10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2018

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  [X]    No  [    ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  [X]    No  [    ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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	[X]	Accelerated filer	[    ]
Non-accelerated filer	[    ] (Do not check if a smaller reporting company)	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 Act).

Yes  [    ]    No  [X]

      Number of registrant’s common shares outstanding as of April 27, 2018 963,146,387

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	9
Notes to Condensed Consolidated Financial Statements	10
Item 2.      Management’s Discussion and Analysis of Financial Condition and Results of Operations	35
Item 3.      Quantitative and Qualitative Disclosures about Market Risk	53
Item 4.     Controls and Procedures	54
PART II
Item 1.     Legal Proceedings	55
Item 1A.  Risk Factors	55
Item 2.      Unregistered Sales of Equity Securities and Use of Proceeds	55
Item 3.     Defaults Upon Senior Securities	55
Item 4.     Mine Safety Disclosures	55
Item 5.     Other Information	55
Item 6.     Exhibits	56
Signatures	57

2

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.

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

“NYMEX” means New York Mercantile Exchange.

“OPEC” means Organization of the Petroleum Exporting Countries.

“SEC” means United States Securities and Exchange Commission.

“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 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.

3

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 to being a leading North American resource play company; 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 lower costs and improve efficiencies to achieve competitive advantage; ability to repeat and deploy successful practices across the Company’s multi-basin portfolio; balancing commodity portfolio; 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; expected timing for construction of facilities and costs thereof; expansion of future midstream services; 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, 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 compliance with financial covenants; impact to the Company as a result of changes to its credit rating; access to the Company’s credit facilities; planned annualized dividend and the declaration and payment of future dividends, if any; the Company’s normal course issuer bid (“NCIB”) program, including amounts and number of shares to be acquired, anticipated timeframe, method and location of purchases, and source of funding thereof; 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 five-year plan; 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; statements with respect to future ceiling test impairments; and the possible impact and timing of accounting pronouncements, rule changes and standards.

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, five-year plan 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; 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

4

difficulties, including impact of weather; 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, 2017 (“2017 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 2017 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.

5

PART I

Item 1. Financial Statements

Condensed Consolidated Statement of Earnings (unaudited)

		Three Months Ended March 31,
(US$ millions, except per share amounts)		2018			2017 (1)
Revenues	(Notes 3, 4)
Product and service revenues		$	1,260		$	934
Gains (losses) on risk management, net	(Note 19)		36			338
Sublease revenues			17			17
Total Revenues			1,313			1,289
Operating Expenses	(Note 3)
Production, mineral and other taxes			29			29
Transportation and processing	(Note 19)		249			212
Operating	(Notes 16, 17)		111			132
Purchased product			273			171
Depreciation, depletion and amortization			275			187
Accretion of asset retirement obligation	(Note 12)		8			11
Administrative	(Notes 16, 17)		31			58
Total Operating Expenses			976			800
Operating Income (Loss)			337			489
Other (Income) Expenses
Interest	(Note 5)		92			88
Foreign exchange (gain) loss, net	(Notes 6, 19)		91			(26	)
(Gain) loss on divestitures, net			(3	)		1
Other (gains) losses, net	(Note 17)		(3	)		(8	)
Total Other (Income) Expenses			177			55
Net Earnings (Loss) Before Income Tax			160			434
Income tax expense (recovery)	(Note 7)		9			3
Net Earnings (Loss)		$	151		$	431
Net Earnings (Loss) per Common Share
Basic & Diluted	(Note 13)	$	0.16		$	0.44
Dividends Declared per Common Share	(Note 13)	$	0.015		$	0.015
Weighted Average Common Shares Outstanding (millions)
Basic & Diluted	(Note 13)		971.5			973.0

(1)   Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net. The remaining Q1 2017 revenues have been realigned to conform with the current year presentation.

Condensed Consolidated Statement of Comprehensive Income (unaudited)

		Three Months Ended March 31,
(US$ millions)		2018			2017
Net Earnings (Loss)		$	151		$	431
Other Comprehensive Income (Loss), Net of Tax
Foreign currency translation adjustment	(Note 14)		24			(16	)
Pension and other post-employment benefit plans	(Notes 14, 17)		(1	)		(1	)
Other Comprehensive Income (Loss)			23			(17	)
Comprehensive Income (Loss)		$	174		$	414

See accompanying Notes to Condensed Consolidated Financial Statements

6

Condensed Consolidated Balance Sheet (unaudited)

(US$ millions)		As at    March 31,    2018			As at    December 31,    2017
Assets
Current Assets
Cash and cash equivalents		$	433		$	719
Accounts receivable and accrued revenues			731			774
Risk management	(Notes 18, 19)		226			205
Income tax receivable			562			573
			1,952			2,271
Property, Plant and Equipment, at cost:	(Note 9)
Oil and natural gas properties, based on full cost accounting
Proved properties			40,508			40,228
Unproved properties			4,301			4,480
Other			2,241			2,302
Property, plant and equipment			47,050			47,010
Less: Accumulated depreciation, depletion and amortization			(37,933	)		(38,056	)
Property, plant and equipment, net	(Note 3)		9,117			8,954
Other Assets			139			144
Risk Management	(Notes 18, 19)		290			246
Deferred Income Taxes			1,021			1,043
Goodwill	(Note 3)		2,591			2,609
	(Note 3)	$	15,110		$	15,267
Liabilities and Shareholders’ Equity
Current Liabilities
Accounts payable and accrued liabilities		$	1,432		$	1,415
Income tax payable			3			7
Risk management	(Notes 18, 19)		250			236
			1,685			1,658
Long-Term Debt	(Note 10)		4,198			4,197
Other Liabilities and Provisions	(Note 11)		1,958			2,167
Risk Management	(Notes 18, 19)		17			13
Asset Retirement Obligation	(Note 12)		443			470
Deferred Income Taxes			33			34
			8,334			8,539
Commitments and Contingencies	(Note 21)
Shareholders’ Equity
Share capital - authorized unlimited common shares 2018 issued and outstanding: 963.1 million shares (2017: 973.1 million shares)	(Note 13)		4,707			4,757
Paid in surplus			1,358			1,358
Accumulated deficit			(354	)		(429	)
Accumulated other comprehensive income	(Note 14)		1,065			1,042
Total Shareholders’ Equity			6,776			6,728
		$	15,110		$	15,267

See accompanying Notes to Condensed Consolidated Financial Statements

7

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

Three Months Ended March 31, 2018 (US$ millions)			Share Capital			Paid in Surplus		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)				-			-		151			-			151
Dividends on Common Shares	(Note 13	)		-			-		(15	)		-			(15	)
Common Shares Purchased under Normal Course Issuer Bid	(Note 13	)		(50	)		-		(61	)		-			(111	)
Common Shares Issued Under Dividend Reinvestment Plan	(Note 13	)		-			-		-			-			-
Other Comprehensive Income (Loss)	(Note 14	)		-			-		-			23			23
Balance, March 31, 2018			$	4,707		$	1,358	$	(354	)	$	1,065		$	6,776
Three Months Ended March 31, 2017 (US$ millions)			Share Capital			Paid in Surplus		Accumulated Deficit			Accumulated Other Comprehensive Income			Total Shareholders’ Equity
Balance, December 31, 2016			$	4,756		$	1,358	$	(1,198)		$	1,210		$	6,126
Net Earnings (Loss)				-			-		431			-			431
Dividends on Common Shares	(Note 13	)		-			-		(15)			-			(15	)
Common Shares Issued Under Dividend Reinvestment Plan	(Note 13	)		-			-		-			-			-
Other Comprehensive Income (Loss)	(Note 14	)		-			-		-			(17	)		(17	)
Balance, March 31, 2017			$	4,756		$	1,358	$	(782)		$	1,193		$	6,525

See accompanying Notes to Condensed Consolidated Financial Statements

8

Condensed Consolidated Statement of Cash Flows (unaudited)

			Three Months Ended March 31,
(US$ millions)			2018			2017
Operating Activities
Net earnings (loss)			$	151		$	431
Depreciation, depletion and amortization				275			187
Accretion of asset retirement obligation	(Note 12	)		8			11
Deferred income taxes	(Note 7	)		6			42
Unrealized (gain) loss on risk management	(Note 19	)		(68	)		(362	)
Unrealized foreign exchange (gain) loss	(Note 6	)		150			(36	)
Foreign exchange on settlements	(Note 6	)		(50	)		2
(Gain) loss on divestitures, net				(3	)		1
Other				(69	)		2
Net change in other assets and liabilities				(11	)		(12	)
Net change in non-cash working capital	(Note 20	)		(8	)		(160	)
Cash From (Used in) Operating Activities				381			106
Investing Activities
Capital expenditures	(Note 3	)		(508	)		(399	)
Acquisitions	(Note 8	)		(2	)		(46	)
Proceeds from divestitures	(Note 8	)		19			3
Net change in investments and other				(25	)		55
Cash From (Used in) Investing Activities				(516	)		(387	)
Financing Activities
Purchase of common shares	(Note 13	)		(111	)		-
Dividends on common shares	(Note 13	)		(15	)		(15	)
Capital lease payments and other financing arrangements	(Note 11	)		(22	)		(16	)
Cash From (Used in) Financing Activities				(148	)		(31	)
Foreign Exchange Gain (Loss) on Cash and Cash Equivalents Held in Foreign Currency				(3	)		1
Increase (Decrease) in Cash and Cash Equivalents				(286	)		(311	)
Cash and Cash Equivalents, Beginning of Year				719			834
Cash and Cash Equivalents, End of Period			$	433		$	523
Cash, End of Period			$	39		$	45
Cash Equivalents, End of Period				394			478
Cash and Cash Equivalents, End of Period			$	433		$	523

See accompanying Notes to Condensed Consolidated Financial Statements

9

 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, 2017, which are included in Item 8 of Encana’s 2017 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, 2017, 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, 2018, Encana adopted the following ASUs issued by the FASB, which have not had a material impact on the Company’s interim Condensed Consolidated Financial Statements:

· ASU 2014-09, “Revenue from Contracts with Customers” under Topic 606. The new standard replaces Topic 605, “Revenue Recognition” as well as other industry-specific guidance within the Accounting Standards Codification. Topic 606 is based on the principle that revenue is recognized on the transfer of promised goods or services to customers in an amount that reflects the consideration the company expects to be entitled to in exchange for those goods or services. The standard has been applied using the modified retrospective approach and did not have a material impact on the Company’s Condensed Consolidated Financial Statements, other than enhancing disclosures related to the disaggregation of revenues from contracts with customers and performance obligations. The disclosures required under Topic 606 are included in Note 4, Revenues from Contracts with Customers.

· ASU 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”. The amendment requires the service cost component to be presented with the related employee compensation costs, while the other components of net benefit costs are required to be presented separately from the service cost component and outside the subtotal of income from operations. In addition, the amendment allows only the service cost to be eligible for capitalization. The amendment has been applied retrospectively for the presentation of net periodic pension costs and net periodic postretirement benefit cost, whereas prospective adoption has been applied to the capitalization of the service cost component.

10

New Standards Issued Not Yet Adopted

As of January 1, 2019, Encana will be required to adopt ASU 2016-02, “Leases” under Topic 842, which will replace Topic 840 “Leases”. The new standard will require lessees to recognize right-of-use assets and related lease liabilities for all leases, including leases classified as operating leases, on the Consolidated Balance Sheet. The dual classification model was retained for the purpose of subsequent measurement and presentation of leases in the Consolidated Statement of Earnings and Consolidated Statement of Cash Flows. Topic 842 also expands disclosures related to the amount, timing and uncertainty of cash flows arising from leases. The standard will be applied using a modified retrospective approach, in addition Encana intends to elect certain practical expedients which will allow the Company to retain the classification of leases assessed under Topic 840 which commenced prior to adoption.

In January 2018, FASB issued ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842”, which permits entities to elect an optional transition practical expedient for land easements that were not previously accounted for as leases under Topic 840. The expedient provides prospective application of Topic 842 to all new or modified land easements upon adoption of the new standard. Encana intends to elect this transitional practical expedient.

Encana continues to review and analyze contracts, identify its portfolio of leased assets, gather the necessary terms and data elements, as well as identify the processes and controls required to support the accounting for leases and related disclosures. The Company is in the early stages of implementing a lease software system which will facilitate the measurement and required disclosures for operating leases. The Company anticipates the software implementation to be complete by the end of 2018. Although Encana is not able to reasonably estimate the financial impact of Topic 842 at this time, the Company anticipates there will be a material impact on the Consolidated Financial Statements resulting from the recognition of assets and liabilities from operating lease activities.

As of January 1, 2019, Encana will be required to adopt 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”). Amendments can be applied either in the period of adoption or retrospectively to each period in which the effect of the rate change from the U.S. Tax Reform is recognized. While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact is not material to the Company’s Consolidated Financial Statements. As a result, the Company does not intend to take the election provided in the amendment.

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 is currently in the early stages of reviewing the amendment, but does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

11

 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 centre.

· 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 centre.

· 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.

12

Results of Operations (For the three months ended March 31)

Segment and Geographic Information

	Canadian Operations					USA Operations						Market Optimization
	2018		2017 (1)			2018			2017 (1)			2018			2017 (1)
Revenues
Product and service revenues	$	404	$	301		$	555		$	447		$	301		$	186
Gains (losses) on risk management, net		12		(21	)		(44	)		(3	)		-			-
Sublease revenues		-		-			-			-			-			-
Total Revenues		416		280			511			444			301			186
Operating Expenses
Production, mineral and other taxes		4		5			25			24			-			-
Transportation and processing		190		132			27			59			32			21
Operating		29		31			74			87			4			9
Purchased product		-		-			-			-			273			171
Depreciation, depletion and amortization		77		64			185			106			-			-
Total Operating Expenses		300		232			311			276			309			201
Operating Income (Loss)	$	116	$	48		$	200		$	168		$	(8	)	$	(15	)
						Corporate & Other						Consolidated
						2018			2017 (1)			2018			2017 (1)
Revenues
Product and service revenues						$	-		$	-		$	1,260		$	934
Gains (losses) on risk management, net							68			362			36			338
Sublease revenues							17			17			17			17
Total Revenues							85			379			1,313			1,289
Operating Expenses
Production, mineral and other taxes							-			-			29			29
Transportation and processing							-			-			249			212
Operating							4			5			111			132
Purchased product							-			-			273			171
Depreciation, depletion and amortization							13			17			275			187
Accretion of asset retirement obligation							8			11			8			11
Administrative							31			58			31			58
Total Operating Expenses							56			91			976			800
Operating Income (Loss)						$	29		$	288			337			489
Other (Income) Expenses
Interest													92			88
Foreign exchange (gain) loss, net													91			(26	)
(Gain) loss on divestitures, net													(3	)		1
Other (gains) losses, net													(3	)		(8	)
Total Other (Income) Expenses													177			55
Net Earnings (Loss) Before Income Tax													160			434
Income tax expense (recovery)													9			3
Net Earnings (Loss)												$	151		$	431

(1) Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net. The remaining Q1 2017 revenues have been realigned to conform with the current year presentation.

13

Intersegment Information

	Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the three months ended March 31,	2018			2017			2018			2017			2018			2017
Revenues	$	1,331		$	956		$	(1,030	)	$	(770	)	$	301		$	186
Operating Expenses
Transportation and processing		106			64			(74	)		(43	)		32			21
Operating		4			9			-			-			4			9
Purchased product		1,229			898			(956	)		(727	)		273			171
Operating Income (Loss)	$	(8	)	$	(15	)	$	-		$	-		$	(8	)	$	(15	)
Capital Expenditures
													Three Months Ended         March 31,
													2018			2017
Canadian Operations													$	168		$	88
USA Operations														338			311
Corporate & Other														2			-
													$	508		$	399
Goodwill, Property, Plant and Equipment and Total Assets by Segment
	Goodwill						Property, Plant and Equipment						Total Assets
	As at						As at						As at
	March 31, 2018			December 31, 2017			March 31, 2018			December 31, 2017			March 31, 2018			December 31, 2017
Canadian Operations	$	678		$	696		$	920		$	862		$	1,923		$	1,908
USA Operations		1,913			1,913			6,710			6,555			9,432			9,301
Market Optimization		-			-			1			2			151			152
Corporate & Other		-			-			1,486			1,535			3,604			3,906
	$	2,591		$	2,609		$	9,117		$	8,954		$	15,110		$	15,267

14

4.   Revenues from Contracts with Customers

The table below summarizes 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.

	Canadian Operations					USA Operations						Market Optimization
For the three months ended March 31,	2018		2017			2018			2017			2018		2017
Revenues from Customers
Product revenues (1)
Oil	$	3	$	2		$	473		$	301		$	22	$	37
NGLs		180		95			52			40			2		12
Natural gas		221		203			32			107			273		127
Service revenues
Gathering and processing		2		4			-			6			-		-
Product and Service Revenues		406		304			557			454			297		176
Other Revenues
Gains (losses) on risk management, net (2)		12		(21	)		(44	)		(3	)		-		-
Sublease revenues		-		-			-			-			-		-
Other Revenues		12		(21	)		(44	)		(3	)		-		-
Total Revenues	$	418	$	283		$	513		$	451		$	297	$	176
						Corporate & Other						Consolidated
						2018			2017 (3)			2018		2017 (3)
Revenues from Customers
Product revenues (1)
Oil						$	-		$	-		$	498	$	340
NGLs							-			-			234		147
Natural gas							-			-			526		437
Service revenues
Gathering and processing							-			-			2		10
Product and Service Revenues							-			-			1,260		934
Other Revenues
Gains (losses) on risk management, net (2)							68			362			36		338
Sublease revenues							17			17			17		17
Other Revenues							85			379			53		355
Total Revenues						$	85		$	379		$	1,313	$	1,289

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

(2) Canadian and USA Operations includes realized gains/(losses) on risk management. Corporate & Other includes unrealized gains/(losses) on risk management.

(3) Corporate interest income of $8 million previously reported in revenues in Q1 2017 has been reclassified to other (gains) losses, net.

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 March 31, 2018, receivables and accrued revenues from contracts with customers were $658 million ($676 million as at December 31, 2017).

Performance obligations arising from product sales contracts are typically satisfied at a point in time when the product is delivered to the customer and control is transferred. Payment from the customer is due when the product is delivered to the custody point. The Company’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.

As at March 31, 2018, 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.

Performance obligations arising from arrangements to gather and process natural gas on behalf of third parties are typically satisfied over time as the service is provided to the customer. Payment from the customer is due when the customer receives

15

the benefit of the service and the product is delivered to the custody point or plant tailgate. 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 March 31, 2018.

5.   Interest

	Three Months Ended         March 31,
	2018		2017
Interest Expense on:
Debt	$	66	$	66
The Bow office building		16		16
Capital leases		5		5
Other		5		1
	$	92	$	88

6.   Foreign Exchange (Gain) Loss, Net

	Three Months Ended         March 31,
	2018			2017
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	122		$	(33	)
Translation of U.S. dollar risk management contracts issued from Canada		9			(4	)
Translation of intercompany notes		19			1
		150			(36	)
Foreign Exchange on Settlements of:
U.S. dollar risk management contracts issued from Canada		(7	)		(1	)
Intercompany notes		(50	)		2
Other Monetary Revaluations		(2	)		9
	$	91		$	(26	)

16

7.   Income Taxes

	Three Months Ended         March 31,
	2018			2017
Current Tax
Canada	$	-		$	(42	)
United States		1			-
Other Countries		2			3
Total Current Tax Expense (Recovery)		3			(39	)
Deferred Tax
Canada		(3	)		18
United States		4			15
Other Countries		5			9
Total Deferred Tax Expense (Recovery)		6			42
Income Tax Expense (Recovery)	$	9		$	3
Effective Tax Rate		5.6%			0.7%

Encana’s interim income tax expense is determined using an 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 including U.S. Tax Reform, non-taxable capital gains and losses, tax differences on divestitures and transactions, and partnership tax allocations in excess of funding.

During the three months ended March 31, 2017, the current income tax recovery was primarily due to the successful resolution of certain tax items previously assessed by the taxing authorities relating to prior taxation years.

The effective tax rates of 5.6 percent and 0.7 percent for the three months ended March 31, 2018 and March 31, 2017, respectively, are lower than the Canadian statutory rate of 27 percent primarily due to the impact of the foreign jurisdictional tax rates relative to the Canadian statutory tax rate applied to jurisdictional earnings as well as the items discussed above.

During the three months ended March 31, 2018, there was no change to the provisional tax adjustment recognized in 2017 resulting from the re-measurement of the Company’s tax position due to a reduction of the U.S. federal corporate tax rate under U.S. Tax Reform. The provisional amount recognized may change due to additional regulatory guidance that may be issued, and from additional analysis or changes in interpretation and assumptions of the U.S. Tax Reform made by the Company.

17

 8.  Acquisitions and Divestitures

	Three Months Ended
	March 31,
	2018		2017
Acquisitions
Canadian Operations	$	2	$	31
USA Operations		-		15
Total Acquisitions		2		46
Divestitures
Canadian Operations		(13)		(3)
USA Operations		(6)		-
Total Divestitures		(19)		(3)
Net Acquisitions & (Divestitures)	$	(17)	$	43

Acquisitions

For the three months ended March 31, 2018, acquisitions in the Canadian and USA Operations were $2 million (2017 - $31 million) and nil (2017 - $15 million), respectively, which primarily included land purchases with oil and liquids rich potential.

Divestitures

For the three months ended March 31, 2018, divestitures in the Canadian and USA Operations were $13 million (2017 - $3 million) and $6 million (2017 - nil), respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

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

18

 9.  Property, Plant and Equipment, Net

	As at March 31, 2018							As at December 31, 2017
			Accumulated							Accumulated
	Cost		DD&A			Net		Cost		DD&A			Net
Canadian Operations
Proved properties	$	14,366	$	(13,743	)	$	623	$	14,555	$	(14,047	)	$	508
Unproved properties		262		-			262		311		-			311
Other		35		-			35		43		-			43
		14,663		(13,743	)		920		14,909		(14,047	)		862
USA Operations
Proved properties		26,081		(23,426	)		2,655		25,610		(23,240	)		2,370
Unproved properties		4,039		-			4,039		4,169		-			4,169
Other		16		-			16		16		-			16
		30,136		(23,426	)		6,710		29,795		(23,240	)		6,555
Market Optimization		7		(6	)		1		7		(5	)		2
Corporate & Other		2,244		(758	)		1,486		2,299		(764	)		1,535
	$	47,050	$	(37,933	)	$	9,117	$	47,010	$	(38,056	)	$	8,954

Canadian and USA Operations property, plant and equipment include internal costs directly related to exploration, development and construction activities of $39 million, which have been capitalized during the three months ended March 31, 2018 (2017 - $54 million). Included in Corporate and Other are $61 million ($63 million as at December 31, 2017) of international property costs, which have been fully impaired.

