195
New ROU operating lease assets and liabilities (See Note 11)		(1	)		-			(11	)		-
Non-Cash Financing Activities
Common shares issued in conjunction with the Newfield business    combination (See Note 8)	$	-		$	-		$	(3,478	)	$	-
Common shares issued under dividend reinvestment plan (See Note 15)		-			-			-			-

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Segmented Information (Tables)

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

Segment and Geographic Information

Results of Operations (For the three months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019			2018
Revenues
Product and service revenues	$	377	$	453	$	1,097	$	718		$	3		$	-
Gains (losses) on risk management, net		87		8		35		(84	)		-			-
Sublease revenues		-		-		-		-			-			-
Total Revenues		464		461		1,132		634			3			-
Operating Expenses
Production, mineral and other taxes		3		4		63		41			-			-
Transportation and processing		211		211		125		34			-			-
Operating		32		34		151		80			4			-
Depreciation, depletion and amortization		100		95		438		241			-			-
Total Operating Expenses		346		344		777		396			4			-
Operating Income (Loss)	$	118	$	117	$	355	$	238		$	(1	)	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	294		$	317		$	-		$	-		$	1,771		$	1,488
Gains (losses) on risk management, net		-			(1	)		(41	)		(164	)		81			(241	)
Sublease revenues		-			-			19			15			19			15
Total Revenues		294			316			(22	)		(149	)		1,871			1,262
Operating Expenses
Production, mineral and other taxes		-			-			-			-			66			45
Transportation and processing		62			33			-			-			398			278
Operating		6			8			-			2			193			124
Purchased product		264			282			-			-			264			282
Depreciation, depletion and amortization		-			-			7			13			545			349
Accretion of asset retirement obligation		-			-			9			8			9			8
Administrative		-			-			81			57			81			57
Total Operating Expenses		332			323			97			80			1,556			1,143
Operating Income (Loss)	$	(38	)	$	(7	)	$	(119	)	$	(229	)		315			119
Other (Income) Expenses
Interest														99			92
Foreign exchange (gain) loss, net														30			(23	)
(Gain) loss on divestitures, net														(5	)		-
Other (gains) losses, net														(1	)		5
Total Other (Income) Expenses														123			74
Net Earnings (Loss) Before Income Tax														192			45
Income tax expense (recovery)														43			6
Net Earnings (Loss)													$	149		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

Results of Operations (For the nine months ended September 30)

Segment and Geographic Information

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues
Product and service revenues	$	1,222	$	1,236	$	3,062	$	1,880		$	37	$	-
Gains (losses) on risk management, net		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Total Revenues		1,396		1,329		3,190		1,695			37		-
Operating Expenses
Production, mineral and other taxes		11		12		176		97			-		-
Transportation and processing		640		608		340		92			-		-
Operating		96		98		414		238			16		-
Depreciation, depletion and amortization		287		257		1,141		628			-		-
Total Operating Expenses		1,034		975		2,071		1,055			16		-
Operating Income (Loss)	$	362	$	354	$	1,119	$	640		$	21	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues
Product and service revenues	$	870		$	909		$	-		$	-		$	5,191		$	4,025
Gains (losses) on risk management, net		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Total Revenues		869			906			(331	)		(372	)		5,161			3,558
Operating Expenses
Production, mineral and other taxes		-			-			-			-			187			109
Transportation and processing		168			99			-			-			1,148			799
Operating		21			25			(2	)		11			545			372
Purchased product		784			803			-			-			784			803
Depreciation, depletion and amortization		-			1			26			38			1,454			924
Accretion of asset retirement obligation		-			-			28			24			28			24
Administrative		-			-			389			187			389			187
Total Operating Expenses		973			928			441			260			4,535			3,218
Operating Income (Loss)	$	(104	)	$	(22	)	$	(772	)	$	(632	)		626			340
Other (Income) Expenses
Interest														285			265
Foreign exchange (gain) loss, net														(62	)		93
(Gain) loss on divestitures, net														(4	)		(4	)
Other (gains) losses, net														24			2
Total Other (Income) Expenses														243			356
Net Earnings (Loss) Before Income Tax														383			(16	)
Income tax expense (recovery)														143			(55	)
Net Earnings (Loss)													$	240		$	39