Capital Lease Arrangements

The Company has several lease arrangements that are accounted for as capital leases including an office building and an offshore production platform.

As at March 31, 2018, the total carrying value of assets under capital lease was $45 million ($46 million as at December 31, 2017), net of accumulated amortization of $672 million ($684 million as at December 31, 2017). Liabilities for the capital lease arrangements are included in other liabilities and provisions in the Condensed Consolidated Balance Sheet and are disclosed in Note 11.

Other Arrangement

As at March 31, 2018, Corporate and Other property, plant and equipment and total assets include a carrying value of $1,216 million ($1,255 million as at December 31, 2017) related to The Bow office building, which is under a 25-year lease agreement. The Bow asset is being depreciated over the 60-year estimated life of the building. At the conclusion of the 25-year term, the remaining asset and corresponding liability are expected to be derecognized as disclosed in Note 11.

19

10.   Long-Term Debt

	As at		As at
	March 31,		December 31,
	2018		2017
U.S. Dollar Denominated Debt
U.S. Unsecured Notes:
6.50% due May 15, 2019	$	500	$	500
3.90% due November 15, 2021		600		600
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		4,211		4,211
Increase in Value of Debt Acquired		25		26
Unamortized Debt Discounts and Issuance Costs		(38)		(40)
Current Portion of Long-Term Debt		-		-
	$	4,198	$	4,197

As at March 31, 2018, total long-term debt had a carrying value of $4,198 million and a fair value of $4,909 million (as at December 31, 2017 - carrying value of $4,197 million and a fair value of $5,042 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.

11.   Other Liabilities and Provisions

	As at		As at
	March 31,		December 31,
	2018		2017
The Bow Office Building	$	1,304	$	1,344
Capital Lease Obligations		275		295
Unrecognized Tax Benefits		197		202
Pensions and Other Post-Employment Benefits		116		116
Long-Term Incentive Costs (See Note 16)		32		175
Other Derivative Contracts (See Notes 18, 19)		13		14
Other		21		21
	$	1,958	$	2,167

20

The Bow Office Building

As described in Note 9, Encana has recognized the accumulated costs for The Bow office building, which is under a 25-year lease agreement. At the conclusion of the lease term, the remaining asset and corresponding liability are expected to be derecognized. Encana has also subleased approximately 50 percent of The Bow office space under the lease agreement. The total expected future principal and interest payments related to the 25-year lease agreement and the total undiscounted future amounts expected to be recovered from the sublease are outlined below.

	2018			2019			2020			2021			2022			Thereafter			Total
Expected Future Lease Payments	$	55		$	75		$	75		$	76		$	76		$	1,260		$	1,617
Less: Amounts Representing Interest		47			63			61			61			60			781			1,073
Present Value of Expected Future Lease Payments	$	8		$	12		$	14		$	15		$	16		$	479		$	544
Sublease Recoveries (undiscounted)	$	(27	)	$	(37	)	$	(37	)	$	(37	)	$	(38	)	$	(619	)	$	(795	)
Capital Lease Obligations
As described in Note 9, the Company has several lease arrangements that are accounted for as capital leases including an office building and the Deep Panuke offshore Production Field Centre (“PFC”). Variable interests related to the PFC are described in Note 15.
The total expected future lease payments related to the Company’s capital lease obligations are outlined below.
	2018			2019			2020			2021			2022			Thereafter			Total
Expected Future Lease Payments	$	75		$	99		$	99		$	87		$	8		$	38		$	406
Less: Amounts Representing Interest		15			15			10			4			2			5			51
Present Value of Expected Future Lease Payments	$	60		$	84		$	89		$	83		$	6		$	33		$	355

12.   Asset Retirement Obligation

	As at March 31, 2018			As at December 31, 2017
Asset Retirement Obligation, Beginning of Year	$	514		$	687
Liabilities Incurred and Acquired		5			11
Liabilities Settled and Divested		(4	)		(333	)
Change in Estimated Future Cash Outflows		-			88
Accretion Expense		8			37
Foreign Currency Translation		(11	)		24
Asset Retirement Obligation, End of Period	$	512		$	514
Current Portion	$	69		$	44
Long-Term Portion		443			470
	$	512		$	514

21

13.   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 March 31, 2018						As at December 31, 2017
	Number (millions)			Amount			Number (millions)		Amount
Common Shares Outstanding, Beginning of Year		973.1		$	4,757			973.0	$	4,756
Common Shares Purchased		(10.0	)		(50	)		-		-
Common Shares Issued Under Dividend Reinvestment Plan		-			-			0.1		1
Common Shares Outstanding, End of Period		963.1		$	4,707			973.1	$	4,757

During the three months ended March 31, 2018, Encana issued 23,023 common shares totaling $0.3 million under the Company’s dividend reinvestment plan (“DRIP”). During the twelve months ended December 31, 2017, Encana issued 58,480 common shares totaling $0.6 million under the DRIP.

Dividends

During the three months ended March 31, 2018, Encana paid dividends of $0.015 per common share totaling $15 million (2017 - $0.015 per common share totaling $15 million). For the three months ended March 31, 2018, the dividends paid included $0.3 million in common shares issued in lieu of cash dividends under the DRIP (2017 - $0.2 million).

On April 30, 2018, the Board of Directors declared a dividend of $0.015 per common share payable on June 29, 2018 to common shareholders of record as of June 15, 2018.

Normal Course Issuer Bid

On February 26, 2018, the Company announced it received approval from the TSX to purchase, for cancellation, up to 35 million common shares pursuant to a normal course issuer bid (“NCIB”) over a 12-month period from February 28, 2018 to February 27, 2019. The Company has authorization from its Board to spend up to $400 million on the NCIB.

All purchases are 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, and any excess is allocated to retained earnings/accumulated deficit.

During the three months ended March 31, 2018, the Company purchased 10 million common shares for total consideration of approximately $111 million. Of the amount paid, $50 million was charged to share capital and $61 million was charged to accumulated deficit.

22

Earnings Per Common Share

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

	Three Months Ended March 31,
(US$ millions, except per share amounts)	2018		2017
Net Earnings (Loss)	$	151	$	431
Number of Common Shares:
Weighted average common shares outstanding - Basic		971.5		973.0
Effect of dilutive securities		-		-
Weighted average common shares outstanding - Diluted		971.5		973.0
Net Earnings (Loss) per Common Share Basic & Diluted	$	0.16	$	0.44

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 March 31, 2018 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.

In addition, certain stock options granted are performance-based whereby vesting is also subject to Encana attaining prescribed performance relative to predetermined key measures. 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 (“RSUs”)

Encana has a share-based compensation plan whereby eligible employees and Directors are granted 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 of the RSU Plan and Grant Agreement. The Company currently settles vested RSUs in cash. As a result, RSUs are not considered potentially dilutive securities.

23

14.    Accumulated Other Comprehensive Income

	Three Months Ended March 31,
	2018			2017
Foreign Currency Translation Adjustment
Balance, Beginning of Year	$	1,029		$	1,200
Change in Foreign Currency Translation Adjustment		24			(16	)
Balance, End of Period	$	1,053		$	1,184
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Year	$	13		$	10
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 17)		(1	)		(1	)
Income Taxes		-			-
Balance, End of Period	$	12		$	9
Total Accumulated Other Comprehensive Income	$	1,065		$	1,193

15.   Variable Interest Entities

Production Field Centre

In 2008, Encana entered into a contract for the design, construction and operation of the PFC at its Deep Panuke facility. Upon commencement of operations in December 2013, Encana recognized the PFC as a capital lease asset. Under the lease contract, Encana has a purchase option and the option to extend the lease for 12 one-year terms at fixed prices after the initial lease term expires in 2021.

As a result of the purchase option and fixed price renewal options, Encana has determined it holds variable interests and that the related leasing entity qualifies as a variable interest entity (“VIE”). Encana is not the primary beneficiary of the VIE as the Company does not have the power to direct the activities that most significantly impact the VIE’s economic performance. Encana is not required to provide any financial support or guarantees to the leasing entity or its affiliates, other than the contractual payments under the lease and operating agreements. Encana’s maximum exposure is the expected lease payments over the initial contract term. As at March 31, 2018, Encana had a capital lease obligation of $296 million ($314 million as at December 31, 2017) related to the PFC.

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 March 31, 2018, VMLP provides approximately 1,110 MMcf/d of natural gas gathering and compression and 600 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from up to 13 to 27 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.

24

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 $2,390 million as at March 31, 2018. 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 21 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 March 31, 2018, there were no accounts payable and accrued liabilities outstanding related to the take or pay commitment.

16.   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 held by employees 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 held by employees:

	As at March 31, 2018				As at March 31, 2017
	US$ Share Units		C$ Share Units		US$ Share Units		C$ Share Units
Risk Free Interest Rate		1.79%		1.79%		0.74%		0.74%
Dividend Yield		0.55%		0.54%		0.51%		0.51%
Expected Volatility Rate (1)		58.46%		54.78%		58.12%		54.02%
Expected Term		2.0 yrs		2.1 yrs		1.9 yrs		1.9 yrs
Market Share Price		US$11.00		C$14.17		US$11.71		C$15.58

(1) Volatility was estimated using historical rates.

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

	Three Months Ended March 31,
	2018			2017
Total Compensation Costs of Transactions Classified as Cash-Settled	$	(27	)	$	34
Less: Total Share-Based Compensation Costs Capitalized		9			(11	)
Total Share-Based Compensation Expense (Recovery)	$	(18	)	$	23
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	(6	)	$	8
Administrative		(12	)		15
	$	(18	)	$	23

25

As at March 31, 2018, the liability for share-based payment transactions totaled $217 million ($327 million as at December 31, 2017), of which $185 million ($152 million as at December 31, 2017) is recognized in accounts payable and accrued liabilities and $32 million ($175 million as at December 31, 2017) is recognized in other liabilities and provisions in the Condensed Consolidated Balance Sheet.

	As at  March 31,  2018		As at December 31, 2017
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested	$	167	$	274
Vested		50		53
	$	217	$	327

The following units were granted primarily in conjunction with the Company’s February annual long-term incentive award. 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.

Three Months Ended March 31, 2018 (thousands of units)
TSARs	872
SARs	359
PSUs	2,503
DSUs	31
RSUs	5,238

17.    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 three months ended March 31 as follows:

	Pension Benefits				OPEB				Total
	2018		2017		2018		2017		2018		2017
Net Defined Periodic Benefit Cost	$	-	$	-	$	2	$	2	$	2	$	2
Defined Contribution Plan Expense		6		6		-		-		6		6
Total Benefit Plans Expense	$	6	$	6	$	2	$	2	$	8	$	8

Of the total benefit plans expense, $6 million (2017 - $6 million) was included in operating expense and $2 million (2017 - $2 million) was included in administrative expense.

26

The net defined periodic benefit cost for the three months ended March 31 is as follows:

	Defined Benefits				OPEB				Total
	2018		2017		2018		2017		2018		2017
Service Cost	$	-	$	-	$	2	$	2	$	2	$	2
Interest Cost		2		2		1		1		3		3
Expected Return on Plan Assets		(2)		(2)		-		-		(2)		(2)
Amounts Reclassified from Accumulated Other Comprehensive Income:
Amortization of net actuarial (gains) and losses		-		-		(1)		(1)		(1)		(1)
Total Net Defined Periodic Benefit Cost (1)	$	-	$	-	$	2	$	2	$	2	$	2

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

18.   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.

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note 19. 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, transportation and processing expense, and foreign exchange gains and losses according to their purpose.

As at March 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	$	-	$	267	$	-	$	267	$	(53	)	$	214
Long-term assets		-		298		-		298		(8	)		290
Foreign Currency Derivatives:
Current assets		-		12		-		12		-			12
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	241	$	62	$	303	$	(53	)	$	250
Long-term liabilities		-		25		-		25		(8	)		17
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-		$	5
Long-term in other liabilities and provisions		-		13		-		13		-			13

(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.

27

As at December 31, 2017	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	$	-	$	189	$	-	$	189	$	(15	)	$	174
Long-term assets		-		248		-		248		(2	)		246
Foreign Currency Derivatives:
Current assets		-		31		-		31		-			31
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	3	$	196	$	51	$	250	$	(15	)	$	235
Long-term liabilities		-		15		-		15		(2	)		13
Foreign Currency Derivatives:
Current liabilities		-		1		-		1		-			1
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-		$	5
Long-term in other liabilities and provisions		-		14		-		14		-			14

(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 call options, foreign currency swaps and basis swaps with terms to 2023. Level 2 also includes financial guarantee contracts as discussed in Note 19. The fair values of these contracts are based on a market approach and are estimated using inputs which are either directly or indirectly observable at the reporting date, such as exchange and other published prices, broker quotes and observable trading activity.

Level 3 Fair Value Measurements

As at March 31, 2018, the Company’s Level 3 risk management assets and liabilities consist of WTI three-way options and WTI costless collars with terms to 2018. 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.

28

A summary of changes in Level 3 fair value measurements for the three months ended March 31 is presented below:

					Risk Management
					2018		2017
Balance, Beginning of Year					$	(51)	$                  (36)
Total Gains (Losses)						6	41
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances						-	-
Settlements						(17)	-
Transfers Out of Level 3 (1)						-	-
Balance, End of Period					$	(62)	$                     5
Change in Unrealized Gains (Losses) Related to Assets and Liabilities Held at End of Period					$	(24)	$                   40
(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:
					As at		As at
					March 31,		December 31,
	Valuation Technique		Unobservable Input		2018		2017
Risk Management - WTI Options		Option Model		Implied Volatility		24% - 83%	17% - 76%

A 10 percent increase or decrease in implied volatility for the WTI options would cause a corresponding $1 million ($2 million as at December 31, 2017) increase or decrease to net risk management assets and liabilities.

19.   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, 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 and options. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

29

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 March 31, 2018, Encana has entered into $538 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7606 to C$1, which mature monthly through the remainder of 2018.

Risk Management Positions as at March 31, 2018

	Notional Volumes		Term		Average Price	Fair Value
Crude Oil and NGL Contracts					US$/bbl
Fixed Price Contracts
WTI Fixed Price		94.3 Mbbls/d		2018	55.53	$	(194	)
WTI Fixed Price		15.0 Mbbls/d		2019	58.30		(2	)
WTI Fixed Price Swaptions (1)		24.0 Mbbls/d		Q1 - Q2 2019	63.13		(16	)
WTI Three-Way Options
Sold call / bought put / sold put		16.0 Mbbls/d		2018	54.49 / 47.17 / 36.88		(42	)
WTI Costless Collars
Sold call / bought put		10.0 Mbbls/d		2018	57.08 / 45.00		(20	)
Basis Contracts (2)				2018 - 2020			26
Crude Oil and NGLs Fair Value Position							(248	)
Natural Gas Contracts					US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price		1,007 MMcf/d		2018	3.02		52
NYMEX Fixed Price Swaptions (3)		300 MMcf/d		Q1 - Q2 2019	2.99		(9	)
NYMEX Call Options
Sold call price		230 MMcf/d		2018	3.75		(1	)
Sold call price		64 MMcf/d		2019	3.75		(4	)
Sold call price		166 MMcf/d		2020	3.25		(1	)
Basis Contracts (4)				2018			130
				2019			136
				2020			99
				2021 - 2023			86
Premiums Received on Unexpired Options							(3	)
Natural Gas Fair Value Position							485
Other Derivative Contracts
Fair Value Position							(18	)
Foreign Currency Contracts
Fair Value Position (5)				2018			12
Total Fair Value Position						$	231

(1) WTI Fixed Price Swaptions give the counterparty the option to extend certain Q3 - Q4 2018 Fixed Price swaps to Q1- Q2 2019.

(2) Encana has entered into swaps to protect against widening Midland, Magellan East Houston, Louisiana Light Sweet and Edmonton Condensate differentials to WTI.

(3) NYMEX Fixed Price Swaptions give the counterparty the option to extend certain Q3 - Q4 2018 Fixed Price swaps to Q1- Q2 2019.

(4) Encana has entered into swaps to protect against widening AECO, Dawn, Malin and Waha basis to 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.

30

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

	Three Months Ended March 31,
	2018			2017
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	(32	)	$	(24	)
Transportation and processing		-			(4	)
Foreign Currency Derivatives:
Foreign exchange		7			1
	$	(25	)	$	(27	)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	68		$	362
Foreign Currency Derivatives:
Foreign exchange		(18	)		2
	$	50		$	364
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	36		$	338
Transportation and processing		-			(4	)
Foreign Currency Derivatives:
Foreign exchange		(11	)		3
	$	25		$	337

(1) Includes a realized gain of $1 million (2017 - gain of $2 million) related to other derivative contracts.

(2) Includes an unrealized gain of nil (2017 - nil) related to other derivative contracts.

Reconciliation of Unrealized Risk Management Positions from January 1 to March 31

	2018					2017
	Fair Value			Total Unrealized Gain (Loss)		Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	183
Change in Fair Value of Contracts in Place at Beginning of Year and Contracts Entered into During the Period		25		$	25	$	337
Settlement of Other Derivative Contracts		1
Fair Value of Contracts Realized During the Period		25			25		27
Fair Value of Contracts Outstanding	$	234		$	50	$	364
Premiums Received on Unexpired Options		(3	)
Fair Value of Contracts and Premiums Received, End of Period	$	231

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value. See Note 18 for a discussion of fair value measurements.

31

Unrealized Risk Management Positions

	As at March 31, 2018		As at December 31, 2017
Risk Management Assets
Current	$	226	$	205
Long-term		290		246
		516		451
Risk Management Liabilities
Current		250		236
Long-term		17		13
		267		249
Other Derivative Contracts
Current in accounts payable and accrued liabilities		5		5
Long-term in other liabilities and provisions		13		14
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	231	$	183

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 New York Stock Exchange 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 18. As at March 31, 2018, the Company had no significant credit derivatives in place and held no collateral.

As at March 31, 2018, 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 March 31, 2018, approximately 93 percent (92 percent as at December 31, 2017) of Encana’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

As at March 31, 2018, Encana had two 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. As at March 31, 2018, these counterparties accounted for 53 percent and 11 percent of the fair value of the outstanding in-the-money net risk management contracts. As at December 31, 2017, Encana had three counterparties whose net settlement position accounted for 56 percent, 11 percent and 11 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 three to six years with a fair value recognized of $18 million as at March 31, 2018 ($19 million as at December 31, 2017). The maximum potential amount of undiscounted future payments is $317 million as at March 31, 2018, and is considered unlikely.

32

20.   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 March 31,
	2018			2017
Operating Activities
Accounts receivable and accrued revenues	$	(2	)	$	70
Accounts payable and accrued liabilities		(7	)		(134	)
Income tax receivable and payable		1			(96	)
	$	(8	)	$	(160	)

B) Non-Cash Activities

	Three Months Ended March 31,
	2018			2017
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 12)	$	5		$	3
Property, plant and equipment accruals		9			44
Capitalized long-term incentives		(36	)		11
Property additions/dispositions (swaps)		49			6
Non-Cash Financing Activities
Common shares issued under dividend reinvestment plan (See Note 13)	$	-		$	-

33

21.   Commitments and Contingencies

Commitments

The following table outlines the Company’s commitments as at March 31, 2018:

	Expected Future Payments
(undiscounted)	2018		2019		2020		2021		2022		Thereafter		Total
Transportation and Processing	$	446	$	692	$	663	$	579	$	551	$	2,458	$	5,389
Drilling and Field Services		165		46		24		9		-		-		244
Operating Leases		13		16		16		15		15		46		121
Total	$	624	$	754	$	703	$	603	$	566	$	2,504	$	5,754

Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note 15. 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 unfavourable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures. If an unfavourable 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.

34

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 March 31, 2018 (“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, 2017, which are included in Items 8 and 7, respectively, of the 2017 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 disciplined focus on generating profitable growth. The Company is pursuing the key business objectives of exercising a disciplined capital allocation strategy by investing in a limited number of core assets, growing high margin liquids volumes, maximizing profitability through operating efficiencies and reducing costs, and preserving balance sheet strength.

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 unified team.

Encana continually reviews and evaluates its strategy and changing market conditions. In 2018, Encana continues to focus on quality growth from high margin, scalable projects located in some of the best plays in North America, referred to as the “Core Assets”, comprising Montney and Duvernay in Canada and Eagle Ford and Permian in the U.S. These world-class assets form a multi-basin portfolio enabling flexible and efficient investment of capital. The Company rapidly deploys successful ideas and practices across these assets, becoming more efficient as innovative and sustainable technical improvements are implemented.

For additional information on Encana’s strategy, its reporting segments and the plays in which the Company operates, refer to Items 1 and 2 of the 2017 Annual Report on Form 10-K. In evaluating its operations and assessing its leverage, the Company reviews performance-based measures such as Non-GAAP Cash Flow and Non-GAAP Cash Flow Margin 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. Further information regarding these measures, including reconciliations to the closest GAAP measure, can be found in the Non-GAAP Measures section of this MD&A.

35

Highlights

During the first quarter of 2018, Encana focused on executing its 2018 capital plan, maintaining operational efficiencies achieved in 2017 and minimizing the effect of inflationary costs. Higher oil and NGL benchmark prices during the first quarter of 2018 compared to 2017 contributed to increases in Encana’s average realized oil and NGL prices of 28 percent and 21 percent, respectively, resulting in higher revenues. Encana is also focused on the diversification of the Company’s downstream markets to capture higher realized prices. Encana remains committed to delivering a business model that allows the Company to adapt to fluctuating commodity prices.

Significant Developments

· Received approval from the TSX to purchase, for cancellation, up to 35 million common shares pursuant to a NCIB over a 12-month period from February 28, 2018 to February 27, 2019. As of March 31, 2018, the Company has purchased 10 million common shares for total consideration of approximately $111 million.

Financial Results

· Reported net earnings of $151 million, including a net foreign exchange loss of $91 million, before tax, and net gains on risk management in revenues of $36 million, before tax.

· Generated cash from operating activities of $381 million, Non-GAAP Cash Flow of $400 million and Non-GAAP Cash Flow Margin of $13.70 per BOE.

· Paid dividends of $0.015 per common share.

· Held cash and cash equivalents of $433 million and had available credit facilities of $4.0 billion for total liquidity of $4.4 billion at March 31, 2018.

Capital Investment

· Commenced the Company’s 2018 capital plan with expenditures totaling $508 million of which $393 million, or 77 percent, was directed to the Permian and Montney.