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

Schedule of Marketing Intersegment Eliminations

Intersegment Information

							Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the three months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	2,088		$	1,513		$	(1,794	)	$	(1,197	)	$	294		$	316
Operating Expenses
Transportation and processing		173			120			(111	)		(87	)		62			33
Operating		6			8			-			-			6			8
Purchased product		1,947			1,392			(1,683	)		(1,110	)		264			282
Operating Income (Loss)	$	(38	)	$	(7	)	$	-		$	-		$	(38	)	$	(7	)

	Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the nine months ended September 30,	2019			2018			2019			2018			2019			2018
Revenues	$	5,459		$	4,203		$	(4,590	)	$	(3,297	)	$	869		$	906
Operating Expenses
Transportation and processing		465			335			(297	)		(236	)		168			99
Operating		21			25			-			-			21			25
Purchased product		5,078			3,864			(4,294	)		(3,061	)		784			803
Depreciation, depletion and amortization		-			1			-			-			-			1
Operating Income (Loss)	$	(105	)	$	(22	)	$	1		$	-		$	(104	)	$	(22	)

Capital Expenditures

Capital Expenditures

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2019		2018		2019		2018
Canadian Operations	$	99	$	174	$	364	$	553
USA Operations		464		345		1,682		1,065
Market Optimization		2		-		2		-
Corporate & Other		1		4		4		8
	$	566	$	523	$	2,052	$	1,626

Goodwill, Property, Plant and Equipment and Total Assets By Segment

Goodwill, Property, Plant and Equipment and Total Assets by Segment

	Goodwill					Property, Plant and Equipment					Total Assets
	As at					As at					As at
	September 30,		December 31,			September 30,		December 31,			September 30,		December 31,
	2019			2018		2019			2018		2019			2018
Canadian Operations	$	660		$	640	$	1,111		$	999	$	1,978		$	1,852
USA Operations		1,935			1,913		13,782			6,591		16,634			9,104
Market Optimization		-			-		2			1		225			295
Corporate & Other		-			-		231			1,381		2,519			4,093
	$	2,595		$	2,553	$	15,126		$	8,972	$	21,356		$	15,344

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Business Combination

9 Months Ended

Sep. 30, 2019

Business Combinations [Abstract]

Business Combination

8. Business Combination

Newfield Exploration Company Acquisition

On February 13, 2019, Encana completed the business combination with Newfield Exploration Company, a Delaware corporation (“Newfield”), pursuant to its Agreement and Plan of Merger with Newfield (the “Merger”). As a result of the Merger, Newfield stockholders received 2.6719 Encana common shares for each share of Newfield common stock that was issued and outstanding immediately prior to the effective date of the Merger. Encana issued approximately 543.4 million common shares representing a value of $3.5 billion and paid approximately $5 million in cash in respect of Newfield’s cash-settled incentive awards. Following the acquisition, Newfield’s senior notes totaling $2.45 billion remained outstanding. Transaction costs of approximately $33 million were included in other (gains) losses, net.

Newfield’s operations focused on the exploration and development of oil and gas properties located in the Anadarko and Arkoma Basins of Oklahoma, the Williston Basin of North Dakota and the Uinta Basin of Utah, as well as offshore oil assets located in China. The assets acquired generated revenues of $1,485 million and net earnings of $69 million for the period from February 14, 2019 to September 30, 2019. The results of Newfield’s operations have been included in Encana’s Consolidated Financial Statements as of February 14, 2019.  

Purchase Price Allocation

The transaction was accounted for under the acquisition method, which requires that the assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date, with any excess of the purchase price over the estimated fair value of identified net assets acquired recorded as goodwill. The purchase price allocation represents the consideration paid and the fair values of the assets acquired, and liabilities assumed as of the acquisition date. The purchase price allocation is subject to change based on information that may not yet be available, including, the valuation of any pre-acquisition contingencies, final appraisals and tax returns that provide the underlying tax basis of the net assets and liabilities acquired and uncertain tax positions. The Company expects the purchase price allocation to be completed within 12 months following the acquisition date, during which time the value of the net assets and liabilities acquired may be revised as appropriate.