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

Production

· Produced average oil and NGL volumes of 145.2 Mbbls/d which accounted for 45 percent of total production volumes. Average oil and plant condensate production volumes of 113.2 Mbbls/d were 78 percent of total liquids production volumes.

· Produced average natural gas volumes of 1,075 MMcf/d which accounted for 55 percent of total production volumes.

Operating Expenses

· Focused on maintaining operational efficiencies achieved in previous years and minimizing the effect of inflationary costs.

· Increased transportation and processing expense by $37 million, or 17 percent, primarily due to higher volumes in Montney and additional costs incurred in conjunction with the diversification of downstream markets to capture higher realized prices.

36

2018 Outlook

Industry Outlook

The oil and gas industry is cyclical and commodity prices are inherently volatile. Oil prices during 2018 are expected to reflect global supply and demand dynamics as well as the geopolitical environment. At a meeting in November 2017, OPEC and certain non-OPEC countries agreed to further extend an agreement to voluntarily cut crude oil production through the end of 2018. The agreement and recent drawdowns of oil storage inventory levels were generally supportive of oil prices in the first quarter of 2018; however, production growth in other countries continues to partially offset the expected benefit of the OPEC agreement. OPEC is scheduled to meet again in June 2018 to review production levels and a decision to discontinue or reduce the production cuts could negatively impact oil prices in 2018.

Natural gas prices in 2018 will be affected by the timing of supply and demand growth. Natural gas prices in western Canada have seen significant negative price pressure as supply reached multi-year highs, surpassing regional demand and stressing effective pipeline capacity. Stronger condensate prices may also lend support to activity levels resulting in additional downward pressure on natural gas prices in 2018. Natural gas prices in the U.S. have remained flat. Potential for improvement in U.S. natural gas prices remains limited due to continued substantial production increases in Northeast U.S. and associated gas production in the Permian Basin.

Company Outlook

Encana is positioned to be flexible in the current price environment in order to continue to achieve strong returns. 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 March 31, 2018, the Company has hedged approximately 120 Mbbls/d of expected oil and condensate production and 1,026 MMcf/d of expected natural gas production for the remainder of 2018 using a variety of structures at average prices of $55.52 per bbl and $3.02 per Mcf, respectively.

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, natural gas may vary between geographic regions depending on local supply and demand conditions. Encana proactively utilizes transportation contracts to diversify the Company’s downstream markets and reduce 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 2018 and 2019. In addition, Encana continues to seek new markets to yield higher returns.

Capital Investment

Encana is on track to meet its full year capital investment guidance of $1.8 billion to $1.9 billion. During the first quarter of 2018, the Company spent $508 million, of which $238 million was directed to Permian where the Company has drilled 26 net wells and $155 million was directed to Montney with 40 net wells drilled. Capital investment in Permian is expected to be optimized by Encana’s cube development approach to maximize returns and recovery. Capital investment in Montney is expected to be allocated to both Cutbank Ridge and Pipestone with a focus on growing condensate volumes.

Encana continually strives to improve well performance by lowering drilling and completion 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 impact of Encana’s disciplined capital program and continuous innovation create flexibility and opportunity to grow cash flows and production volumes going forward.

Production

As part of the Company’s long-term growth strategy, Encana has significantly shifted its production mix to a more balanced portfolio in the recent years, thereby reducing the extent of exposure to market volatility of a particular commodity. During the first quarter of 2018, average liquids production volumes were 145.2 Mbbls/d and average natural gas production volumes were 1,075 MMcf/d. The Company expects to deliver substantial liquids growth in the second half of 2018. The Company is on track to meet the full year 2018 guidance ranges for liquids production volumes of 165.0 Mbbls/d to 175.0 Mbbls/d and natural gas production volumes of 1,150 MMcf/d to 1,250 MMcf/d

37

by year end as a result of the Company’s growth plans for Montney. Encana’s growth plans for Montney are supported by third party processing plants commissioned in 2017 and two additional facilities expected to be completed in the second half of 2018, including the planned completion of the Pipestone liquids hub in the fourth quarter.

Operating Expenses

Efficiency improvements and lower service costs are expected to be maintained through the support of the Company’s culture of innovation and its focus on continuous improvement in operational execution. As activity in the industry accelerates, Encana expects to continue pursuing innovative ways to reduce upstream operating and administrative expenses. Operating costs in the first quarter of 2018 are on track to meet the full year 2018 guidance ranges. Transportation and processing expense was $7.42 per BOE, while upstream operating expense and administrative expense, excluding long-term incentive costs, were $3.60 per BOE and $1.49 per BOE, respectively.

Service costs are expected to increase with higher activity in the oil and gas industry and the recovery of commodity prices. Encana continues to offset any inflationary pressures with efficiency improvements and effective supply chain management, including favorable price negotiations.

Further information on Encana’s 2018 Corporate Guidance can be accessed on the Company’s website at www.encana.com.

Results of Operations

Selected Financial Information

	Three months ended March 31,
($ millions)		2018		2017 (1)
Product and Service Revenues
Upstream product revenues	$	957	$	738
Market optimization		301		186
Service revenues		2		10
Total Product and Service Revenues		1,260		934
Gains (Losses) on Risk Management, Net		36		338
Sublease Revenues		17		17
Total Revenues		1,313		1,289
Total Operating Expenses (2)		976		800
Operating Income (Loss)		337		489
Total Other (Income) Expenses		177		55
Net Earnings (Loss) Before Income Tax	$	160	$	434
Net Earnings (Loss)	$	151	$	431
(1) Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net. The remaining Q1 2017 revenues have been realigned to conform with the current year presentation. (2) Total Operating Expenses include non-cash items such as DD&A, impairments, accretion of asset retirement obligations and long-term incentive costs.

38

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. Canadian Operations realized prices are linked to Edmonton Condensate and AECO, as well as other downstream natural gas benchmarks, including Dawn, which reflect the diversification of the Company’s markets. The USA Operations realized prices generally reflect WTI and NYMEX benchmark prices. Realized NGL prices are significantly influenced by oil 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 March 31,
(average for the period)	2018		2017
Oil & NGLs
WTI ($/bbl)	$	62.87	$	51.91
Edmonton Condensate (C$/bbl)		79.72		69.13
Natural Gas
NYMEX ($/MMBtu)	$	3.00	$	3.32
AECO (C$/Mcf)		1.85		2.94
Dawn (C$/MMBtu)		3.82		4.23

39

Production Volumes and Realized Prices

	Production Volumes (1)				Realized Prices (2)
Three months ended March 31,	2018		2017		2018			2017
Oil (Mbbls/d, $/bbl)
Canadian Operations		0.4		0.4		$	55.47		$	43.29
USA Operations		82.6		67.0			63.33			49.65
Total		83.0		67.4			63.29			49.61
NGLs – Plant Condensate (Mbbls/d, $/bbl)
Canadian Operations		27.5		18.7			61.10			50.29
USA Operations		2.7		1.8			51.94			42.87
Total		30.2		20.5			60.28			49.63
NGLs – Other (Mbbls/d, $/bbl)
Canadian Operations		10.4		5.0			30.08			22.62
USA Operations		21.6		18.0			20.53			20.11
Total		32.0		23.0			23.64			20.66
Total NGLs (Mbbls/d, $/bbl)
Canadian Operations		37.9		23.7			52.55			44.40
USA Operations		24.3		19.8			24.01			22.22
Total		62.2		43.5			41.40			34.31
Total Oil & NGLs (Mbbls/d, $/bbl)
Canadian Operations		38.3		24.1			52.58			44.38
USA Operations		106.9		86.8			54.39			43.36
Total		145.2		110.9			53.91			43.59
Natural Gas (MMcf/d, $/Mcf)
Canadian Operations		936		885			2.48			2.52
USA Operations		139		356			2.52			3.23
Total		1,075		1,241			2.48			2.72
Total Production (MBOE/d, $/BOE)
Canadian Operations		194.3		171.7			22.29			19.23
USA Operations		130.1		146.2			47.39			33.59
Total		324.4		317.9			32.35			25.82
Production Mix (%)
Oil & Plant Condensate		35		28
NGLs – Other		10		7
Total Oil & NGLs		45		35
Natural Gas		55		65
Core Assets Production
Oil (Mbbls/d)		80.4		62.3
NGLs – Plant Condensate (Mbbls/d)		30.2		20.0
NGLs – Other (Mbbls/d)		30.9		20.9
Total NGLs (Mbbls/d)		61.1		40.9
Total Oil & NGLs (Mbbls/d)		141.5		103.2
Natural Gas (MMcf/d)		996		804
Total Production (MBOE/d)		307.5		237.3
% of Total Encana Production		95		75
(1)   Average daily.    (2)   Average per-unit prices, excluding the impact of risk management activities.

40

Upstream Product Revenues

	Three months ended March 31,
($ millions)	Oil			NGLs (1)			Natural Gas (2)				Total
2017 Upstream Product Revenues		$	300		$	134		$	304			$	738
Increase (decrease) due to:
Sales prices			102			32			(5	)			129
Production volumes			72			65			(58	)			79
2018 Upstream Product Revenues		$	474		$	231		$	241			$	946
(1) Includes plant condensate.   (2) Natural gas revenues exclude a royalty adjustment of $11 million (2017 - nil) with no associated production volumes.

Oil Revenues

Three months ended March 31, 2018 versus March 31, 2017

Oil revenues increased $174 million compared to the first quarter of 2017 primarily due to:

· Higher average realized oil prices of $13.68 per bbl, or 28 percent, increased revenues by $102 million. The increase reflected a higher WTI benchmark price which was up 21 percent. The increase was also due to improved regional pricing in the USA Operations; and

· Higher average oil production volumes of 15.6 Mbbls/d increased revenues by $72 million. Higher volumes were primarily due to a successful drilling program in Permian (18.9 Mbbls/d), partially offset by asset sales (2.4 Mbbls/d), which mainly include the Tuscaloosa Marine Shale assets in the second quarter of 2017.

NGL Revenues

Three months ended March 31, 2018 versus March 31, 2017

NGL revenues increased $97 million compared to the first quarter of 2017 primarily due to:

· Higher average realized NGL prices of $7.09 per bbl, or 21 percent, increased revenues by $32 million. The increase reflected higher Edmonton Condensate and WTI benchmark prices which were up 15 percent and 21 percent, respectively, as well as improved regional pricing; and

· Higher average NGL production volumes of 18.7 Mbbls/d increased revenues by $65 million. Higher volumes were primarily due to successful drilling programs in Montney and Permian (21.0 Mbbls/d), partially offset by asset sales (1.6 Mbbls/d), which mainly include the Piceance natural gas assets in the third quarter of 2017.

Natural Gas Revenues

Three months ended March 31, 2018 versus March 31, 2017

Natural gas revenues decreased $63 million compared to the first quarter of 2017 primarily due to:

· Lower average realized natural gas prices of $0.24 per Mcf, or nine percent, decreased revenues by $5 million. The decrease reflected lower NYMEX and AECO benchmark prices which were down 10 percent and 37 percent, respectively, partially offset by relatively higher other downstream benchmark prices in 2018 resulting from the diversification of the Company’s markets; and

· Lower average natural gas production volumes of 166 MMcf/d decreased revenues by $58 million. Lower volumes were primarily due to asset sales (305 MMcf/d), which mainly include the Piceance natural gas assets in the third quarter of 2017 and certain assets in Wheatland in the fourth quarter of 2017, and lower activity in Other Upstream Operations (74 MMcf/d), partially offset by successful drilling in Montney and Permian (199 MMcf/d).

41

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, NGLs and natural gas production volumes. The Company’s commodity price mitigation program reduces volatility and helps sustain revenues during periods of lower prices. Further information on the Company’s commodity price positions as at March 31, 2018 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.

The following table provides the effects of Encana’s risk management activities on revenues.

	$ millions				Per-Unit
Three months ended March 31,	2018		2017		2018		2017
Realized Gains (Losses) on Risk Management
Commodity Price
Oil ($/bbl)	$	(56)	$	-	$	(7.55)	$             0.05
NGLs ($/bbl) (1)		(21)		(1)	$	(3.77)	$           (0.42)
Natural Gas ($/Mcf)		44		(25)	$	0.46	$           (0.22)
Other (2)		1		2	$	-	$                  -
Total ($/BOE)		(32)		(24)	$	(1.13)	$           (0.91)
Unrealized Gains (Losses) on Risk Management		68		362
Total Gains (Losses) on Risk Management, Net	$	36	$	338
(1)   Includes plant condensate. (2)   Other includes realized gains or losses from 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.

Market Optimization Revenues

Market Optimization revenues relate to activities that provide operational flexibility and cost mitigation for transportation commitments, product type, delivery points and customer diversification.

	Three months ended March 31,
($ millions)	2018		2017
Market Optimization	$	301	$	186

Three months ended March 31, 2018 versus March 31, 2017

Market Optimization revenues increased $115 million compared to the first quarter of 2017 primarily due to:

· Higher sales of third-party purchased volumes, primarily related to natural gas, used for optimization activities and long-term marketing arrangements associated with the Company’s previous divestitures ($168 million), partially offset by lower natural gas commodity prices ($53 million).

42

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. Further information on The Bow office sublease can be found in Note 11 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

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.

	$ millions				$/BOE
Three months ended March 31,	2018		2017		2018		2017
Canadian Operations	$	4	$	5	$	0.23	$	0.30
USA Operations		25		24	$	2.12	$	1.84
Total	$	29	$	29	$	0.99	$	1.01

Three months ended March 31, 2018 versus March 31, 2017

Production, mineral and other taxes were flat compared to the first quarter of 2017 primarily due to:

· Higher oil prices and production volumes in Permian ($7 million);

partially offset by:

· Asset sales ($6 million), which mainly include the Piceance natural gas assets in the third quarter of 2017 and certain assets in Wheatland in the fourth quarter of 2017.

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.

	$ millions				$/BOE
Three months ended March 31,	2018		2017		2018		2017
Canadian Operations	$	190	$	132	$	10.87	$	8.56
USA Operations		27		59	$	2.26	$	4.44
Upstream Transportation and Processing		217		191	$	7.42	$	6.67
Market Optimization		32		21
Corporate and Other		-		-
Total	$	249	$	212

43

Three months ended March 31, 2018 versus March 31, 2017

Transportation and processing expense increased $37 million compared to the first quarter of 2017 primarily due to:

· Higher downstream processing and transportation costs mainly in Montney and Duvernay due to Encana’s focus on liquids rich wells in the plays and costs relating to the diversification of the Company’s downstream markets ($39 million), higher volumes and gathering and processing fees in Montney ($28 million), higher volumes in Permian ($6 million) and the higher U.S./Canadian dollar exchange rate ($6 million);

partially offset by:

· Asset sales ($30 million), which mainly include the Piceance natural gas assets in the third quarter of 2017 and lower activity in Other Upstream Operations ($10 million).

Operating

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

	$ millions				$/BOE
Three months ended March 31,	2018		2017		2018		2017
Canadian Operations	$	29	$	31	$	1.59	$	1.91
USA Operations		74		87	$	6.28	$	6.43
Upstream Operating Expense (1)		103		118	$	3.47	$	3.99
Market Optimization		4		9
Corporate and Other		4		5
Total	$	111	$	132

(1) Upstream Operating Expense per BOE for the first quarter of 2018 includes a recovery of long-term incentive costs of $0.13/BOE (2017 - long-term incentive costs of $0.17/BOE).

Three months ended March 31, 2018 versus March 31, 2017

Operating expense decreased $21 million compared to the first quarter of 2017 primarily due to:

· Asset sales ($24 million), which mainly include the Piceance natural gas assets in the third quarter of 2017 and certain assets in Wheatland in the fourth quarter of 2017, and a recovery of long-term incentive costs resulting from the decrease in Encana’s share price in the first quarter of 2018 ($14 million). Further information on Encana’s long-term incentives can be found in Note 16 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

partially offset by:

· Higher activity in Permian and Montney ($12 million).

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.

	Three months ended March 31,
($ millions)	2018		2017
Market Optimization	$	273	$	171

44

Three months ended March 31, 2018 versus March 31, 2017

Purchased product expense increased $102 million compared to the first quarter of 2017 primarily due to:

· Higher third-party volumes purchased, primarily related to natural gas, for optimization activities and long-term marketing arrangements associated with the Company’s previous divestitures ($163 million), partially offset by lower natural gas commodity prices ($61 million).

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 2017 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. Additional information can be found in the Critical Accounting Estimates section of the MD&A included in Item 7 of the 2017 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.

	$ millions				$/BOE
Three months ended March 31,	2018		2017		2018		2017
Canadian Operations	$	77	$	64	$	4.39	$	4.11
USA Operations		185		106	$	15.84	$	8.09
Upstream DD&A		262		170	$	8.98	$	5.93
Corporate and Other		13		17
Total	$	275	$	187

Three months ended March 31, 2018 versus March 31, 2017

DD&A increased $88 million compared to the first quarter of 2017 primarily due to:

· Higher depletion rates primarily in the USA Operations ($91 million).

The depletion rate increased $3.05 per BOE compared to the first quarter of 2017 primarily due to:

· Lower reserve volumes from the sale of the Piceance natural gas assets in the third quarter of 2017.

Administrative

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

	Three months ended March 31,
	2018		2017
Administrative ($ millions)	$	31	$               58
Administrative ($/BOE) (1)	$	1.08	$            2.04
(1) Administrative expense per BOE for the first quarter of 2018 includes a recovery of long-term incentive costs of $0.41/BOE (2017 - long-term incentive costs of $0.54/BOE).

Three months ended March 31, 2018 versus March 31, 2017

Administrative expense in the first quarter of 2018 decreased $27 million compared to the first quarter of 2017 primarily due to a recovery of long-term incentive costs resulting from the decrease in Encana’s share price ($27 million).

45

Other (Income) Expenses

	Three months ended March 31,
($ millions)	2018			2017
Interest	$	92		$	88
Foreign exchange (gain) loss, net		91			(26	)
(Gain) loss on divestitures, net		(3	)		1
Other (gains) losses, net		(3	)		(8	)
Total Other (Income) Expenses	$	177		$	55

Foreign Exchange (Gain) Loss, Net

Foreign exchange gains and losses result from the impact of fluctuations in the Canadian to U.S. dollar exchange rate. Further details 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.

In the first quarter of 2018, Encana recorded a net foreign exchange loss compared to a net gain in 2017 ($117 million). The change was primarily due to unrealized foreign exchange losses on the translation of U.S. dollar financing debt issued from Canada compared to gains in 2017 ($155 million) and higher unrealized foreign exchange losses on the translation of intercompany notes ($18 million), partially offset by foreign exchange gains on the settlement of intercompany notes compared to losses in 2017 ($52 million).

46

Income Tax

	Three months ended March 31,
($ millions)	2018		2017
Current Income Tax Expense (Recovery)	$	3	$	(39	)
Deferred Income Tax Expense (Recovery)		6		42
Income Tax Expense (Recovery)	$	9	$	3
Effective Tax Rate		5.6%		0.7%

Income Tax Expense

Three months ended March 31, 2018 versus March 31, 2017

Current income tax in the first quarter of 2018 was an expense of $3 million compared to a recovery of $39 million in 2017. The current income tax recovery in 2017 resulted from the successful resolution of certain tax items previously assessed by the taxing authorities relating to prior taxation years.

Deferred income tax in the first quarter of 2018 was $36 million lower than 2017 primarily due to:

· Lower net earnings before income tax in 2018 compared to 2017; and

· A reduction in the U.S. federal corporate tax rate to 21 percent from 35 percent resulting from U.S. Tax Reform as enacted on December 22, 2017. Additional information on U.S. Tax Reform can be found in Note 6 to the Consolidated Financial Statements included in Item 8 of the 2017 Annual Report on Form 10-K.

There has been no change in the first quarter of 2018 to the provisional tax adjustment recognized in December 2017 resulting from the re-measurement of the Company’s tax position due to a reduction of the U.S. federal corporate tax rate under U.S. Tax Reform.

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 impacted by expected annual earnings, income tax related to foreign operations, the effect of legislative changes including U.S. Tax Reform, 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 was 5.6 percent for the first quarter of 2018, which is lower than the Canadian statutory rate of 27 percent primarily due to the impact of the foreign jurisdictional tax rates relative to the Canadian statutory tax rate applied to jurisdictional earnings as well as the items discussed above.

Tax interpretations, regulations and legislation, including U.S. Tax Reform and potential Treasury Department regulations and guidance, in the various jurisdictions in which the Company and its subsidiaries operate are subject to change and interpretation. 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.

47

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 bank 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 and share issuances to fund its operations or to manage its capital structure as discussed below. At March 31, 2018, $303 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 through a NCIB, issuing new debt or repaying existing debt.

	As at March 31,
($ millions, except as indicated)	2018		2017
Cash and Cash Equivalents	$	433	$          523
Available Credit Facility – Encana (1)		2,500	3,000
Available Credit Facility – U.S. Subsidiary (1)		1,500	1,500
Total Liquidity		4,433	5,023
Long-Term Debt		4,198	4,198
Total Shareholders’ Equity		6,776	6,525
Debt to Capitalization (%) (2)		38	39
Debt to Adjusted Capitalization (%) (3)		22	23
(1)   Collectively, the “Credit Facilities”. (2)   Calculated as long-term debt, including the current portion, divided by shareholders’ equity plus long-term debt, including the current portion. (3)   A non-GAAP measure which is defined in the Non-GAAP Measures section of this MD&A.

In the first quarter of 2018, the Company amended the capacity of its Encana Credit Facility from $3.0 billion to $2.5 billion and extended the maturity for both Credit Facilities to July 2022.

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. 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 12 to the Consolidated Financial Statements included in Item 8 of the 2017 Annual Report on Form 10-K.

48

Sources and Uses of Cash

In the first quarter of 2018, 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 March 31,
($ millions)	Activity Type		2018			2017
Sources of Cash and Cash Equivalents
Cash from operating activities		Operating	$	381		$	106
Proceeds from divestitures		Investing		19			3
Other		Investing		-			55
				400			164
Uses of Cash and Cash Equivalents
Capital expenditures		Investing		508			399
Acquisitions		Investing		2			46
Purchase of common shares		Financing		111			-
Dividends on common shares		Financing		15			15
Other		Investing/Financing		47			16
				683			476
Foreign Exchange Gain (Loss) on Cash and Cash Equivalents Held in Foreign Currency				(3	)		1
Increase (Decrease) in Cash and Cash Equivalents			$	(286	)	$	(311	)

Operating Activities

Cash from operating activities in the first quarter of 2018 was $381 million and was primarily a reflection of recovering commodity prices, the Company’s efforts in maintaining cost efficiencies achieved in previous years, changes in production volumes and changes in non-cash working capital. Additional detail on changes in non-cash working capital can be found in Note 20 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 first quarter of 2018 was $400 million 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 March 31, 2018 versus March 31, 2017

Net cash from operating activities in the first quarter of 2018 increased $275 million compared to the first quarter of 2017 primarily due to:

· Changes in non-cash working capital ($152 million), higher realized commodity prices ($129 million) and higher production volumes ($79 million).

partially offset by:

· A current tax expense in the first quarter of 2018 compared to a recovery in 2017 ($42 million), and higher transportation and processing expense ($37 million).