Preliminary Purchase Price Allocation
Consideration:
Fair value of Encana's common shares issued (1)	$	3,478
Fair value of Newfield liability awards paid in cash (2)		5
Total Consideration	$	3,483
Assets Acquired:
Cash and cash equivalents	$	46
Accounts receivable and accrued revenues		486
Other current assets		50
Proved properties		5,903
Unproved properties		838
Other property, plant and equipment		22
Restricted cash		53
Other assets		105
Goodwill (3)		22
Liabilities Assumed:
Accounts payable and accrued liabilities (3)		(795	)
Long-term debt		(2,603	)
Operating lease liabilities		(76	)
Other long-term liabilities (3)		(61	)
Asset retirement obligation		(184	)
Deferred income taxes (3)		(323	)
Total Purchase Price	$	3,483

(1) The fair value was based on the NYSE closing price of the Encana common shares of $6.40 on February 13, 2019.

(2) The fair value was based on a price of $6.50 per notional unit which was determined using a volume-weighted average of the trading price of Encana common shares on the NYSE on each of the five consecutive trading days ending on the trading day that was three trading days prior to February 13, 2019.

(3) Since the completion of the business combination on February 13, 2019, additional information related to pre-acquisition liabilities and contingencies was obtained resulting in a measurement period adjustment. Changes in the fair value estimates comprised an increase in other liabilities of $12 million, of which the total liability is presented in accounts payable and accrued liabilities, a decrease in deferred tax liabilities of $3 million and a corresponding increase in goodwill of $9 million.

The Company used the income approach valuation technique for the fair value of assets acquired and liabilities assumed. The carrying amounts of cash and cash equivalents, accounts receivable and accrued revenues, restricted cash and other current assets, and accounts payable and accrued liabilities approximate their fair values due to their nature and/or the short-term maturity of the instruments. The fair values of long-term debt, ROU assets and operating lease liabilities were categorized within Level 2 of the fair value hierarchy and were determined using quoted prices and rates from an available pricing source. The fair values of the proved and unproved properties, other property, plant and equipment, other assets, other long-term liabilities and asset retirement obligation were categorized within Level 3 and were determined using relevant market assumptions, including discount rates, future commodity prices and costs, timing of development activities, projections of oil and gas reserves, and estimates for abandonment and reclamation.

Goodwill arose from the Newfield acquisition primarily from the requirement to recognize deferred taxes on the difference between the fair value of the assets acquired and liabilities assumed and the respective carry-over tax basis. Goodwill is not amortized and is not deductible for tax purposes.

Unaudited Pro Forma Financial Information

The following unaudited pro forma financial information combines the historical financial results of Encana with Newfield and has been prepared as though the acquisition had occurred on January 1, 2018. The pro forma information is not intended to reflect the actual results of operations that would have occurred if the business combination had been completed at the date indicated. In addition, the pro forma information is not intended to be a projection of Encana’s results of operations for any future period.

Additionally, pro forma earnings were adjusted to exclude acquisition-related costs incurred of approximately $71 million and severance payments made to employees which totaled $134 million for the nine months ended September 30, 2019. The pro forma financial information does not include any cost savings or other synergies that may result from the Merger or any estimated costs that have been or will be incurred to integrate the assets.

For the nine months ended September 30, (US$ millions, except per share amounts)	2019		2018
Revenues	$	5,440	$	5,215
Net Earnings (Loss)	$	376	$	369
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.29	$	0.25

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Revenue from Contracts with Customers

9 Months Ended

Sep. 30, 2019

Revenue From Contract With Customer [Abstract]

Revenues from Contracts with Customers

4. Revenues from Contracts with Customers

The following tables summarize the Company’s revenues from contracts with customers and other sources of revenues. Encana presents realized and unrealized gains and losses on certain derivative contracts within revenues.