Investing Activities

Cash used in investing activities in the first quarter of 2018 was $516 million primarily due to capital expenditures. Capital expenditures totaled $508 million, which increased $109 million compared to the first quarter of 2017 due to an increase in Encana’s capital program for 2018. This increase was primarily in Montney ($94 million) and Permian ($41 million). Capital expenditures exceeded cash from operating activities by $127 million and the difference was funded using cash on hand.

49

Divestitures in the first quarter of 2018 and 2017 were $19 million and $3 million, respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

Acquisitions in the first quarter of 2018 and 2017 were $2 million and $46 million, respectively, which primarily included land purchases with oil and liquids rich potential.

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

On April 2, 2018, Encana announced an agreement with Keyera Partnership, a subsidiary of Keyera Corp., to sell the Company’s Pipestone liquids hub in Alberta. In conjunction with the sale, Keyera will own and construct a natural gas processing facility and provide Encana with processing services under a competitive fee-for-service arrangement in support of the Company’s liquids growth plans in Montney. The effective date of the agreement is March 1, 2018.

Financing Activities

Net cash used in financing activities in the first quarter of 2018 increased $117 million compared to the first quarter of 2017. The change was primarily due to the purchase of common shares under a NCIB in the first quarter of 2018 ($111 million) as discussed below.

Encana’s long-term debt totaled $4,198 million at March 31, 2018 and $4,197 million at December 31, 2017. There was no current portion outstanding at March 31, 2018 or December 31, 2017. Encana has no long-term debt maturities until May 2019 and, as at March 31, 2018, over 73 percent of the Company’s debt is not due until 2030 and beyond.

The Company continues to have full access to the Credit Facilities, which remain committed through July 2022. The Credit Facilities provide financial flexibility and allow the Company to fund its operations, development activities or capital program. At March 31, 2018, Encana had no outstanding balance under the Credit Facilities.

Dividends

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

	Three months ended March 31,
($ millions, except as indicated)	2018		2017
Dividend Payments	$	15	$	15
Dividend Payments ($/share)	$	0.015	$	0.015

On April 30, 2018, the Board of Directors declared a dividend of $0.015 per common share payable on June 29, 2018 to common shareholders of record as of June 15, 2018.

Normal Course Issuer Bid

On February 26, 2018, Encana received approval from the TSX to commence a NCIB that enables the Company to purchase, for cancellation, up to 35 million common shares over a 12-month period from February 28, 2018 to February 27, 2019. The number of shares authorized for purchase represents approximately 3.6 percent of Encana’s issued and outstanding common shares as at February 20, 2018. The Company has authorization from its Board to spend up to $400 million on the NCIB. In the first quarter of 2018, the Company purchased 10 million common shares for total consideration of approximately $111 million. The Company plans to fund the NCIB with cash on hand.

For additional information on NCIB, refer to Note 13 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 2017 Annual Report on Form 10-K.

50

Commitments and Contingencies

For information on commitments and contingencies, refer to Note 21 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

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, 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 March 31,
($ millions, except as indicated)	2018			2017
Cash From (Used in) Operating Activities	$	381		$	106
(Add back) deduct:
Net change in other assets and liabilities		(11	)		(12)
Net change in non-cash working capital		(8	)		(160)
Current tax on sale of assets		-			-
Non-GAAP Cash Flow	$	400		$	278
Production Volumes (MMBOE)		29.2			28.6
Non-GAAP Cash Flow Margin ($/BOE) (1)	$	13.70		$	9.72

(1) Non-GAAP Cash Flow Margin was previously presented as Corporate Margin.

51

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)	March 31, 2018		December 31, 2017
Debt		$                  4,198		$                4,197
Total Shareholders’ Equity		6,776		6,728
Equity Adjustment for Impairments at December 31, 2011		7,746		7,746
Adjusted Capitalization		$                18,720		$              18,671
Debt to Adjusted Capitalization		22%		22%

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, the Company’s ability to service its debt and other financial obligations, and as a measure considered comparable to other companies in the industry. 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)	March 31, 2018			December 31, 2017
Long-Term Debt, including current portion		$                  4,198			$                4,197
Less:
Cash and cash equivalents		433			719
Net Debt		3,765			3,478
Net Earnings (Loss)		547			827
Add back (deduct):
Depreciation, depletion and amortization		921			833
Impairments		-			-
Accretion of asset retirement obligation		34			37
Interest		367			363
Unrealized (gains) losses on risk management		(148	)		(442)
Foreign exchange (gain) loss, net		(162	)		(279)
(Gain) loss on divestitures, net		(408	)		(404)
Other (gains) losses, net		(37	)		(42)
Income tax expense (recovery)		609			603
Adjusted EBITDA		$                1,723			$              1,496
Net Debt to Adjusted EBITDA (times)		2.2			2.3

52

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 2017 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 19 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:

	March 31, 2018
(US$ millions)		10% Price  Increase		10% Price  Decrease
Crude oil price		$	(303)	$	293
Natural gas price			24		(31)

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 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 in the first quarter of 2018 compared to the same period in 2017.

	$ millions		$/BOE
Increase (Decrease) in:
Capital Investment	$	4
Transportation and Processing Expense (1)		6	$	0.21
Operating Expense (1)		1		0.05
Administrative Expense		2		0.06
Depreciation, Depletion and Amortization (1)		3		0.10

(1) Reflects upstream operations.

53

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 March 31, 2018, Encana has entered into $538 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7606 to C$1, which mature monthly through the remainder of 2018.

As at March 31, 2018, Encana had $4.2 billion in U.S. dollar long-term debt and $296 million in U.S. dollar capital leases 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:

	March 31, 2018
(US$ millions)	10% Rate Increase			10% Rate Decrease
Foreign currency exchange	$	(394	)	$	482

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 March 31, 2018, the Company had no floating rate debt and there were no interest rate derivatives outstanding.

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 March 31, 2018.

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING

There were no changes in Encana’s internal control over financial reporting during the first quarter of 2018 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

54

PART II

Item 1. Legal Proceedings

Please refer to Item 3 of the 2017 Annual Report on Form 10-K and Note 21 of Encana’s Condensed Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report on Form 10-Q.

Item 1A. Risk Factors

There have been no material changes from the risk factors disclosed in Item 1A. Risk Factors in the 2017 Annual Report on Form 10-K.

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

Issuer Purchase of Equity Securities

On February 26, 2018, Encana announced it had received approval from the TSX to purchase, for cancellation, up to 35 million common shares pursuant to a normal course issuer bid (“NCIB”) over a 12-month period from February 28, 2018 to February 27, 2019.

During the three months ended March 31, 2018, the Company purchased 10 million common shares for total consideration of approximately $111 million at a weighted average price of $11.11. The following table presents the common shares purchased during the three months ended March 31, 2018.

Period	Total Number of Shares Purchased		Average Price Paid per Share (1)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number of Shares That May Yet be Purchased Under the Plans or Programs
January 1 to January 31, 2018		-	$	-		-		-
February 1 to February 28, 2018		-		-		-		35,000,000
March 1 to March 31, 2018		10,000,000		11.11		10,000,000		25,000,000
Total		10,000,000	$	11.11		10,000,000		25,000,000

⁽¹⁾ Includes commissions.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

55

Item 6. Exhibits

Exhibit No	Description
10.1	First Amending Agreement dated as of March  28, 2018, among Encana Corporation as borrower, the financial institutions party thereto as lenders and Royal Bank of Canada as agent (incorporated by reference to Exhibit 10.1 to Encana’s Current Report on Form 8-K filed on March 29, 2018, SEC File No. 001-15226).
10.2	Successor Agent Agreement and Amendment No. 4 to the Credit Agreement dated as of March  28, 2018, among Alenco Inc. as borrower, the banks, financial institutions and other institutional lenders thereto as lenders, JPMorgan Chase Bank, N.A., in its capacity as successor administrative agent, and Citibank, N.A., in its capacity as existing administrative agent (incorporated by reference to Exhibit 10.2 to Encana’s Current Report on Form 8-K filed on March 29, 2018, SEC File No. 001-15226).
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	XBRL Instance Document.
101.SCH	XBRL Taxonomy Schema Document.
101.CAL	XBRL Calculation Linkbase Document.
101.DEF	XBRL Definition Linkbase Document.
101.LAB	XBRL Label Linkbase Document.
101.PRE	XBRL Presentation Linkbase Document.

56

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/ Sherri A. Brillon
	Name:	Sherri A. Brillon
	Title:	Executive Vice-President & Chief Financial Officer

Dated: May 3, 2018

57

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: May 3, 2018

/s/ Douglas J. Suttles

Douglas J. Suttles

President & 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, Sherri A. Brillon, 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: May 3, 2018

/s/ Sherri A. Brillon

Sherri A. Brillon

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 March 31, 2018 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Douglas J. Suttles, President & 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

President & Chief Executive Officer

Dated: May 3, 2018

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 March 31, 2018 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Sherri A. Brillon, 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/ Sherri A. Brillon

      Sherri A. Brillon

      Executive Vice-President & Chief Financial Officer

Dated: May 3, 2018

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2018	Apr. 27, 2018
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2018
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2018
Entity Registrant Name	ENCANA CORP
Entity Central Index Key	0001157806
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		963,146,387
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Trading Symbol	ECA

XML

Condensed Consolidated Statement Of Earnings - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Product and Service Revenues	$ 1,260	$ 934
Gains (losses) from risk management, net	36	338
Sublease revenues	17	17
Total Revenues	1,313	1,289
Expenses
Production, mineral and other taxes	29	29
Transportation and processing	249	212
Operating	111	132
Purchased product	273	171
Depreciation, depletion and amortization	275	187
Accretion of asset retirement obligation	8	11
Administrative	31	58
Total Operating Expenses	976	800
Operating Income (Loss)	337	489
Interest	92	88
Foreign exchange (gain) loss, net	91	(26)
(Gain) loss on divestitures, net	(3)	1
Other (gains) losses, net	(3)	(8)
Total Other (Income) Expenses	177	55
Net Earnings (Loss) Before Income Tax	160	434
Income tax expense (Recovery)	9	3
Net Earnings (Loss)	$ 151	$ 431
Net Earnings (Loss) per Common Share
Earnings Per Share, Basic and Diluted	$ 0.16	$ 0.44
Dividends, Common Stock [Abstract]
Common Stock, Dividends, Per Share, Cash Paid	$ 0.015	$ 0.015
Weighted Average Number of Shares Outstanding, Diluted [Abstract]
Weighted Average Number of Shares Outstanding, Basic and Diluted	971.5	973.0
Revenues and Operating Income (Loss) [Member]
Supplemental Income Statement Elements [Abstract]
Quarterly Financial Information, Quarterly Charges and Credits, Amount Reconciling to Previously Reported Results		$ 8
Immaterial Error Correction	Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net.

XML

Condensed Consolidated Statement Of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Consolidated Statement Of Comprehensive Income [Abstract]
Net Earnings (Loss)	$ 151	$ 431
Other Comprehensive Income (Loss), Net of Tax
Foreign currency translation adjustment	24	(16)
Pension and other post-employment benefit plans	(1)	(1)
Other Comprehensive Income (Loss)	23	(17)
Comprehensive Income (Loss)	$ 174	$ 414

XML

Condensed Consolidated Balance Sheet - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 433	$ 719
Accounts receivable and accrued revenues	731	774
Risk Management Assets, Net, Current	226	205
Income tax receivable	562	573
Total Current Assets	1,952	2,271
Natural gas & oil properties, based on full cost accounting
Proved properties	40,508	40,228
Unproved properties	4,301	4,480
Other	2,241	2,302
Property, plant and equipment	47,050	47,010
Less: Accumulated depreciation, depletion and amortization	(37,933)	(38,056)
Property, plant and equipment, net	9,117	8,954
Other Assets	139	144
Risk Management Assets, Net, Long-term	290	246
Deferred Income Taxes Assets	1,021	1,043
Goodwill	2,591	2,609
Total Assets	15,110	15,267
Current Liabilities
Accounts payable and accrued liabilities	1,432	1,415
Income tax payable	3	7
Risk Management Liabilities, Net, Current	250	236
Total Current Liabilities	1,685	1,658
Long-Term Debt	4,198	4,197
Other Liabilities and Provisions	1,958	2,167
Risk Management Liabilities, Net, Long-term	17	13
Asset Retirement Obligation	443	470
Deferred Income Taxes	33	34
Total Liabilities	8,334	8,539
Commitments and Contingencies
Shareholders' Equity
Share capital - authorized unlimited common shares, without par value, 2017 issued and outstanding: 973.1 million shares (2016: 973.0 million shares)	4,707	4,757
Paid in surplus	1,358	1,358
Accumulated deficit	(354)	(429)
Accumulated other comprehensive income	1,065	1,042
Total Shareholders' Equity	6,776	6,728
Total Liabilities and Shareholders' Equity	$ 15,110	$ 15,267

XML

Condensed Consolidated Balance Sheet (Parenthetical) - shares shares in Millions	Mar. 31, 2018	Dec. 31, 2017
Consolidated Balance Sheet [Abstract]
Common Stock, Shares, Issued	963.1	973.1
Common Stock, Shares, Outstanding	963.1	973.1

XML

Condensed Consolidated Statement Of Changes In Shareholders' Equity - USD ($) $ in Millions	Share Capital [Member]	Paid In Surplus [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]	Total
Balance, Beginning of Year at Dec. 31, 2016	$ 4,756.0	$ 1,358.0	$ (1,198.0)	$ 1,210.0	$ 6,126.0
Net Earnings (Loss)			431.0		431.0
Dividends on Common Shares			(15.0)		(15.0)
Other Comprehensive Income (Loss)				(17.0)	(17.0)
Balance, End of Period at Mar. 31, 2017	4,756.0	1,358.0	(782.0)	1,193.0	6,525.0
Balance, Beginning of Year at Dec. 31, 2016	4,756.0	1,358.0	(1,198.0)	1,210.0	6,126.0
Common Shares Issued under Dividend Reinvestment Plan					0.6
Balance, End of Period at Dec. 31, 2017	4,757.0	1,358.0	(429.0)	1,042.0	6,728.0
Net Earnings (Loss)			151.0		151.0
Dividends on Common Shares			(15.0)		(15.0)
Common Shares Purchased under Normal Course Issuer Bid	(50.0)		(61.0)		(111.0)
Common Shares Issued under Dividend Reinvestment Plan					0.3
Other Comprehensive Income (Loss)				23.0	23.0
Balance, End of Period at Mar. 31, 2018	$ 4,707.0	$ 1,358.0	$ (354.0)	$ 1,065.0	$ 6,776.0

XML

Condensed Consolidated Statement Of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Operating Activities
Net Earnings (Loss)	$ 151	$ 431
Depreciation, depletion and amortization	275	187
Accretion of asset retirement obligation	8	11
Deferred income taxes	6	42
Unrealized (gain) loss on risk management	(68)	(362)
Unrealized foreign exchange (gain) loss	150	(36)
Foreign exchange on settlements	(50)	2
(Gain) loss on divestitures, net	(3)	1
Other	(69)	2
Net change in other assets and liabilities	(11)	(12)
Net change in non-cash working capital	(8)	(160)
Cash From (Used in) Operating Activities	381	106
Investing Activities
Capital expenditures	(508)	(399)
Acquisitions	(2)	(46)
Proceeds from divestitures	19	3
Net change in investments and other	(25)	55
Cash From (Used in) Investing Activities	(516)	(387)
Financing Activities
Purchase of common shares	(111)
Dividends on common shares	(15)	(15)
Capital lease payments and other financing arrangements	(22)	(16)
Cash From (Used in) Financing Activities	(148)	(31)
Foreign Exchange Gain (Loss) on Cash and Cash Equivalents Held in Foreign Currency	(3)	1
Increase (Decrease) in Cash and Cash Equivalents	(286)	(311)
Cash and Cash Equivalents, Beginning of Period	719	834
Cash and Cash Equivalents, End of Period	$ 719	$ 834

XML

Basis of Presentation and Principles of Consolidation

3 Months Ended

Mar. 31, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization, Consolidation and Presentation of Financial Statements Disclosure and Significant Accounting Policies [Text Block]

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, 2017, which are included in Item 8 of Encana’s 2017 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, 2017, 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.

XML

Recent Accounting Pronouncements

3 Months Ended

Mar. 31, 2018

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, 2018, Encana adopted the following ASUs issued by the FASB, which have not had a material impact on the Company's interim Condensed Consolidated Financial Statements:

· ASU 2014-09, “Revenue from Contracts with Customers” under Topic 606. The new standard replaces Topic 605, “Revenue Recognition” as well as other industry-specific guidance within the Accounting Standards Codification. Topic 606 is based on the principle that revenue is recognized on the transfer of promised goods or services to customers in an amount that reflects the consideration the company expects to be entitled to in exchange for those goods or services. The standard has been applied using the modified retrospective approach and did not have a material impact on the Company’s Condensed Consolidated Financial Statements, other than enhancing disclosures related to the disaggregation of revenues from contracts with customers and performance obligations. The disclosures required under Topic 606 are included in Note 4, Revenues from Contracts with Customers.

· ASU 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”. The amendment requires the service cost component to be presented with the related employee compensation costs, while the other components of net benefit costs are required to be presented separately from the service cost component and outside the subtotal of income from operations. In addition, the amendment allows only the service cost to be eligible for capitalization. The amendment has been applied retrospectively for the presentation of net periodic pension costs and net periodic postretirement benefit cost, whereas prospective adoption has been applied to the capitalization of the service cost component.

New Standards Issued Not Yet Adopted

As of January 1, 2019, Encana will be required to adopt ASU 2016-02, “Leases” under Topic 842, which will replace Topic 840 “Leases”. The new standard will require lessees to recognize right-of-use assets and related lease liabilities for all leases, including leases classified as operating leases, on the Consolidated Balance Sheet. The dual classification model was retained for the purpose of subsequent measurement and presentation of leases in the Consolidated Statement of Earnings and Consolidated Statement of Cash Flows. Topic 842 also expands disclosures related to the amount, timing and uncertainty of cash flows arising from leases. The standard will be applied using a modified retrospective approach, in addition Encana intends to elect certain practical expedients which will allow the Company to retain the classification of leases assessed under Topic 840 which commenced prior to adoption.  

In January 2018, FASB issued ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842”, which permits entities to elect an optional transition practical expedient for land easements that were not previously accounted for as leases under Topic 840. The expedient provides prospective application of Topic 842 to all new or modified land easements upon adoption of the new standard. Encana intends to elect this transitional practical expedient. 

Encana continues to review and analyze contracts, identify its portfolio of leased assets, gather the necessary terms and data elements, as well as identify the processes and controls required to support the accounting for leases and related disclosures.   The Company is in the early stages of implementing a lease software system which will facilitate the measurement and required disclosures for operating leases. The Company anticipates the software implementation to be complete by the end of 2018. Although Encana is not able to reasonably estimate the financial impact of Topic 842 at this time, the Company anticipates there will be a material impact on the Consolidated Financial Statements resulting from the recognition of assets and liabilities from operating lease activities.

As of January 1, 2019, Encana will be required to adopt 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”). Amendments can be applied either in the period of adoption or retrospectively to each period in which the effect of the rate change from the U.S. Tax Reform is recognized. While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact is not material to the Company’s Consolidated Financial Statements. As a result, the Company does not intend to take the election provided in the amendment.

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 is currently in the early stages of reviewing the amendment, but does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

XML

Segmented Information

3 Months Ended

Mar. 31, 2018

Segmented Information [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 centre.

· 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 centre.

· 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.

Results of Operations (For the three months ended March 31)

Segment and Geographic Information

	Canadian Operations				USA Operations				Market Optimization
		2018		2017 (1)		2018		2017 (1)		2018		2017 (1)
Revenues
Product and service revenues	$	404	$	301	$	555	$	447	$	301	$	186
Gains (losses) on risk management, net		12		(21)		(44)		(3)		-		-
Sublease revenues		-		-		-		-		-		-
Total Revenues		416		280		511		444		301		186
Operating Expenses
Production, mineral and other taxes		4		5		25		24		-		-
Transportation and processing		190		132		27		59		32		21
Operating		29		31		74		87		4		9
Purchased product		-		-		-		-		273		171
Depreciation, depletion and amortization		77		64		185		106		-		-
Total Operating Expenses		300		232		311		276		309		201
Operating Income (Loss)	$	116	$	48	$	200	$	168	$	(8)	$	(15)

	Corporate & Other				Consolidated
		2018		2017 (1)		2018		2017 (1)
Revenues
Product and service revenues	$	-	$	-	$	1,260	$	934
Gains (losses) on risk management, net		68		362		36		338
Sublease revenues		17		17		17		17
Total Revenues		85		379		1,313		1,289
Operating Expenses
Production, mineral and other taxes		-		-		29		29
Transportation and processing		-		-		249		212
Operating		4		5		111		132
Purchased product		-		-		273		171
Depreciation, depletion and amortization		13		17		275		187
Accretion of asset retirement obligation		8		11		8		11
Administrative		31		58		31		58
Total Operating Expenses		56		91		976		800
Operating Income (Loss)	$	29	$	288		337		489
Other (Income) Expenses
Interest						92		88
Foreign exchange (gain) loss, net						91		(26)
(Gain) loss on divestitures, net						(3)		1
Other (gains) losses, net						(3)		(8)
Total Other (Income) Expenses						177		55
Net Earnings (Loss) Before Income Tax						160		434
Income tax expense (recovery)						9		3
Net Earnings (Loss)					$	151	$	431

(1) Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net. The remaining Q1 2017 revenues have been realigned to conform with the current year presentation.

Intersegment Information

	Market Optimization
	Marketing Sales				Upstream Eliminations				Total
For the three months ended March 31		2018		2017		2018		2017		2018		2017
Revenues	$	1,331	$	956	$	(1,030)	$	(770)	$	301	$	186
Operating Expenses
Transportation and processing		106		64		(74)		(43)		32		21
Operating		4		9		-		-		4		9
Purchased product		1,229		898		(956)		(727)		273		171
Operating Income (Loss)	$	(8)	$	(15)	$	-	$	-	$	(8)	$	(15)

Capital Expenditures

	Three Months Ended March 31,
		2018		2017
Canadian Operations	$	168	$	88
USA Operations		338		311
Corporate & Other		2		-
	$	508	$	399

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

	Goodwill				Property, Plant and Equipment				Total Assets
	As at				As at				As at
		March 31, 2018		December 31, 2017		March 31, 2018		December 31, 2017		March 31, 2018		December 31, 2017
Canadian Operations	$	678	$	696	$	920	$	862	$	1,923	$	1,908
USA Operations		1,913		1,913		6,710		6,555		9,432		9,301
Market Optimization		-		-		1		2		151		152
Corporate & Other		-		-		1,486		1,535		3,604		3,906
	$	2,591	$	2,609	$	9,117	$	8,954	$	15,110	$	15,267

XML

Revenue from Contracts with Customers

3 Months Ended

Mar. 31, 2018

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

4.Revenues from Contracts with Customers

The table below summarizes 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.

	Canadian Operations				USA Operations				Market Optimization
For the three months ended March 31		2018		2017		2018		2017		2018		2017
Revenues from Customers
Product revenues (1)
Oil	$	3	$	2	$	473	$	301	$	22	$	37
NGLs		180		95		52		40		2		12
Natural gas		221		203		32		107		273		127
Service revenues								-
Gathering and processing		2		4		-		6		-		-
Product and Service Revenues		406		304		557		454		297		176
Other Revenues
Gains (losses) on risk management, net (2)		12		(21)		(44)		(3)		-		-
Sublease revenues		-		-		-		-		-		-
Other Revenues		12		(21)		(44)		(3)		-		-
Total Revenues	$	418	$	283	$	513	$	451	$	297	$	176

	Corporate & Other				Consolidated
		2018		2017 (3)		2018		2017 (3)
Revenues from Customers
Product revenues (1)
Oil	$	-	$	-	$	498	$	340
NGLs		-		-		234		147
Natural gas		-		-		526		437
Service revenues
Gathering and processing		-		-		2		10
Product and Service Revenues		-		-		1,260		934
Other Revenues
Gains (losses) on risk management, net (2)		68		362		36		338
Sublease revenues		17		17		17		17
Other Revenues		85		379		53		355
Total Revenues	$	85	$	379	$	1,313	$	1,289

(1) Includes revenues from production and revenues of product purchased from third parties, but excludes intercompany marketing fees transacted between

the Company’s operating segments.

(2) Canadian and USA Operations includes realized gains/(losses) on risk management. Corporate & Other includes unrealized gains/(losses) on risk management.

(3) Corporate interest income of $8 million previously reported in revenues in Q1 2017 has been reclassified to other (gains) losses, net.

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 March 31, 2018, receivables and accrued revenues from contracts with customers were $658 million ($676 million as at December 31, 2017).

Performance obligations arising from product sales contracts are typically satisfied at a point in time when the product is delivered to the customer and control is transferred. Payment from the customer is due when the product is delivered to the custody point. The Company’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.  

As at March 31, 2018, 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.

Performance obligations arising from arrangements to gather and process natural gas on behalf of third parties are typically satisfied over time as the service is provided to the customer. Payment from the customer is due when the customer receives the benefit of the service and the product is delivered to the custody point or plant tailgate. 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 March 31, 2018.

XML

Interest

3 Months Ended

Mar. 31, 2018

Interest [Abstract]

Interest

5.Interest

	Three Months Ended March 31,
		2018		2017
Interest Expense on:
Debt	$	66	$	66
The Bow office building		16		16
Capital leases		5		5
Other		5		1
	$	92	$	88

XML

Foreign Exchange (Gain) Loss, Net

3 Months Ended

Mar. 31, 2018

Foreign Currency [Abstract]

Foreign Exchange (Gain) Loss, Net

6.Foreign Exchange (Gain) Loss, Net

	Three Months Ended March 31,
		2018		2017
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	122	$	(33)
Translation of U.S. dollar risk management contracts issued from Canada		9		(4)
Translation of intercompany notes		19		1
		150		(36)
Foreign Exchange on Settlements of:
U.S. dollar risk management contracts issued from Canada		(7)		(1)
Intercompany notes		(50)		2
Other Monetary Revaluations		(2)		9
	$	91	$	(26)

XML

Income Taxes

3 Months Ended

Mar. 31, 2018

Income Taxes [Abstract]

Income Taxes

7.Income Taxes

	Three Months Ended March 31,
		2018		2017
Current Tax
Canada	$	-	$	(42)
United States		1		-
Other Countries		2		3
Total Current Tax Expense (Recovery)		3		(39)
Deferred Tax
Canada		(3)		18
United States		4		15
Other Countries		5		9
Total Deferred Tax Expense (Recovery)		6		42
Income Tax Expense (Recovery)	$	9	$	3
Effective Tax Rate		5.6%		0.7%

Encana’s interim income tax expense is determined using an 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 including U.S. Tax Reform, non-taxable capital gains and losses, tax differences on divestitures and transactions, and partnership tax allocations in excess of funding.

During the three months ended March 31, 2017, the current income tax recovery was primarily due to the successful resolution of certain tax items previously assessed by the taxing authorities relating to prior taxation years.

The effective tax rates of 5.6 percent and 0.7 percent for the three months ended March 31, 2018 and March 31, 2017, respectively, are lower than the Canadian statutory rate of 27 percent primarily due to the impact of the foreign jurisdictional tax rates relative to the Canadian statutory tax rate applied to jurisdictional earnings as well as the items discussed above.

During the three months ended March 31, 2018, there was no change to the provisional tax adjustment recognized in 2017 resulting from the re-measurement of the Company’s tax position due to a reduction of the U.S. federal corporate tax rate under U.S. Tax Reform. The provisional amount recognized may change due to additional regulatory guidance that may be issued, and from additional analysis or changes in interpretation and assumptions of the U.S. Tax Reform made by the Company.

XML

Acquisitions And Divestitures

3 Months Ended

Mar. 31, 2018

Acquisitions And Divestitures [Abstract]

Acquisitions And Divestitures

8.Acquisitions and Divestitures

	Three Months Ended March 31,
		2018		2017
Acquisitions
Canadian Operations	$	2	$	31
USA Operations		-		15
Total Acquisitions		2		46
Divestitures
Canadian Operations		(13)		(3)
USA Operations		(6)		-
Total Divestitures		(19)		(3)
Net Acquisitions & (Divestitures)	$	(17)	$	43

Acquisitions

For the three months ended March 31, 2018, acquisitions in the Canadian and USA Operations were $2 million (2017 - $31 million) and nil (2017 - $15 million), respectively, which primarily included land purchases with oil and liquids rich potential.

Divestitures

For the three months ended March 31, 2018, divestitures in the Canadian and USA Operations were $13 million (2017 - $3 million) and $6 million (2017 - nil), respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

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

XML

Property, Plant And Equipment, Net

3 Months Ended

Mar. 31, 2018

Property, Plant And Equipment, Net [Abstract]

Property, Plant And Equipment, Net

9.Property, Plant and Equipment, Net

	As at March 31, 2018						As at December 31, 2017
		Cost		Accumulated DD&A		Net		Cost		Accumulated DD&A		Net
Canadian Operations
Proved properties	$	14,366	$	(13,743)	$	623	$	14,555	$	(14,047)	$	508
Unproved properties		262		-		262		311		-		311
Other		35		-		35		43		-		43
		14,663		(13,743)		920		14,909		(14,047)		862
USA Operations
Proved properties		26,081		(23,426)		2,655		25,610		(23,240)		2,370
Unproved properties		4,039		-		4,039		4,169		-		4,169
Other		16		-		16		16		-		16
		30,136		(23,426)		6,710		29,795		(23,240)		6,555
Market Optimization		7		(6)		1		7		(5)		2
Corporate & Other		2,244		(758)		1,486		2,299		(764)		1,535
	$	47,050	$	(37,933)	$	9,117	$	47,010	$	(38,056)	$	8,954

Canadian and USA Operations property, plant and equipment include internal costs directly related to exploration, development and construction activities of $39 million, which have been capitalized during the three months ended March 31, 2018 (2017 - $54 million). Included in Corporate and Other are $61 million ($63 million as at December 31, 2017) of international property costs, which have been fully impaired.

Capital Lease Arrangements

The Company has several lease arrangements that are accounted for as capital leases including an office building and an offshore production platform.

As at March 31, 2018, the total carrying value of assets under capital lease was $45 million ($46 million as at December 31, 2017), net of accumulated amortization of $672 million ($684 million as at December 31, 2017). Liabilities for the capital lease arrangements are included in other liabilities and provisions in the Condensed Consolidated Balance Sheet and are disclosed in Note 11.

Other Arrangement

As at March 31, 2018, Corporate and Other property, plant and equipment and total assets include a carrying value of $1,216 million ($1,255 million as at December 31, 2017) related to The Bow office building, which is under a 25-year lease agreement. The Bow asset is being depreciated over the 60-year estimated life of the building. At the conclusion of the 25-year term, the remaining asset and corresponding liability are expected to be derecognized as disclosed in Note 11.

XML

Long-Term Debt

3 Months Ended

Mar. 31, 2018

Long-Term Debt [Abstract]

Long-Term Debt

10.Long-Term Debt

		As at March 31, 2018		As at December 31, 2017
U.S. Dollar Denominated Debt
U.S. Unsecured Notes
6.50% due May 15, 2019	$	500	$	500
3.90% due November 15, 2021		600		600
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		4,211		4,211
Increase in Value of Debt Acquired		25		26
Unamortized Debt Discounts and Issuance Costs		(38)		(40)
Current Portion of Long-Term Debt		-		-
	$	4,198	$	4,197

As at March 31, 2018, total long-term debt had a carrying value of $4,198 million and a fair value of $4,909 million (as at December 31, 2017 - carrying value of $4,197 million and a fair value of $5,042 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.

XML

Other Liabilities And Provisions

3 Months Ended

Mar. 31, 2018

Other Liabilities And Provisions [Abstract]

Other Liabilities And Provisions

11.Other Liabilities and Provisions

		As at March 31, 2018		As at December 31, 2017
The Bow Office Building	$	1,304	$	1,344
Capital Lease Obligations		275		295
Unrecognized Tax Benefits		197		202
Pensions and Other Post-Employment Benefits		116		116
Long-Term Incentive Costs (See Note 16)		32		175
Other Derivative Contracts (See Notes 18, 19)		13		14
Other		21		21
	$	1,958	$	2,167

The Bow Office Building

As described in Note 9, Encana has recognized the accumulated costs for The Bow office building, which is under a 25-year lease agreement. At the conclusion of the lease term, the remaining asset and corresponding liability are expected to be derecognized. Encana has also subleased approximately 50 percent of The Bow office space under the lease agreement. The total expected future principal and interest payments related to the 25-year lease agreement and the total undiscounted future amounts expected to be recovered from the sublease are outlined below.

		2018		2019		2020		2021		2022		Thereafter		Total
Expected Future Lease Payments	$	55	$	75	$	75	$	76	$	76	$	1,260	$	1,617
Less: Amounts Representing Interest		47		63		61		61		60		781		1,073
Present Value of Expected Future
Lease Payments	$	8	$	12	$	14	$	15	$	16	$	479	$	544
Sublease Recoveries (undiscounted)	$	(27)	$	(37)	$	(37)	$	(37)	$	(38)	$	(619)	$	(795)

Capital Lease Obligations

As described in Note 9, the Company has several lease arrangements that are accounted for as capital leases including an office building and the Deep Panuke offshore Production Field Centre (“PFC”). Variable interests related to the PFC are described in Note 15.

The total expected future lease payments related to the Company’s capital lease obligations are outlined below.

		2018		2019		2020		2021		2022		Thereafter		Total
Expected Future Lease Payments	$	75	$	99	$	99	$	87	$	8	$	38	$	406
Less: Amounts Representing Interest		15		15		10		4		2		5		51
Present Value of Expected Future
Lease Payments	$	60	$	84	$	89	$	83	$	6	$	33	$	355

XML

Asset Retirement Obligation

3 Months Ended

Mar. 31, 2018

Asset Retirement Obligation [Abstract]

Asset Retirement Obligation

12.Asset Retirement Obligation

		As at March 31, 2018		As at December 31, 2017
Asset Retirement Obligation, Beginning of Year	$	514	$	687
Liabilities Incurred and Acquired		5		11
Liabilities Settled and Divested		(4)		(333)
Change in Estimated Future Cash Outflows		-		88
Accretion Expense		8		37
Foreign Currency Translation		(11)		24
Asset Retirement Obligation, End of Period	$	512	$	514
Current Portion	$	69	$	44
Long-Term Portion		443		470
	$	512	$	514

XML

Share Capital

3 Months Ended

Mar. 31, 2018

Share Capital [Abstract]

Share Capital

13.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 March 31, 2018			As at December 31, 2017
	Number (millions)		Amount	Number (millions)		Amount
Common Shares Outstanding, Beginning of Year	973.1	$	4,757	973.0	$	4,756
Common Shares Purchased	(10.0)		(50)	-		-
Common Shares Issued Under Dividend Reinvestment Plan	-		-	0.1		1
Common Shares Outstanding, End of Period	963.1	$	4,707	973.1	$	4,757

During the three months ended March 31, 2018, Encana issued 23,023 common shares totaling $0.3 million under the Company’s dividend reinvestment plan (“DRIP”). During the twelve months ended December 31, 2017, Encana issued 58,480 common shares totaling $0.6 million under the DRIP.

Dividends

During the three months ended March 31, 2018, Encana paid dividends of $0.015 per common share totaling $15 million (2017 - $0.015 per common share totaling $15 million). For the three months ended March 31, 2018, the dividends paid included $0.3 million in common shares issued in lieu of cash dividends under the DRIP (2017 - $0.2 million).

On April 30, 2018, the Board of Directors declared a dividend of $0.015 per common share payable on June 29, 2018 to common shareholders of record as of June 15, 2018.

Normal Course Issuer Bid

On February 26, 2018, the Company announced it received approval from the TSX to purchase, for cancellation, up to 35 million common shares pursuant to a normal course issuer bid (“NCIB”) over a 12-month period from February 28, 2018 to February 27, 2019. The Company has authorization from its Board to spend up to $400 million on the NCIB.

All purchases are 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, and any excess is allocated to retained earnings/accumulated deficit.

During the three months ended March 31, 2018, the Company purchased 10 million common shares for total consideration of approximately $111 million. Of the amount paid, $50 million was charged to share capital and $61 million was charged to accumulated deficit.

Earnings Per Common Share

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

	Three Months Ended March 31,
(US$ millions, except per share amounts)		2018		2017
Net Earnings (Loss)	$	151	$	431
Number of Common Shares:
Weighted average common shares outstanding - Basic		971.5		973.0
Effect of dilutive securities		-		-
Weighted average common shares outstanding - Diluted		971.5		973.0
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.16	$	0.44

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 March 31, 2018 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.

In addition, certain stock options granted are performance-based whereby vesting is also subject to Encana attaining prescribed performance relative to predetermined key measures. 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 (“RSUs”)

Encana has a share-based compensation plan whereby eligible employees and Directors are granted 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 of the RSU Plan and Grant Agreement. The Company currently settles vested RSUs in cash. As a result, RSUs are not considered potentially dilutive securities.

XML

Accumulated Other Comprehensive Income

3 Months Ended

Mar. 31, 2018

Accumulated Other Comprehensive Income [Abstract]

Accumulated Other Comprehensive Income

14.Accumulated Other Comprehensive Income

	Three Months Ended March 31,
		2018		2017
Foreign Currency Translation Adjustment
Balance, Beginning of Year	$	1,029	$	1,200
Change in Foreign Currency Translation Adjustment		24		(16)
Balance, End of Period	$	1,053	$	1,184
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Year	$	13	$	10
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 17)		(1)		(1)
Income Taxes		-		-
Balance, End of Period	$	12	$	9
Total Accumulated Other Comprehensive Income	$	1,065	$	1,193

XML

Variable Interest Entities

3 Months Ended

Mar. 31, 2018

Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract]

Variable Interest Entity Disclosure

15.Variable Interest Entities

Production Field Centre

In 2008, Encana entered into a contract for the design, construction and operation of the PFC at its Deep Panuke facility. Upon commencement of operations in December 2013, Encana recognized the PFC as a capital lease asset. Under the lease contract, Encana has a purchase option and the option to extend the lease for 12one-year terms at fixed prices after the initial lease term expires in 2021.

As a result of the purchase option and fixed price renewal options, Encana has determined it holds variable interests and that the related leasing entity qualifies as a variable interest entity (“VIE”). Encana is not the primary beneficiary of the VIE as the Company does not have the power to direct the activities that most significantly impact the VIE’s economic performance. Encana is not required to provide any financial support or guarantees to the leasing entity or its affiliates, other than the contractual payments under the lease and operating agreements. Encana’s maximum exposure is the expected lease payments over the initial contract term. As at March 31, 2018, Encana had a capital lease obligation of $296 million ($314 million as at December 31, 2017) related to the PFC.

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 March 31, 2018, VMLP provides approximately 1,110 MMcf/d of natural gas gathering and compression and 600 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from up to 13 to 27 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 $2,390 million as at March 31, 2018. 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 21 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 March 31, 2018, there were no accounts payable and accrued liabilities outstanding related to the take or pay commitment.

XML

Compensation Plans

3 Months Ended

Mar. 31, 2018

Compensation Plans [Abstract]

Compensation Plans

16.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 held by employees 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 held by employees:

	As at March 31, 2018		As at March 31, 2017
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units
Risk Free Interest Rate	1.79%	1.79%	0.74%	0.74%
Dividend Yield	0.55%	0.54%	0.51%	0.51%
Expected Volatility Rate (1)	58.46%	54.78%	58.12%	54.02%
Expected Term	2.0 yrs	2.1 yrs	1.9 yrs	1.9 yrs
Market Share Price	US$11.00	C$14.17	US$11.71	C$15.58

(1) Volatility was estimated using historical rates.

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

	Three Months Ended March 31,
		2018		2017
Total Compensation Costs of Transactions Classified as Cash-Settled	$	(27)	$	34
Less: Total Share-Based Compensation Costs Capitalized		9		(11)
Total Share-Based Compensation Expense (Recovery)	$	(18)	$	23
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	(6)	$	8
Administrative		(12)		15
	$	(18)	$	23

As at March 31, 2018, the liability for share-based payment transactions totaled $217 million ($327 million as at December 31, 2017), of which $185 million ($152 million as at December 31, 2017) is recognized in accounts payable and accrued liabilities and $32 million ($175 million as at December 31, 2017) is recognized in other liabilities and provisions in the Condensed Consolidated Balance Sheet.

		As at March 31, 2018		As at December 31, 2017
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested	$	167	$	274
Vested		50		53
	$	217	$	327

The following units were granted primarily in conjunction with the Company’s February annual long-term incentive award. 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.

Three Months Ended March 31, 2018 (thousands of units)
TSARs	872
SARs	359
PSUs	2,503
DSUs	31
RSUs	5,238

XML

Pension and Other Post-Employment Benefits

3 Months Ended

Mar. 31, 2018

General Discussion of Pension and Other Postretirement Benefits [Abstract]

Pension and Other Postretirement Benefits Disclosure

17.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 three months ended March 31 as follows:

	Pension Benefits				OPEB				Total
		2018		2017		2018		2017		2018		2017
Net Defined Periodic Benefit Cost	$	-	$	-	$	2	$	2	$	2	$	2
Defined Contribution Plan Expense		6		6		-		-		6		6
Total Benefit Plans Expense	$	6	$	6	$	2	$	2	$	8	$	8

Of the total benefit plans expense, $6 million (2017 - $6 million) was included in operating expense and $2 million (2017 - $2 million) was included in administrative expense.

The net defined periodic benefit cost for the three months ended March 31 is as follows:

	Defined Benefits				OPEB				Total
		2018		2017		2018		2017		2018		2017
Service Cost	$	-	$	-	$	2	$	2	$	2	$	2
Interest Cost		2		2		1		1		3		3
Expected Return on Plan Assets		(2)		(2)		-		-		(2)		(2)
Amounts Reclassified from Accumulated Other
Comprehensive Income:
Amortization of net actuarial (gains) and losses		-		-		(1)		(1)		(1)		(1)
Total Net Defined Periodic Benefit Cost (1)	$	-	$	-	$	2	$	2	$	2	$	2

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

XML

Fair Value Measurements

3 Months Ended

Mar. 31, 2018

Fair Value Measurements [Abstract]

Fair Value Measurements

18.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.

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note 19. 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, transportation and processing expense, and foreign exchange gains and losses according to their purpose.

As at March 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	$	-	$	267	$	-	$	267	$	(53)	$	214
Long-term assets		-		298		-		298		(8)		290
Foreign Currency Derivatives:
Current assets		-		12		-		12		-		12
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	241	$	62	$	303	$	(53)	$	250
Long-term liabilities		-		25		-		25		(8)		17
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-	$	5
Long-term in other liabilities and provisions		-		13		-		13		-		13
As at December 31, 2017		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	$	-	$	189	$	-	$	189	$	(15)	$	174
Long-term assets		-		248		-		248		(2)		246
Foreign Currency Derivatives:
Current assets		-		31		-		31		-		31
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	3	$	196	$	51	$	250	$	(15)	$	235
Long-term liabilities		-		15		-		15		(2)		13
Foreign Currency Derivatives:
Current liabilities		-		1		-		1		-		1
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-	$	5
Long-term in other liabilities and provisions		-		14		-		14		-		14

(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 call options, foreign currency swaps and basis swaps with terms to 2023. Level 2 also includes financial guarantee contracts as discussed in Note 19. The fair values of these contracts are based on a market approach and are estimated using inputs which are either directly or indirectly observable at the reporting date, such as exchange and other published prices, broker quotes and observable trading activity.

Level 3 Fair Value Measurements

As at March 31, 2018, the Company’s Level 3 risk management assets and liabilities consist of WTI three-way options and WTI costless collars with terms to 2018. 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 three months ended March 31 is presented below:

		Risk Management
		2018		2017
Balance, Beginning of Year	$	(51)	$	(36)
Total Gains (Losses)		6		41
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances		-		-
Settlements		(17)		-
Transfers Out of Level 3 (1)		-		-
Balance, End of Period	$	(62)	$	5
Change in Unrealized Gains (Losses) Related to
Assets and Liabilities Held at End of Period	$	(24)	$	40

(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 March 31, 2018	As at December 31, 2017
Risk Management - WTI Options	Option Model	Implied Volatility	24% - 83%	17% - 76%

A  10 percent increase or decrease in implied volatility for the WTI options would cause a corresponding $1 million ($2 million as at December 31, 2017) increase or decrease to net risk management assets and liabilities.