Revenues (For the three months ended September 30)

	Canadian Operations				USA Operations						China Operations (1)
	2019		2018		2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	3	$	1	$	905		$	590		$	3	$	-
NGLs		225		259		99			98			-		-
Natural gas		150		195		95			31			-		-
Service revenues
Gathering and processing		2		1		(1	)		4			-		-
Product and Service Revenues		380		456		1,098			723			3		-
Other Revenues
Gains (losses) on risk management, net (3)		87		8		35			(84	)		-		-
Sublease revenues		-		-		-			-			-		-
Other Revenues		87		8		35			(84	)		-		-
Total Revenues	$	467	$	464	$	1,133		$	639		$	3	$	-

	Market Optimization					Corporate & Other						Consolidated
	2019		2018			2019			2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	107	$	34		$	-		$	-		$	1,018	$	625
NGLs		2		1			-			-			326		358
Natural gas		181		274			-			-			426		500
Service revenues
Gathering and processing		-		-			-			-			1		5
Product and Service Revenues		290		309			-			-			1,771		1,488
Other Revenues
Gains (losses) on risk management, net (3)		-		(1	)		(41	)		(164	)		81		(241	)
Sublease revenues		-		-			19			15			19		15
Other Revenues		-		(1	)		(22	)		(149	)		100		(226	)
Total Revenues	$	290	$	308		$	(22	)	$	(149	)	$	1,871	$	1,262

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

Revenues (For the nine months ended September 30)

	Canadian Operations				USA Operations					China Operations (1)
	2019		2018		2019		2018			2019		2018
Revenues from Customers
Product revenues (2)
Oil	$	6	$	6	$	2,461	$	1,579		$	37	$	-
NGLs		659		655		332		221			-		-
Natural gas		563		580		276		92			-		-
Service revenues
Gathering and processing		4		5		2		4			-		-
Product and Service Revenues		1,232		1,246		3,071		1,896			37		-
Other Revenues
Gains (losses) on risk management, net (3)		174		93		128		(185	)		-		-
Sublease revenues		-		-		-		-			-		-
Other Revenues		174		93		128		(185	)		-		-
Total Revenues	$	1,406	$	1,339	$	3,199	$	1,711		$	37	$	-

	Market Optimization						Corporate & Other						Consolidated
	2019			2018			2019			2018			2019			2018
Revenues from Customers
Product revenues (2)
Oil	$	205		$	84		$	-		$	-		$	2,709		$	1,669
NGLs		6			6			-			-			997			882
Natural gas		640			793			-			-			1,479			1,465
Service revenues
Gathering and processing		-			-			-			-			6			9
Product and Service Revenues		851			883			-			-			5,191			4,025
Other Revenues
Gains (losses) on risk management, net (3)		(1	)		(3	)		(385	)		(422	)		(84	)		(517	)
Sublease revenues		-			-			54			50			54			50
Other Revenues		(1	)		(3	)		(331	)		(372	)		(30	)		(467	)
Total Revenues	$	850		$	880		$	(331	)	$	(372	)	$	5,161		$	3,558

(1) The Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019.

(2) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between the Company’s operating segments.

(3) Canadian Operations, USA Operations and Market Optimization include realized gains (losses) on risk management. Corporate and Other includes unrealized gains (losses) on risk management.

The Company’s revenues from contracts with customers consists of product sales including oil, NGLs and natural gas, as well as the provision of gathering and processing services to third parties. Encana had no contract asset or liability balances during the periods presented. As at September 30, 2019, receivables and accrued revenues from contracts with customers were $980 million ($662 million as at December 31, 2018).

Encana’s product sales are sold under short-term contracts with terms that are less than one year at either fixed or market index prices or under long-term contracts exceeding one year at market index prices.  

The Company’s gathering and processing services are provided on an interruptible basis with transaction prices that are for fixed prices and/or variable consideration. Variable consideration received is related to recovery of plant operating costs or escalation of the fixed price based on a consumer price index. As the service contracts are interruptible, with service provided on an “as available” basis, there are no unsatisfied performance obligations remaining at September 30, 2019.

As at September 30, 2019, all remaining performance obligations are priced at market index prices or are variable volume delivery contracts. As such, the variable consideration is allocated entirely to the wholly unsatisfied performance obligation or promise to deliver units of production, and revenue is recognized at the amount for which the Company has the right to invoice the product delivered. As the period between when the product sales are transferred and Encana receives payments is generally 30 to 60 days, there is no financing element associated with customer contracts. In addition, Encana does not disclose unsatisfied performance obligations for customer contracts with terms less than 12 months.