XML

Financial Instruments And Risk Management

3 Months Ended

Mar. 31, 2018

Financial Instruments And Risk Management [Abstract]

Financial Instruments and Risk Management

19.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, 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 and options. 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 March 31, 2018, Encana has entered into $538 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$0.7606 to C$1, which mature monthly through the remainder of 2018.

⁽¹⁾

Risk Management Positions as at March 31, 2018

	Notional Volumes		Term	Average Price						Fair Value
Crude Oil and NGL Contracts						US$/bbl
Fixed Price Contracts
WTI Fixed Price	94.3	Mbbls/d	2018	55.53					$	(194)
WTI Fixed Price	15.0	Mbbls/d	2019	58.30						(2)
WTI Fixed Price Swaptions (1)	24.0	Mbbls/d	Q1 - Q2 2019			63.13				(16)
WTI Three-Way Options
Sold call / bought put / sold put	16.0	Mbbls/d	2018	54.49	/	47.17	/	36.88		(42)
WTI Costless Collars
Sold call / bought put	10.0	Mbbls/d	2018	57.08	/	45.00				(20)
Basis Contracts (2)			2018 - 2020							26
Crude Oil and NGLs Fair Value Position										(248)
Natural Gas Contracts						US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	1,007	MMcf/d	2018	3.02						52
NYMEX Fixed Price Swaptions (3)	300	MMcf/d	Q1 - Q2 2019			2.99				(9)
NYMEX Call Options
Sold call price	230	MMcf/d	2018	3.75						(1)
Sold call price	64	MMcf/d	2019	3.75						(4)
Sold call price	166	MMcf/d	2020	3.25						(1)
Basis Contracts (4)			2018							130
			2019							136
			2020							99
			2021 - 2023							86
Premiums Received on Unexpired Options										(3)
Natural Gas Fair Value Position										485
Other Derivative Contracts
Fair Value Position										(18)
Foreign Currency Contracts
Fair Value Position (5)			2018							12
Total Fair Value Position									$	231

⁽¹⁾ WTI Fixed Price Swaptions give the counterparty the option to extend certain Q3 - Q4 2018 Fixed Price swaps to Q1- Q2 2019.

⁽²⁾ Encana has entered into swaps to protect against widening Midland, Magellan East Houston, Louisiana Light Sweet and Edmonton Condensate differentials to WTI.

⁽³⁾ NYMEX Fixed Price Swaptions give the counterparty the option to extend certain Q3 - Q4 2018 Fixed Price swaps to Q1- Q2 2019.

⁽⁴⁾ Encana has entered into swaps to protect against widening AECO, Dawn, Malin and Waha basis to 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 March 31,
		2018		2017
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	(32)	$	(24)
Transportation and processing		-		(4)
Foreign Currency Derivatives:
Foreign exchange		7		1
	$	(25)	$	(27)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	68	$	362
Foreign Currency Derivatives:
Foreign exchange		(18)		2
	$	50	$	364
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	36	$	338
Transportation and processing		-		(4)
Foreign Currency Derivatives:
Foreign exchange		(11)		3
	$	25	$	337

(1) Includes a realized gain of $1 million (2017 - gain of $2 million) related to other derivative contracts.

(2) Includes an unrealized gain of nil (2017 - nil) related to other derivative contracts.

Reconciliation of Unrealized Risk Management Positions from January 1 to March 31

		2018				2017
		Fair Value		Total Unrealized Gain (Loss)		Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	183
Change in Fair Value of Contracts in Place at Beginning of Year
and Contracts Entered into During the Period		25	$	25	$	337
Settlement of Other Derivative Contracts		1
Fair Value of Contracts Realized During the Period		25		25		27
Fair Value of Contracts Outstanding	$	234	$	50	$	364
Premiums Received on Unexpired Options		(3)
Fair Value of Contracts and Premiums Received, End of Period	$	231

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value. See Note 18 for a discussion of fair value measurements.

Unrealized Risk Management Positions

		As at March 31, 2018		As at December 31, 2017
Risk Management Assets
Current	$	226	$	205
Long-term		290		246
		516		451
Risk Management Liabilities
Current		250		236
Long-term		17		13
		267		249
Other Derivative Contracts
Current in accounts payable and accrued liabilities		5		5
Long-term in other liabilities and provisions		13		14
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	231	$	183

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 New York Stock Exchange 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 18. As at March 31, 2018, the Company had no significant credit derivatives in place and held no collateral.

As at March 31, 2018, 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 March 31, 2018, approximately 93 percent (92 percent as at December 31, 2017) of Encana’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

As at March 31, 2018, Encana had two 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. As at March 31, 2018, these counterparties accounted for 53 percent and 11 percent of the fair value of the outstanding in-the-money net risk management contracts. As at December 31, 2017, Encana had three counterparties whose net settlement position accounted for 56percent, 11 percent and 11 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 three to six years with a fair value recognized of $18 million as at March 31, 2018 ($19 million as at December 31, 2017). The maximum potential amount of undiscounted future payments is $317 million as at March 31, 2018, and is considered unlikely.

XML

Supplementary Information

3 Months Ended

Mar. 31, 2018

Supplementary Information [Abstract]

Cash Flow, Supplemental Disclosures [Text Block]

20.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 March 31,
		2018		2017
Operating Activities
Accounts receivable and accrued revenues	$	(2)	$	70
Accounts payable and accrued liabilities		(7)		(134)
Income tax receivable and payable		1		(96)
	$	(8)	$	(160)

B) Non-Cash Activities

	Three Months Ended March 31,
		2018		2017
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 12)	$	5	$	3
Property, plant and equipment accruals		9		44
Capitalized long-term incentives		(36)		11
Property additions/dispositions (swaps)		49		6
Non-Cash Financing Activities
Common shares issued under dividend reinvestment plan (See Note 13)	$	-	$	-

XML

Commitments and Contigencies

3 Months Ended

Mar. 31, 2018

Commitments and Contingencies [Abstract]

Commitments and Contingencies Disclosure [Text Block]

21.Commitments and Contingencies

Commitments

The following table outlines the Company’s commitments as at March 31, 2018:

		Expected Future Payments
(undiscounted)		2018		2019		2020		2021		2022		Thereafter		Total
Transportation and Processing	$	446	$	692	$	663	$	579	$	551	$	2,458	$	5,389
Drilling and Field Services		165		46		24		9		-		-		244
Operating Leases		13		16		16		15		15		46		121
Total	$	624	$	754	$	703	$	603	$	566	$	2,504	$	5,754

Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note 15. 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 unfavourable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures. If an unfavourable 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.

XML

Basis of Presentation and Principles of Consolidation (Policy)

3 Months Ended

Mar. 31, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies [Text Block]

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, 2017, which are included in Item 8 of Encana’s 2017 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, 2017, 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, 2018, Encana adopted the following ASUs issued by the FASB, which have not had a material impact on the Company's interim Condensed Consolidated Financial Statements:

· ASU 2014-09, “Revenue from Contracts with Customers” under Topic 606. The new standard replaces Topic 605, “Revenue Recognition” as well as other industry-specific guidance within the Accounting Standards Codification. Topic 606 is based on the principle that revenue is recognized on the transfer of promised goods or services to customers in an amount that reflects the consideration the company expects to be entitled to in exchange for those goods or services. The standard has been applied using the modified retrospective approach and did not have a material impact on the Company’s Condensed Consolidated Financial Statements, other than enhancing disclosures related to the disaggregation of revenues from contracts with customers and performance obligations. The disclosures required under Topic 606 are included in Note 4, Revenues from Contracts with Customers.

· ASU 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”. The amendment requires the service cost component to be presented with the related employee compensation costs, while the other components of net benefit costs are required to be presented separately from the service cost component and outside the subtotal of income from operations. In addition, the amendment allows only the service cost to be eligible for capitalization. The amendment has been applied retrospectively for the presentation of net periodic pension costs and net periodic postretirement benefit cost, whereas prospective adoption has been applied to the capitalization of the service cost component.

New Standards Issued Not Yet Adopted

As of January 1, 2019, Encana will be required to adopt ASU 2016-02, “Leases” under Topic 842, which will replace Topic 840 “Leases”. The new standard will require lessees to recognize right-of-use assets and related lease liabilities for all leases, including leases classified as operating leases, on the Consolidated Balance Sheet. The dual classification model was retained for the purpose of subsequent measurement and presentation of leases in the Consolidated Statement of Earnings and Consolidated Statement of Cash Flows. Topic 842 also expands disclosures related to the amount, timing and uncertainty of cash flows arising from leases. The standard will be applied using a modified retrospective approach, in addition Encana intends to elect certain practical expedients which will allow the Company to retain the classification of leases assessed under Topic 840 which commenced prior to adoption.  

In January 2018, FASB issued ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842”, which permits entities to elect an optional transition practical expedient for land easements that were not previously accounted for as leases under Topic 840. The expedient provides prospective application of Topic 842 to all new or modified land easements upon adoption of the new standard. Encana intends to elect this transitional practical expedient. 

Encana continues to review and analyze contracts, identify its portfolio of leased assets, gather the necessary terms and data elements, as well as identify the processes and controls required to support the accounting for leases and related disclosures.   The Company is in the early stages of implementing a lease software system which will facilitate the measurement and required disclosures for operating leases. The Company anticipates the software implementation to be complete by the end of 2018. Although Encana is not able to reasonably estimate the financial impact of Topic 842 at this time, the Company anticipates there will be a material impact on the Consolidated Financial Statements resulting from the recognition of assets and liabilities from operating lease activities.

As of January 1, 2019, Encana will be required to adopt 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”). Amendments can be applied either in the period of adoption or retrospectively to each period in which the effect of the rate change from the U.S. Tax Reform is recognized. While Encana has other post-employment benefit plans which were affected by the U.S. Tax Reform, the impact is not material to the Company’s Consolidated Financial Statements. As a result, the Company does not intend to take the election provided in the amendment.

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 is currently in the early stages of reviewing the amendment, but does not expect the amendment to have a material impact on the Company’s Consolidated Financial Statements.

XML

Segmented Information (Tables)

3 Months Ended

Mar. 31, 2018

Segmented Information [Abstract]

Segment And Geographic Information

	Canadian Operations				USA Operations				Market Optimization
		2018		2017 (1)		2018		2017 (1)		2018		2017 (1)
Revenues
Product and service revenues	$	404	$	301	$	555	$	447	$	301	$	186
Gains (losses) on risk management, net		12		(21)		(44)		(3)		-		-
Sublease revenues		-		-		-		-		-		-
Total Revenues		416		280		511		444		301		186
Operating Expenses
Production, mineral and other taxes		4		5		25		24		-		-
Transportation and processing		190		132		27		59		32		21
Operating		29		31		74		87		4		9
Purchased product		-		-		-		-		273		171
Depreciation, depletion and amortization		77		64		185		106		-		-
Total Operating Expenses		300		232		311		276		309		201
Operating Income (Loss)	$	116	$	48	$	200	$	168	$	(8)	$	(15)

	Corporate & Other				Consolidated
		2018		2017 (1)		2018		2017 (1)
Revenues
Product and service revenues	$	-	$	-	$	1,260	$	934
Gains (losses) on risk management, net		68		362		36		338
Sublease revenues		17		17		17		17
Total Revenues		85		379		1,313		1,289
Operating Expenses
Production, mineral and other taxes		-		-		29		29
Transportation and processing		-		-		249		212
Operating		4		5		111		132
Purchased product		-		-		273		171
Depreciation, depletion and amortization		13		17		275		187
Accretion of asset retirement obligation		8		11		8		11
Administrative		31		58		31		58
Total Operating Expenses		56		91		976		800
Operating Income (Loss)	$	29	$	288		337		489
Other (Income) Expenses
Interest						92		88
Foreign exchange (gain) loss, net						91		(26)
(Gain) loss on divestitures, net						(3)		1
Other (gains) losses, net						(3)		(8)
Total Other (Income) Expenses						177		55
Net Earnings (Loss) Before Income Tax						160		434
Income tax expense (recovery)						9		3
Net Earnings (Loss)					$	151	$	431

(1) Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net. The remaining Q1 2017 revenues have been realigned to conform with the current year presentation.

Schedule Of Marketing Intersegment Eliminations

	Market Optimization
	Marketing Sales				Upstream Eliminations				Total
For the three months ended March 31		2018		2017		2018		2017		2018		2017
Revenues	$	1,331	$	956	$	(1,030)	$	(770)	$	301	$	186
Operating Expenses
Transportation and processing		106		64		(74)		(43)		32		21
Operating		4		9		-		-		4		9
Purchased product		1,229		898		(956)		(727)		273		171
Operating Income (Loss)	$	(8)	$	(15)	$	-	$	-	$	(8)	$	(15)

Capital Expenditures

	Three Months Ended March 31,
		2018		2017
Canadian Operations	$	168	$	88
USA Operations		338		311
Corporate & Other		2		-
	$	508	$	399

Goodwill, Property, Plant And Equipment And Total Assets By Segment

	Goodwill				Property, Plant and Equipment				Total Assets
	As at				As at				As at
		March 31, 2018		December 31, 2017		March 31, 2018		December 31, 2017		March 31, 2018		December 31, 2017
Canadian Operations	$	678	$	696	$	920	$	862	$	1,923	$	1,908
USA Operations		1,913		1,913		6,710		6,555		9,432		9,301
Market Optimization		-		-		1		2		151		152
Corporate & Other		-		-		1,486		1,535		3,604		3,906
	$	2,591	$	2,609	$	9,117	$	8,954	$	15,110	$	15,267

XML

Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2018

Disaggregation of Revenue [Abstract]

Disaggregation of Revenue [Table Text Block]

	Canadian Operations				USA Operations				Market Optimization
For the three months ended March 31		2018		2017		2018		2017		2018		2017
Revenues from Customers
Product revenues (1)
Oil	$	3	$	2	$	473	$	301	$	22	$	37
NGLs		180		95		52		40		2		12
Natural gas		221		203		32		107		273		127
Service revenues								-
Gathering and processing		2		4		-		6		-		-
Product and Service Revenues		406		304		557		454		297		176
Other Revenues
Gains (losses) on risk management, net (2)		12		(21)		(44)		(3)		-		-
Sublease revenues		-		-		-		-		-		-
Other Revenues		12		(21)		(44)		(3)		-		-
Total Revenues	$	418	$	283	$	513	$	451	$	297	$	176

	Corporate & Other				Consolidated
		2018		2017 (3)		2018		2017 (3)
Revenues from Customers
Product revenues (1)
Oil	$	-	$	-	$	498	$	340
NGLs		-		-		234		147
Natural gas		-		-		526		437
Service revenues
Gathering and processing		-		-		2		10
Product and Service Revenues		-		-		1,260		934
Other Revenues
Gains (losses) on risk management, net (2)		68		362		36		338
Sublease revenues		17		17		17		17
Other Revenues		85		379		53		355
Total Revenues	$	85	$	379	$	1,313	$	1,289

XML

Interest (Tables)

3 Months Ended

Mar. 31, 2018

Interest [Abstract]

Schedule Of Interest Expense

	Three Months Ended March 31,
		2018		2017
Interest Expense on:
Debt	$	66	$	66
The Bow office building		16		16
Capital leases		5		5
Other		5		1
	$	92	$	88

XML

Foreign Exchange (Gain) Loss, Net (Tables)

3 Months Ended

Mar. 31, 2018

Foreign Currency [Abstract]

Foreign Exchange (Gain) Loss, Net

	Three Months Ended March 31,
		2018		2017
Unrealized Foreign Exchange (Gain) Loss on:
Translation of U.S. dollar financing debt issued from Canada	$	122	$	(33)
Translation of U.S. dollar risk management contracts issued from Canada		9		(4)
Translation of intercompany notes		19		1
		150		(36)
Foreign Exchange on Settlements of:
U.S. dollar risk management contracts issued from Canada		(7)		(1)
Intercompany notes		(50)		2
Other Monetary Revaluations		(2)		9
	$	91	$	(26)

XML

Income Taxes (Tables)

3 Months Ended

Mar. 31, 2018

Income Taxes [Abstract]

Provision For Income Taxes

	Three Months Ended March 31,
		2018		2017
Current Tax
Canada	$	-	$	(42)
United States		1		-
Other Countries		2		3
Total Current Tax Expense (Recovery)		3		(39)
Deferred Tax
Canada		(3)		18
United States		4		15
Other Countries		5		9
Total Deferred Tax Expense (Recovery)		6		42
Income Tax Expense (Recovery)	$	9	$	3
Effective Tax Rate		5.6%		0.7%

XML

Acquisitions And Divestitures (Tables)

3 Months Ended

Mar. 31, 2018

Acquisitions And Divestitures [Abstract]

Schedule of Net Acquisitions & (Divestitures)

	Three Months Ended March 31,
		2018		2017
Acquisitions
Canadian Operations	$	2	$	31
USA Operations		-		15
Total Acquisitions		2		46
Divestitures
Canadian Operations		(13)		(3)
USA Operations		(6)		-
Total Divestitures		(19)		(3)
Net Acquisitions & (Divestitures)	$	(17)	$	43

XML

Property, Plant And Equipment, Net (Tables)

3 Months Ended

Mar. 31, 2018

Property, Plant And Equipment, Net [Abstract]

Schedule Of Property, Plant And Equipment

	As at March 31, 2018						As at December 31, 2017
		Cost		Accumulated DD&A		Net		Cost		Accumulated DD&A		Net
Canadian Operations
Proved properties	$	14,366	$	(13,743)	$	623	$	14,555	$	(14,047)	$	508
Unproved properties		262		-		262		311		-		311
Other		35		-		35		43		-		43
		14,663		(13,743)		920		14,909		(14,047)		862
USA Operations
Proved properties		26,081		(23,426)		2,655		25,610		(23,240)		2,370
Unproved properties		4,039		-		4,039		4,169		-		4,169
Other		16		-		16		16		-		16
		30,136		(23,426)		6,710		29,795		(23,240)		6,555
Market Optimization		7		(6)		1		7		(5)		2
Corporate & Other		2,244		(758)		1,486		2,299		(764)		1,535
	$	47,050	$	(37,933)	$	9,117	$	47,010	$	(38,056)	$	8,954

XML

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2018

Long-Term Debt [Abstract]

Schedule Of Long-Term Debt

		As at March 31, 2018		As at December 31, 2017
U.S. Dollar Denominated Debt
U.S. Unsecured Notes
6.50% due May 15, 2019	$	500	$	500
3.90% due November 15, 2021		600		600
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		4,211		4,211
Increase in Value of Debt Acquired		25		26
Unamortized Debt Discounts and Issuance Costs		(38)		(40)
Current Portion of Long-Term Debt		-		-
	$	4,198	$	4,197

XML

Other Liabilities And Provisions (Tables)

3 Months Ended

Mar. 31, 2018

Other Liabilities And Provisions [Abstract]

Schedule of Other Liabilities and Provisions

		As at March 31, 2018		As at December 31, 2017
The Bow Office Building	$	1,304	$	1,344
Capital Lease Obligations		275		295
Unrecognized Tax Benefits		197		202
Pensions and Other Post-Employment Benefits		116		116
Long-Term Incentive Costs (See Note 16)		32		175
Other Derivative Contracts (See Notes 18, 19)		13		14
Other		21		21
	$	1,958	$	2,167

Schedule Of Expected Future Payments And Sublease Recoveries

		2018		2019		2020		2021		2022		Thereafter		Total
Expected Future Lease Payments	$	55	$	75	$	75	$	76	$	76	$	1,260	$	1,617
Less: Amounts Representing Interest		47		63		61		61		60		781		1,073
Present Value of Expected Future
Lease Payments	$	8	$	12	$	14	$	15	$	16	$	479	$	544
Sublease Recoveries (undiscounted)	$	(27)	$	(37)	$	(37)	$	(37)	$	(38)	$	(619)	$	(795)

Schedule of Future Minimum Lease Payments for Capital Leases

		2018		2019		2020		2021		2022		Thereafter		Total
Expected Future Lease Payments	$	75	$	99	$	99	$	87	$	8	$	38	$	406
Less: Amounts Representing Interest		15		15		10		4		2		5		51
Present Value of Expected Future
Lease Payments	$	60	$	84	$	89	$	83	$	6	$	33	$	355

XML

Asset Retirement Obligation (Tables)

3 Months Ended

Mar. 31, 2018

Asset Retirement Obligation [Abstract]

Schedule of Change In Asset Retirement Obligation

		As at March 31, 2018		As at December 31, 2017
Asset Retirement Obligation, Beginning of Year	$	514	$	687
Liabilities Incurred and Acquired		5		11
Liabilities Settled and Divested		(4)		(333)
Change in Estimated Future Cash Outflows		-		88
Accretion Expense		8		37
Foreign Currency Translation		(11)		24
Asset Retirement Obligation, End of Period	$	512	$	514
Current Portion	$	69	$	44
Long-Term Portion		443		470
	$	512	$	514

XML

Share Capital (Tables)

3 Months Ended

Mar. 31, 2018

Share Capital [Abstract]

Schedule Of Common Stock Issued And Outstanding

	As at March 31, 2018			As at December 31, 2017
	Number (millions)		Amount	Number (millions)		Amount
Common Shares Outstanding, Beginning of Year	973.1	$	4,757	973.0	$	4,756
Common Shares Purchased	(10.0)		(50)	-		-
Common Shares Issued Under Dividend Reinvestment Plan	-		-	0.1		1
Common Shares Outstanding, End of Period	963.1	$	4,707	973.1	$	4,757

Earnings Per Common Share

	Three Months Ended March 31,
(US$ millions, except per share amounts)		2018		2017
Net Earnings (Loss)	$	151	$	431
Number of Common Shares:
Weighted average common shares outstanding - Basic		971.5		973.0
Effect of dilutive securities		-		-
Weighted average common shares outstanding - Diluted		971.5		973.0
Net Earnings (Loss) per Common Share
Basic & Diluted	$	0.16	$	0.44

XML

Accumulated Other Comprehensive Income (Tables)

3 Months Ended

Mar. 31, 2018

Accumulated Other Comprehensive Income [Abstract]

Schedule of Accumulated Other Comprehensive Income

	Three Months Ended March 31,
		2018		2017
Foreign Currency Translation Adjustment
Balance, Beginning of Year	$	1,029	$	1,200
Change in Foreign Currency Translation Adjustment		24		(16)
Balance, End of Period	$	1,053	$	1,184
Pension and Other Post-Employment Benefit Plans
Balance, Beginning of Year	$	13	$	10
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings (See Note 17)		(1)		(1)
Income Taxes		-		-
Balance, End of Period	$	12	$	9
Total Accumulated Other Comprehensive Income	$	1,065	$	1,193

XML

Compensation Plans (Tables)

3 Months Ended

Mar. 31, 2018

Compensation Plans [Abstract]

Schedule of assumptions used to fair value share units

	As at March 31, 2018		As at March 31, 2017
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units
Risk Free Interest Rate	1.79%	1.79%	0.74%	0.74%
Dividend Yield	0.55%	0.54%	0.51%	0.51%
Expected Volatility Rate (1)	58.46%	54.78%	58.12%	54.02%
Expected Term	2.0 yrs	2.1 yrs	1.9 yrs	1.9 yrs
Market Share Price	US$11.00	C$14.17	US$11.71	C$15.58

Amounts Recognized For Share-Based Payment Transactions

	Three Months Ended March 31,
		2018		2017
Total Compensation Costs of Transactions Classified as Cash-Settled	$	(27)	$	34
Less: Total Share-Based Compensation Costs Capitalized		9		(11)
Total Share-Based Compensation Expense (Recovery)	$	(18)	$	23
Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	(6)	$	8
Administrative		(12)		15
	$	(18)	$	23

Liability for Share-Based Payment Transactions

		As at March 31, 2018		As at December 31, 2017
Liability for Cash-Settled Share-Based Payment Transactions:
Unvested	$	167	$	274
Vested		50		53
	$	217	$	327

Schedule of Share-based Compensation, Activity [Table Text Block]

Three Months Ended March 31, 2018 (thousands of units)
TSARs	872
SARs	359
PSUs	2,503
DSUs	31
RSUs	5,238

XML

Pension and Other Post-Employment Benefits (Tables)

3 Months Ended

Mar. 31, 2018

General Discussion of Pension and Other Postretirement Benefits [Abstract]

Total Benefit Plan Expense Recognized

	Pension Benefits				OPEB				Total
		2018		2017		2018		2017		2018		2017
Net Defined Periodic Benefit Cost	$	-	$	-	$	2	$	2	$	2	$	2
Defined Contribution Plan Expense		6		6		-		-		6		6
Total Benefit Plans Expense	$	6	$	6	$	2	$	2	$	8	$	8

Defined Periodic Pension And OPEB Expense

	Defined Benefits				OPEB				Total
		2018		2017		2018		2017		2018		2017
Service Cost	$	-	$	-	$	2	$	2	$	2	$	2
Interest Cost		2		2		1		1		3		3
Expected Return on Plan Assets		(2)		(2)		-		-		(2)		(2)
Amounts Reclassified from Accumulated Other
Comprehensive Income:
Amortization of net actuarial (gains) and losses		-		-		(1)		(1)		(1)		(1)
Total Net Defined Periodic Benefit Cost (1)	$	-	$	-	$	2	$	2	$	2	$	2

XML

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2018

Fair Value Measurements [Abstract]

Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis

As at March 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	$	-	$	267	$	-	$	267	$	(53)	$	214
Long-term assets		-		298		-		298		(8)		290
Foreign Currency Derivatives:
Current assets		-		12		-		12		-		12
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	241	$	62	$	303	$	(53)	$	250
Long-term liabilities		-		25		-		25		(8)		17
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-	$	5
Long-term in other liabilities and provisions		-		13		-		13		-		13
As at December 31, 2017		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	$	-	$	189	$	-	$	189	$	(15)	$	174
Long-term assets		-		248		-		248		(2)		246
Foreign Currency Derivatives:
Current assets		-		31		-		31		-		31
Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	3	$	196	$	51	$	250	$	(15)	$	235
Long-term liabilities		-		15		-		15		(2)		13
Foreign Currency Derivatives:
Current liabilities		-		1		-		1		-		1
Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-	$	5
Long-term in other liabilities and provisions		-		14		-		14		-		14

Summary Of Changes In Level 3 Fair Value Measurements

		Risk Management
		2018		2017
Balance, Beginning of Year	$	(51)	$	(36)
Total Gains (Losses)		6		41
Purchases, Sales, Issuances and Settlements:
Purchases, sales and issuances		-		-
Settlements		(17)		-
Transfers Out of Level 3 (1)		-		-
Balance, End of Period	$	(62)	$	5
Change in Unrealized Gains (Losses) Related to
Assets and Liabilities Held at End of Period	$	(24)	$	40

Quantitative Information About Unobservable Inputs Used In Level 3

	Valuation Technique	Unobservable Input	As at March 31, 2018	As at December 31, 2017
Risk Management - WTI Options	Option Model	Implied Volatility	24% - 83%	17% - 76%

XML

Financial Instruments And Risk Management (Tables)

3 Months Ended

Mar. 31, 2018

Financial Instruments And Risk Management [Abstract]

Commodity Price Positions

	Notional Volumes		Term	Average Price						Fair Value
Crude Oil and NGL Contracts						US$/bbl
Fixed Price Contracts
WTI Fixed Price	94.3	Mbbls/d	2018	55.53					$	(194)
WTI Fixed Price	15.0	Mbbls/d	2019	58.30						(2)
WTI Fixed Price Swaptions (1)	24.0	Mbbls/d	Q1 - Q2 2019			63.13				(16)
WTI Three-Way Options
Sold call / bought put / sold put	16.0	Mbbls/d	2018	54.49	/	47.17	/	36.88		(42)
WTI Costless Collars
Sold call / bought put	10.0	Mbbls/d	2018	57.08	/	45.00				(20)
Basis Contracts (2)			2018 - 2020							26
Crude Oil and NGLs Fair Value Position										(248)
Natural Gas Contracts						US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	1,007	MMcf/d	2018	3.02						52
NYMEX Fixed Price Swaptions (3)	300	MMcf/d	Q1 - Q2 2019			2.99				(9)
NYMEX Call Options
Sold call price	230	MMcf/d	2018	3.75						(1)
Sold call price	64	MMcf/d	2019	3.75						(4)
Sold call price	166	MMcf/d	2020	3.25						(1)
Basis Contracts (4)			2018							130
			2019							136
			2020							99
			2021 - 2023							86
Premiums Received on Unexpired Options										(3)
Natural Gas Fair Value Position										485
Other Derivative Contracts
Fair Value Position										(18)
Foreign Currency Contracts
Fair Value Position (5)			2018							12
Total Fair Value Position									$	231

Earnings Impact Of Realized And Unrealized Gains (Losses) On Risk Management Positions

	Three Months Ended March 31,
		2018		2017
Realized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (1)	$	(32)	$	(24)
Transportation and processing		-		(4)
Foreign Currency Derivatives:
Foreign exchange		7		1
	$	(25)	$	(27)
Unrealized Gains (Losses) on Risk Management
Commodity and Other Derivatives:
Revenues (2)	$	68	$	362
Foreign Currency Derivatives:
Foreign exchange		(18)		2
	$	50	$	364
Total Realized and Unrealized Gains (Losses) on Risk Management, net
Commodity and Other Derivatives:
Revenues (1) (2)	$	36	$	338
Transportation and processing		-		(4)
Foreign Currency Derivatives:
Foreign exchange		(11)		3
	$	25	$	337

Reconciliation Of Unrealized Risk Management Positions

		2018				2017
		Fair Value		Total Unrealized Gain (Loss)		Total Unrealized Gain (Loss)
Fair Value of Contracts, Beginning of Year	$	183
Change in Fair Value of Contracts in Place at Beginning of Year
and Contracts Entered into During the Period		25	$	25	$	337
Settlement of Other Derivative Contracts		1
Fair Value of Contracts Realized During the Period		25		25		27
Fair Value of Contracts Outstanding	$	234	$	50	$	364
Premiums Received on Unexpired Options		(3)
Fair Value of Contracts and Premiums Received, End of Period	$	231

Unrealized Risk Management Position

		As at March 31, 2018		As at December 31, 2017
Risk Management Assets
Current	$	226	$	205
Long-term		290		246
		516		451
Risk Management Liabilities
Current		250		236
Long-term		17		13
		267		249
Other Derivative Contracts
Current in accounts payable and accrued liabilities		5		5
Long-term in other liabilities and provisions		13		14
Net Risk Management Assets (Liabilities) and Other Derivative Contracts	$	231	$	183

XML

Supplementary Information (Tables)

3 Months Ended

Mar. 31, 2018

Supplementary Information [Abstract]

Net change in Non-Cash Working Capital

	Three Months Ended March 31,
		2018		2017
Operating Activities
Accounts receivable and accrued revenues	$	(2)	$	70
Accounts payable and accrued liabilities		(7)		(134)
Income tax receivable and payable		1		(96)
	$	(8)	$	(160)

Non-cash Activity

	Three Months Ended March 31,
		2018		2017
Non-Cash Investing Activities
Asset retirement obligation incurred (See Note 12)	$	5	$	3
Property, plant and equipment accruals		9		44
Capitalized long-term incentives		(36)		11
Property additions/dispositions (swaps)		49		6
Non-Cash Financing Activities
Common shares issued under dividend reinvestment plan (See Note 13)	$	-	$	-

XML

Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2018

Commitments and Contingencies [Abstract]

Commitments

		Expected Future Payments
(undiscounted)		2018		2019		2020		2021		2022		Thereafter		Total
Transportation and Processing	$	446	$	692	$	663	$	579	$	551	$	2,458	$	5,389
Drilling and Field Services		165		46		24		9		-		-		244
Operating Leases		13		16		16		15		15		46		121
Total	$	624	$	754	$	703	$	603	$	566	$	2,504	$	5,754

XML

Basis of Presentation and Principles of Consolidation (Narative) (Details)	3 Months Ended
	Mar. 31, 2018
Bow Office Building [Member]
Assets estimated service lives	60 years

XML

Segmented Information (Narrative) (Details) - Revenues and Operating Income (Loss) [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Segment Reporting, Revenue Reconciling Item [Line Items]
Quarterly Financial Information, Quarterly Charges and Credits, Amount Reconciling to Previously Reported Results		$ 8
Immaterial Error Correction	Corporate interest income of $8 million previously reported in revenues and operating income (loss) in Q1 2017 has been reclassified to other (gains) losses, net.

XML

Segmented Information (Segment And Geographical Information) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Product and Service Revenues	$ 1,260	$ 934
Gains (losses) from risk management, net	36	338
Sublease revenues	17	17
Total Revenues	1,313	1,289
Production, mineral and other taxes	29	29
Transportation and processing	249	212
Operating	111	132
Purchased product	273	171
Depreciation, depletion and amortization	275	187
Accretion of asset retirement obligation	8	11	$ 37
Administrative	31	58
Total Operating Expenses	976	800
Operating Income (Loss), Total	337	489
Interest	92	88
Foreign exchange (gain) loss, net	91	(26)
(Gain) loss on divestitures, net	(3)	1
Other (gains) losses, net	(3)	(8)
Total Other (Income) Expenses	177	55
Net Earnings (Loss) Before Income Tax	160	434
Income tax expense (Recovery)	9	3
Net Earnings (Loss)	151	431
Corporate, Non-segment [Member]
Segment Reporting Information [Line Items]
Gains (losses) from risk management, net	68	362
Sublease revenues	17	17
Total Revenues	85	379
Operating	4	5
Depreciation, depletion and amortization	13	17
Accretion of asset retirement obligation	8	11
Administrative	31	58
Total Operating Expenses	56	91
Operating Income (Loss), Total	29	288
Canadian Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and Service Revenues	404	301
Gains (losses) from risk management, net	12	(21)
Total Revenues	416	280
Production, mineral and other taxes	4	5
Transportation and processing	190	132
Operating	29	31
Depreciation, depletion and amortization	77	64
Total Operating Expenses	300	232
Operating Income (Loss), Total	116	48
USA Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and Service Revenues	555	447
Gains (losses) from risk management, net	(44)	(3)
Total Revenues	511	444
Production, mineral and other taxes	25	24
Transportation and processing	27	59
Operating	74	87
Depreciation, depletion and amortization	185	106
Total Operating Expenses	311	276
Operating Income (Loss), Total	200	168
Market Optimization [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Product and Service Revenues	301	186
Total Revenues	301	186
Transportation and processing	32	21
Operating	4	9
Purchased product	273	171
Total Operating Expenses	309	201
Operating Income (Loss), Total	$ (8)	$ (15)

XML

Segmented Information (Schedule Of Marketing Intersegment Eliminations) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Product Information [Line Items]
Revenues	$ 1,313	$ 1,289
Transportation and processing	249	212
Operating	111	132
Purchased product	273	171
Depreciation, depletion and amortization	275	187
Operating Income (Loss), Total	337	489
Market Optimization [Member] | Operating Segments [Member]
Product Information [Line Items]
Revenues	301	186
Transportation and processing	32	21
Operating	4	9
Purchased product	273	171
Operating Income (Loss), Total	(8)	(15)
Market Optimization [Member] | Reportable Subsegments [Member] | Marketing Sales [Member]
Product Information [Line Items]
Revenues	1,331	956
Transportation and processing	106	64
Operating	4	9
Purchased product	1,229	898
Operating Income (Loss), Total	(8)	(15)
Market Optimization [Member] | Intersubsegment Eliminations [Member]
Product Information [Line Items]
Revenues	(1,030)	(770)
Transportation and processing	(74)	(43)
Purchased product	$ (956)	$ (727)

XML

Segmented Information (Capital Expenditures) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Segment Reporting Information [Line Items]
Payments To Aquire Property Plant and Equipment	$ 508	$ 399
Operating Segments [Member] | Canadian Operations [Member]
Segment Reporting Information [Line Items]
Payments To Aquire Property Plant and Equipment	168	88
Operating Segments [Member] | USA Operations [Member]
Segment Reporting Information [Line Items]
Payments To Aquire Property Plant and Equipment	338	$ 311
Corporate, Non-segment [Member]
Segment Reporting Information [Line Items]
Payments To Aquire Property Plant and Equipment	$ 2

XML

Segmented Information (Goodwill, Property, Plant And Equipment And Total Assets By Segment) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	$ 2,591	$ 2,609
Property, Plant and Equipment	9,117	8,954
Total Assets	15,110	15,267
Operating Segments [Member] | Canadian Operations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	678	696
Property, Plant and Equipment	920	862
Total Assets	1,923	1,908
Operating Segments [Member] | USA Operations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Goodwill	1,913	1,913
Property, Plant and Equipment	6,710	6,555
Total Assets	9,432	9,301
Operating Segments [Member] | Market Optimization [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Property, Plant and Equipment	1	2
Total Assets	151	152
Corporate, Non-segment [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Property, Plant and Equipment	1,486	1,535
Total Assets	$ 3,604	$ 3,906

XML

Revenue from Contracts with Customers (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Contract with Customer, Asset, Net	$ 0
Contract with Customer, Liability	0
Receivables & Accrued Revenues from Contracts with Customers	658		$ 676
Revenue, Remaining Performance Obligation	$ 0
Revenue [Member]
Quarterly Financial Information, Quarterly Charges and Credits, Amount Reconciling to Previously Reported Results		$ 8
Immaterial Error Correction	Corporate interest income of $8 million previously reported in revenues in Q1 2017 has been reclassified to other (gains) losses, net.

XML

Revenue from Contracts wtih Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Disaggregation of Revenue [Line Items]
Product revenues	$ 1,260	$ 934
Gains (losses) from risk management, net	36	338
Sublease revenues	17	17
Other revenues	53	355
Total Revenues	1,313	1,289
Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Product revenues	498	340
Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Product revenues	234	147
Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Product revenues	526	437
Natural gas gathering and compression [Member]
Disaggregation of Revenue [Line Items]
Product revenues	2	10
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	406	304
Gains (losses) from risk management, net	12	(21)
Other revenues	12	(21)
Total Revenues	418	283
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Product revenues	3	2
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Product revenues	180	95
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Product revenues	221	203
Operating Segments [Member] | Canadian Operations Excluding Intercompany Segment Transactions [Member] | Natural gas gathering and compression [Member]
Disaggregation of Revenue [Line Items]
Product revenues	2	4
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	557	454
Gains (losses) from risk management, net	(44)	(3)
Other revenues	(44)	(3)
Total Revenues	513	451
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Product revenues	473	301
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Product revenues	52	40
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Product revenues	32	107
Operating Segments [Member] | USA Operations Excluding Intercompany Segment Transactions [Member] | Natural gas gathering and compression [Member]
Disaggregation of Revenue [Line Items]
Product revenues		6
Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member]
Disaggregation of Revenue [Line Items]
Product revenues	297	176
Total Revenues	297	176
Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Crude Oil [Member]
Disaggregation of Revenue [Line Items]
Product revenues	22	37
Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Product revenues	2	12
Operating Segments [Member] | Market Optimization Excluding Intercompany Segment Transactions [Member] | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Product revenues	273	127
Corporate, Non-segment [Member]
Disaggregation of Revenue [Line Items]
Gains (losses) from risk management, net	68	362
Sublease revenues	17	17
Other revenues	85	379
Total Revenues	$ 85	$ 379

XML

Interest (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Interest [Abstract]
Interest Expense on Debt	$ 66	$ 66
The Bow Office Building	16	16
Capital Leases	5	5
Other	5	1
Interest	$ 92	$ 88

XML

Foreign Exchange (Gain) Loss, Net (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	$ 150	$ (36)
Foreign exchange on settlements	(50)	2
Foreign Exchange (Gain) Loss, Net	91	(26)
Translation Of U.S. Dollar Debt Issued From Canada [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	122	(33)
Translation Of U.S. Dollar Risk Management Contracts Issued From Canada [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	9	(4)
Foreign exchange on settlements	(7)	(1)
Translation of Intercompany Notes [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Unrealized foreign exchange (gain) loss	19	1
Foreign exchange on settlements	(50)	2
Other Monetary Revaluations [Member]
Schedule Of Foreign Exchange Transactions [Line Items]
Foreign exchange on settlements	$ (2)	$ 9

XML

Income Taxes (Narrative) (Details)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Income Taxes [Abstract]
Effective Income Tax Rate, Continuing Operations	5.60%	0.70%
Canadian Statutory rate	27.00%

XML

Income Taxes (Provision For Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Current Tax	$ 3	$ (39)
Deferred Tax	6	42
Income Tax Expense (Recovery), Total	$ 9	$ 3
Effective Income Tax Rate, Continuing Operations	5.60%	0.70%
Canada [Member]
Current Tax		$ (42)
Deferred Tax	$ (3)	18
United States [Member]
Current Tax	1
Deferred Tax	4	15
Other Countries [Member]
Current Tax	2	3
Deferred Tax	$ 5	$ 9

XML

Acquisitions and Divestitures (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Acquisitions and Divestitures [Line Items]
Acquisitions	$ 2	$ 46
Proceeds from divestitures	19	3
Gain (Loss) on Disposition of Assets	3	(1)
Canadian Operations [Member] | Operating Segments [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	2	31
Proceeds from divestitures	13	3
USA Operations [Member] | Operating Segments [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	0	15
Proceeds from divestitures	$ 6	$ 0

XML

Acquisitions and Divestitures (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Acquisitions and Divestitures [Line Items]
Acquisitions	$ 2	$ 46
Divestitures	(19)	(3)
Net Acquisitions and Divestitures	(17)	43
Operating Segments [Member] | Canadian Operations [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	2	31
Divestitures	(13)	(3)
Operating Segments [Member] | USA Operations [Member]
Acquisitions and Divestitures [Line Items]
Acquisitions	0	15
Divestitures	$ (6)	$ 0

XML

Property, Plant And Equipment, Net (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Internal Costs Capitalized	$ 39	$ 54
Property, Plant and Equipment, Net	9,117		$ 8,954
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	37,933		38,056
Bow Office Building [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net	$ 1,216		1,255
Term of Lease Agreement Liability, In Years	25 years
Property, Plant and Equipment, Useful Life	60 years
Assets Held under Capital Leases [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net	$ 45		46
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	672		684
Corporate, Non-segment [Member]
Property, Plant and Equipment [Line Items]
Fully Amortized Property Costs	61		63
Property, Plant and Equipment, Net	$ 1,486		$ 1,535

XML

Property, Plant And Equipment, Net (Schedule Of Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	$ 47,050	$ 47,010
Less: Accumulated depreciation, depletion and amortization	(37,933)	(38,056)
Property, plant and equipment, net	9,117	8,954
Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	14,663	14,909
Less: Accumulated depreciation, depletion and amortization	(13,743)	(14,047)
Property, plant and equipment, net	920	862
Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	30,136	29,795
Less: Accumulated depreciation, depletion and amortization	(23,426)	(23,240)
Property, plant and equipment, net	6,710	6,555
Operating Segments [Member] | Market Optimization [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	1	2
Corporate, Non-segment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	1,486	1,535
Proved Properties [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	14,366	14,555
Less: Accumulated depreciation, depletion and amortization	(13,743)	(14,047)
Property, plant and equipment, net	623	508
Proved Properties [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	26,081	25,610
Less: Accumulated depreciation, depletion and amortization	(23,426)	(23,240)
Property, plant and equipment, net	2,655	2,370
Unproved Properties [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	262	311
Property, plant and equipment, net	262	311
Unproved Properties [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	4,039	4,169
Property, plant and equipment, net	4,039	4,169
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | Canadian Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	35	43
Property, plant and equipment, net	35	43
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | USA Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	16	16
Property, plant and equipment, net	16	16
Other Capitalized Property Plant and Equipment [Member] | Operating Segments [Member] | Market Optimization [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	7	7
Less: Accumulated depreciation, depletion and amortization	(6)	(5)
Property, plant and equipment, net	1	2
Other Capitalized Property Plant and Equipment [Member] | Corporate, Non-segment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	2,244	2,299
Less: Accumulated depreciation, depletion and amortization	(758)	(764)
Property, plant and equipment, net	$ 1,486	$ 1,535

XML

Long-Term Debt (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Long-Term Debt [Abstract]
Long-term Debt Carrying Value	$ 4,198	$ 4,197
Long-term Debt, Fair Value	$ 4,909	$ 5,042

XML

Long-Term Debt (Schedule Of Long-Term Debt) (Details) - USD ($)	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total Principal	$ 4,211,000,000	$ 4,211,000,000
Increase In Value Of Debt Acquired	25,000,000	26,000,000
Debt Discounts	(38,000,000)	(40,000,000)
Long-Term Debt	4,198,000,000	4,197,000,000
6.50% Unsecured Notes [Member] | Unsecured Notes, Due May 15, 2019 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 500,000,000	500,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
6.50% Unsecured Notes [Member] | Unsecured Notes, Due August 15, 2034 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 750,000,000	750,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
6.50% Unsecured Notes [Member] | Unsecured Notes, Due February 1, 2038 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 505,000,000	505,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
3.90% Unsecured Notes [Member] | Unsecured Notes, Due November 15, 2021 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 600,000,000	600,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.90%
8.125% Unsecured Notes [Member] | Unsecured Notes, Due September 15, 2030 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 300,000,000	300,000,000
Debt Instrument, Interest Rate, Stated Percentage	8.125%
7.20% Unsecured Notes [Member] | Unsecured Notes, Due November 1, 2031 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 350,000,000	350,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.20%
7.375% Unsecured Notes [Member] | Unsecured Notes, Due November 1, 2031 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 500,000,000	500,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.375%
6.625% Unsecured Notes [Member] | Unsecured Notes, Due August 15, 2037 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 462,000,000	462,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.625%
5.15% Unsecured Notes [Member] | Unsecured Notes, Due November 15, 2041 [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 244,000,000	$ 244,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.15%

XML

Other Liabilities And Provisions (Narrative) (Details) - Bow Office Building [Member]	3 Months Ended
	Mar. 31, 2018
Other Liabilities And Provisions [Line Items]
Term of Lease Agreement Liability, In Years	25 years
Percentage of Lease Sublet	50.00%

XML

Other Liabilities And Provisions (Schedule Of Other Liabilities And Provisions) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Other Liabilities And Provisions [Line Items]
The Bow Office Building	$ 1,304	$ 1,344
Obligation under Capital Lease	275	295
Unrecognized Tax Benefits	197	202
Pensions and Other Post-Employment Benefits	116	116
Long-Term Incentives	32	175
Other Derivative Contracts, Liabilities	18	19
Other	21	21
Other Liabilities and Provisions	1,958	2,167
Other Liabilities and Provisions [Member]
Other Liabilities And Provisions [Line Items]
Other Derivative Contracts, Liabilities	$ 13	$ 14

XML

Other Liabilities And Provisions (Schedule Of Expected Future Payments And Sublease Recoveries) (Details) - Bow Office Building [Member] $ in Millions	Mar. 31, 2018 USD ($)
Other Liabilities And Provisions [Line Items]
Expected future payments, year one	$ 55
Expected future payments, year two	75
Expected future payments, year three	75
Expected future payments, year four	76
Expected future payments, year five	76
Expected future payments, Thereafter	1,260
Expected future payments, Total	1,617
Sublease recoveries, year one	(27)
Sublease recoveries, year two	(37)
Sublease recoveries, year three	(37)
Sublease recoveries, year four	(37)
Sublease recoveries, year five	(38)
Sublease recoveries, Thereafter	(619)
Sublease recoveries, Total	(795)
Expected Future Payments, Interest Amount [Member]
Other Liabilities And Provisions [Line Items]
Expected future payments, year one	47
Expected future payments, year two	63
Expected future payments, year three	61
Expected future payments, year four	61
Expected future payments, year five	60
Expected future payments, Thereafter	781
Expected future payments, amount representing interest	1,073
Present Value of Expected Future Payments [Member]
Other Liabilities And Provisions [Line Items]
Expected future payments, year one	8
Expected future payments, year two	12
Expected future payments, year three	14
Expected future payments, year four	15
Expected future payments, year five	16
Expected future payments, Thereafter	479
Expected future payments, present value, Total	$ 544

XML

Other Liabilities and Provisions (Schedule of Capital Lease Obligation Payments) (Details) $ in Millions	Mar. 31, 2018 USD ($)
Capital Lease Obligation [Line Items]
Minimum lease payments due, next twelve months	$ 75
Minimum lease payments due in two years	99
Minimum lease payments due in three years	99
Minimum lease payments due in four years	87
Minimum lease payments due in five years	8
Minimum lease payments due, thereafter	38
Minimum lease payments, total	406
Capital Lease Future Minimum Interest Payments [Member]
Capital Lease Obligation [Line Items]
Minimum lease payments due, next twelve months	15
Minimum lease payments due in two years	15
Minimum lease payments due in three years	10
Minimum lease payments due in four years	4
Minimum lease payments due in five years	2
Minimum lease payments due, thereafter	5
Minimum lease payment, amount representing interest	51
Capital Lease Present value of Expected Future Payments [Member]
Capital Lease Obligation [Line Items]
Minimum lease payments due, next twelve months	60
Minimum lease payments due in two years	84
Minimum lease payments due in three years	89
Minimum lease payments due in four years	83
Minimum lease payments due in five years	6
Minimum lease payments due, thereafter	33
Minimum lease payments, present value	$ 355

XML

Asset Retirement Obligation (Schedule of Change In Asset Retirement Obligation) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Asset Retirement Obligation [Abstract]
Asset Retirement Obligation, Beginning of Year	$ 514	$ 687	$ 687
Liabilities Incurred and Acquired	5	3	11
Liabilities Settled	(4)		(333)
Change in Estimated Future Cash Outflows			88
Accretion of asset retirement obligation	8	$ 11	37
Foreign Currency Translation	(11)		24
Asset Retirement Obligation, End of Period	$ 512		$ 514

XML

Asset Retirement Obligation (Schedule Of Asset Retirement Obligation) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation [Abstract]
Current Portion	$ 69	$ 44
Long-Term Portion	443	470
Asset Retirement Obligation, Total	$ 512	$ 514	$ 687

XML

Share Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions			3 Months Ended					12 Months Ended
	Apr. 30, 2018	Feb. 15, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2017
Class of Stock [Line Items]
Common Shares Issued under Dividend Reinvestment Plan, Shares			23,023					58,480
Common Shares Issued under Dividend Reinvestment Plan			$ 0.3					$ 0.6
Dividends on Common Shares			$ 15.0				$ 15.0
Common Stock, Dividends, Per Share, Paid			$ 0.015	$ 0.015	$ 0.015	$ 0.015	$ 0.015
Dividends, Common Shares Issued In Lieu of Cash, Value			$ 0.3				$ 0.2
Stock Repurchase Program, Number of Shares Authorized to be Repurchased		35,000,000
Stock Repurchase Program, Authorized Amount		$ 400.0
Stock Repurchase Program Expiration Date		Feb. 27, 2019
Common Shares Purchased, Shares			10,000,000
Common Shares Purchased under Normal Course Issuer Bid			$ 111.0
Payments for Repurchase of Common Stock			111.0
Subsequent Event [Member]
Class of Stock [Line Items]
Dividends Payable, Date Declared	Apr. 30, 2018
Common Stock, Dividends, Per Share, Declared	$ 0.015
Dividends Payable, Date to be Paid	Jun. 29, 2018
Dividends Payable, Date of Record	Jun. 15, 2018
Share Capital [Member]
Class of Stock [Line Items]
Common Shares Purchased under Normal Course Issuer Bid			50.0
Retained Earnings [Member]
Class of Stock [Line Items]
Dividends on Common Shares			15.0				$ 15.0
Common Shares Purchased under Normal Course Issuer Bid			$ 61.0

XML

Share Capital (Schedule Of Common Stock Issued And Outstanding) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Common Shares Outstanding, Beginning of Year, Shares	973,100,000	973,000,000
Common Shares Purchased, Shares	(10,000,000)
Common Shares Issued under Dividend Reinvestment Plan, Shares	23,023	58,480
Common Shares Outstanding, End of Period, Shares	963,100,000	973,100,000
Common Shares Outstanding, Beginning of Year	$ 4,757.0	$ 4,756.0
Common Shares Purchased, Value	(111.0)
Common Shares Issued under Dividend Reinvestment Plan	0.3	0.6
Common Shares Outstanding, End of Period	4,707.0	$ 4,757.0
Share Capital [Member]
Common Shares Purchased, Value	$ (50.0)

XML

Share Capital (Earnings Per Common Share) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Share Capital [Abstract]
Net earnings (loss)	$ 151	$ 431
Weighted Average Common Shares Outstanding - Basic	971.5	973.0
Weighted Average Common Shares Outstanding - Diluted	971.5	973.0
Earnings Per Share, Basic and Diluted	$ 0.16	$ 0.44

XML

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Accumulated Other Comprehensive Income [Abstract]
AOCI - Foreign Currency Translation Adjustment, Beginning of Period	$ 1,029	$ 1,200
Current Period Change in Foreign Currency Translation Adjustment	24	(16)
AOCI - Foreign Currency Translation Adjustment, End of Period	1,053	1,184
AOCI - Pension and OPEB, Beginning Balance	13	10
Reclassification of Net Actuarial (Gains) and Losses to Net Earnings	(1)	(1)
AOCI - Pension and OPEB, Ending Balance	12	9
Total Accumulated Other Comprehensive Income	$ 1,065	$ 1,193	$ 1,042

XML

Variable Interest Entities (Narrative) (Details) MMcf in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) MMcf	Dec. 31, 2017 USD ($)
Variable Interest Entity [Line Items]
Accounts Payable and Accrued Liabilities, Current	$ 1,432	$ 1,415
Production Field Centre [Member]
Variable Interest Entity [Line Items]
Number of Terms	12
Lease Expiration Date	Dec. 01, 2021
Capital Lease Obligations	$ 296	$ 314
Length of Renewal Term, in Years	1 year
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	$ 2,390
Veresen Midstream Limited Partnership [Member] | Minimum [Member]
Variable Interest Entity [Line Items]
Length of Remaining Terms, In Years	13 years
Veresen Midstream Limited Partnership [Member] | Maximum [Member]
Variable Interest Entity [Line Items]
Length of Remaining Terms, In Years	27 years
Length of Renewal Term, in Years	10 years
Veresen Midstream Limited Partnership [Member] | Natural gas gathering and compression [Member]
Variable Interest Entity [Line Items]
Contracted Capacity Volumes | MMcf	1,110
Veresen Midstream Limited Partnership [Member] | Natural gas processing [Member]
Variable Interest Entity [Line Items]
Contracted Capacity Volumes | MMcf	600
Take or Pay Commitment [Member] | Veresen Midstream Limited Partnership [Member]
Variable Interest Entity [Line Items]
Accounts Payable and Accrued Liabilities, Current	$ 0

XML

Compensation Plans (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Compensation Plans [Abstract]
Liability For Cash-Settled Share-Based Payment Transactions	$ 217	$ 327
Liability for share-based payment recognized in accounts payable and accrued liabilities	185	152
Liability for share-based payment recognized in other liabilities and provisions	$ 32	$ 175

XML

Compensation Plans (Schedule of FV Assumptions) (Details) - $ / shares	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
United States Of America Dollars [Member]
Fair Value Assumptions, Risk Free Interest Rate	1.79%	0.74%
Fair Value Assumption Dividend Yield	0.55%	0.51%
Fair Value Assumptions, Expected Volatility Rate	58.46%	58.12%
Fair Value Assumptions, Expected Term	2 years	1 year 10 months 24 days
Market Share price	$ 11.00	$ 11.71
Canadian Dollar [Member]
Fair Value Assumptions, Risk Free Interest Rate	1.79%	0.74%
Fair Value Assumption Dividend Yield	0.54%	0.51%
Fair Value Assumptions, Expected Volatility Rate	54.78%	54.02%
Fair Value Assumptions, Expected Term	2 years 1 month 6 days	1 year 10 months 24 days
Market Share price	$ 14.17	$ 15.58

XML

Compensation Plans (Amounts Recognized For Share-Based Payment Transactions) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Costs of Transaction Classified as Cash-Settled	$ (27)	$ 34
Less: Total Share-Based Compensation Costs Capitalized	9	(11)
Total Share-Based Compensation Expense	(18)	23
Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Share-Based Compensation Expense	(12)	15
Operating Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Share-Based Compensation Expense	$ (6)	$ 8

XML

Compensation Plans (Liability For Share-Based Payment Transactions) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Compensation Plans [Abstract]
Liability for Unvested Cash-Settled Share-Based Payment Transactions	$ 167	$ 274
Liability for Vested Cash-Settled Share-Based Payment Transactions	50	53
Liability for Cash-Settled Share-Based Payment Transactions	$ 217	$ 327

XML

Compensation Plans (Schedule of Share-based Compensation, Activity) (Details) shares in Thousands	3 Months Ended
	Mar. 31, 2018 shares
Tandem Stock Appreciation Rights (TSARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	872
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	359
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	2,503
Deferred Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	31
Restricted Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	5,238

XML

Pension and Other Post-Employment Benefits (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	$ 8	$ 8
Operating Expense [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	6	6
Administrative Expense [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefit Expense	$ 2	$ 2

XML

Pension and Other Post-Employment Benefits (Total Benefit Plan Expense Recognized) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Net Defined Benefit Plan Expense	$ 2	$ 2
Defined Contribution Plan Expense	6	6
Total Benefit Plans Expense	8	8
Pension Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan Expense	6	6
Total Benefit Plans Expense	6	6
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Net Defined Benefit Plan Expense	2	2
Total Benefit Plans Expense	$ 2	$ 2

XML

Pension and Other Post-Employment Benefits (Defined Periodic Pension And OPEB Expense) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Current service cost	$ 2	$ 2
Interest cost	3	3
Expected return on plan assets	(2)	(2)
Amortization of net actuarial gains and losses	(1)	(1)
Total Defined Benefit Plan Expense	2	2
Pension Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	2	2
Expected return on plan assets	(2)	(2)
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Current service cost	2	2
Interest cost	1	1
Amortization of net actuarial gains and losses	(1)	(1)
Total Defined Benefit Plan Expense	$ 2	$ 2

XML

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Ten Percent Change in Implied Volatility [member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Increase (Decrease) in Risk Management Assets and Liabilities	$ 1	$ 2

XML

Fair Value Measurements (Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Net, Current	$ 226	$ 205
Risk Management Assets, Net, Long-term	290	246
Risk Management Liabilities, Net, Current	250	236
Risk Management Liabilities, Net, Long-term	17	13
Guarantor Obligations, Current Carrying Value	18	19
Accounts Payable and Accrued Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	5	5
Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Guarantor Obligations, Current Carrying Value	13	14
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	5	5
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	13	14
Commodity Contract [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	267	189
Risk Management Assets, Net, Current	214	174
Risk Management Assets, Gross Liabilities	(53)	(15)
Commodity Contract [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	298	248
Risk Management Assets, Net, Long-term	290	246
Risk Management Assets, Gross Liabilities	(8)	(2)
Commodity Contract [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	303	250
Risk Management Liabilities, Net, Current	250	235
Risk Management Liabilities, Gross Assets	(53)	(15)
Commodity Contract [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	25	15
Risk Management Liabilities, Net, Long-term	17	13
Risk Management Liabilities, Gross Assets	(8)	(2)
Commodity Contract [Member] | Level 1 [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities		3
Commodity Contract [Member] | Level 2 [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	267	189
Commodity Contract [Member] | Level 2 [Member] | Other Noncurrent Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	298	248
Commodity Contract [Member] | Level 2 [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	241	196
Commodity Contract [Member] | Level 2 [Member] | Other Liabilities and Provisions [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	25	15
Commodity Contract [Member] | Level 3 [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities	62	51
Foreign Exchange Contract [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	12	31
Risk Management Assets, Net, Current	12	31
Foreign Exchange Contract [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities		1
Risk Management Liabilities, Net, Current		1
Foreign Exchange Contract [Member] | Level 2 [Member] | Other Current Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Assets, Gross assets	$ 12	31
Foreign Exchange Contract [Member] | Level 2 [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Risk Management Liabilities, Gross liabilities		$ 1

XML

Fair Value Measurement (Summary Of Changes In Level 3 Fair Value Measurements) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Balance, Beginning Balance	$ (51)	$ (36)
Total Gains (Losses)	6	41
Settlements	(17)
Balance, Ending Balance	(62)	5
Change in Unrealized Gains (Losses) Related to Assets and Liabilities Held at End of Period	$ (24)	$ 40

XML

Fair Value Measurements (Quantitative Information About Unobservable Inputs Used In Level 3) (Details) - WTI Options [Member] - Option Model [Member]	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Maximum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Fair Value Inputs Commodity Price Volatility	83.00%	76.00%
Minimum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Fair Value Inputs Commodity Price Volatility	24.00%	17.00%

XML

Financial Instruments And Risk Management (Narrative) (Details)	3 Months Ended		12 Months Ended
	Mar. 31, 2018 USD ($) contract item $ / $	Mar. 31, 2017 USD ($)	Dec. 31, 2017 USD ($) item
Derivative [Line Items]
Foreign currency swap, contract amount outstanding	$ 538,000,000
Investment Foreign Currency, Contract, Transaction Type Flag	Buy
Derivative, Average Forward Exchange Rate | $ / $	0.76060
Maximum Remaining Maturity of Foreign Currency Derivatives	9 months
Realized Gain (Loss) on Derivatives	$ (25,000,000)	$ (27,000,000)
Unrealized Gain (Loss) on Derivatives	50,000,000	364,000,000
Collateral balances	$ 0
Number of Credit Risk Derivatives Held | contract	0
Percent of Accounts Receivable and Financial Derivative credit exposures with investment grade counterparties	93.00%		92.00%
Number Of Counterparties With More Than Ten Percent Of The Fair Value Of The Outstanding Risk Management Contracts | item	2		3
Guarantor Obligations, Current Carrying Value	$ 18,000,000		$ 19,000,000
Maximum [Member]
Derivative [Line Items]
Guarantor Obligations, Term	P6Y
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 317,000,000
Minimum [Member]
Derivative [Line Items]
Guarantor Obligations, Term	P3Y
Other Derivative Contracts [Member]
Derivative [Line Items]
Realized Gain (Loss) on Derivatives	$ 1,000,000	2,000,000
Unrealized Gain (Loss) on Derivatives	$ 0	$ 0
Counterparty One [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts	53.00%		56.00%
Counterparty Two [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts	11.00%		11.00%
Counterparty Three [Member]
Derivative [Line Items]
Percent Of The Fair Value Of Outstanding In The Money Net Risk Management Contracts			11.00%

XML

Financial Instruments And Risk Management (Risk Management Positions) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) $ / bbl $ / Mcf MBbls MMcf	Dec. 31, 2017 USD ($)
Derivative [Line Items]
Other Derivative Contracts, Net	$ (18)
Risk Management and Other Derivative Guarantee, at Fair Value, Net	231	$ 183
Premiums Received on Unexpired Options	(3)
Currency Swap [Member]
Derivative [Line Items]
Foreign Currency Swaps, at Fair value, Net	12
Oil [Member] | Basis Contracts [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 26
Oil [Member] | WTI Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	94.3
Average Price, Fixed Price Contracts | $ / bbl	55.53
Price Risk Derivatives, at Fair Value, Net	$ (194)
Oil [Member] | WTI Fixed Price, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	15.0
Average Price, Fixed Price Contracts | $ / bbl	58.30
Price Risk Derivatives, at Fair Value, Net	$ (2)
Oil [Member] | WTI Fixed Price Swaptions [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	24.0
Average Price, Options/Collars | $ / bbl	63.13
Price Risk Derivatives, at Fair Value, Net	$ (16)
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	16.0
Price Risk Derivatives, at Fair Value, Net	$ (42)
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Call Option [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	54.49
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Put Option [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	36.88
Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member] | Put Option [Member] | Bought [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	47.17
Oil [Member] | WTI Costless Collars, Maturing Next Twelve months [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MBbls	10.0
Price Risk Derivatives, at Fair Value, Net	$ (20)
Oil [Member] | WTI Costless Collars, Maturing Next Twelve months [Member] | Call Option [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	57.08
Oil [Member] | WTI Costless Collars, Maturing Next Twelve months [Member] | Put Option [Member] | Bought [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / bbl	45.00
Oil and NGLs [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ (248)
Natural Gas [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 485
Natural Gas [Member] | NYMEX Fixed Price, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMcf	1,007
Average Price, Fixed Price Contracts | $ / Mcf	3.02
Price Risk Derivatives, at Fair Value, Net	$ 52
Natural Gas [Member] | NYMEX Fixed Price Swaptions [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMcf	300
Average Price, Options/Collars | $ / Mcf	2.99
Price Risk Derivatives, at Fair Value, Net	$ (9)
Natural Gas [Member] | NYMEX Call Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMcf	230
Price Risk Derivatives, at Fair Value, Net	$ (1)
Natural Gas [Member] | NYMEX Call Options, Maturing Remainder Of Fiscal Year [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	3.75
Natural Gas [Member] | NYMEX Call Options, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMcf	64
Price Risk Derivatives, at Fair Value, Net	$ (4)
Natural Gas [Member] | NYMEX Call Options, Maturing Next Twelve Months [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	3.75
Natural Gas [Member] | NYMEX Call Options, Maturing In Two Years [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMcf	166
Price Risk Derivatives, at Fair Value, Net	$ (1)
Natural Gas [Member] | NYMEX Call Options, Maturing In Two Years [Member] | Sold [Member]
Derivative [Line Items]
Average Price, Options/Collars | $ / Mcf	3.25
Natural Gas [Member] | Basis Contracts, Maturing Remainder of Year [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 130
Natural Gas [Member] | Basis Contracts, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	136
Natural Gas [Member] | Basis Contracts, Maturing In Two Years [Member[
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	99
Natural Gas [Member] | Basis Contracts, Maturing After Three Years [Member]
Derivative [Line Items]
Price Risk Derivatives, at Fair Value, Net	$ 86
Minimum [Member] | Oil [Member] | Basis Contracts [Member]
Derivative [Line Items]
Term	Jan. 01, 2018
Minimum [Member] | Oil [Member] | WTI Fixed Price Swaptions [Member]
Derivative [Line Items]
Term	Jan. 01, 2019
Minimum [Member] | Natural Gas [Member] | NYMEX Fixed Price Swaptions [Member]
Derivative [Line Items]
Term	Jan. 01, 2019
Minimum [Member] | Natural Gas [Member] | Basis Contracts, Maturing After Three Years [Member]
Derivative [Line Items]
Term	Jan. 01, 2021
Maximum [Member] | Currency Swap [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Oil [Member] | Basis Contracts [Member]
Derivative [Line Items]
Term	Dec. 31, 2020
Maximum [Member] | Oil [Member] | WTI Fixed Price, Maturing Remainder of Fiscal Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Oil [Member] | WTI Fixed Price, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Term	Dec. 31, 2019
Maximum [Member] | Oil [Member] | WTI Fixed Price Swaptions [Member]
Derivative [Line Items]
Term	Jun. 30, 2019
Maximum [Member] | Oil [Member] | WTI Three-Way Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Oil [Member] | WTI Costless Collars, Maturing Next Twelve months [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Natural Gas [Member] | NYMEX Fixed Price, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Natural Gas [Member] | NYMEX Fixed Price Swaptions [Member]
Derivative [Line Items]
Term	Jun. 30, 2019
Maximum [Member] | Natural Gas [Member] | NYMEX Call Options, Maturing Remainder Of Fiscal Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Natural Gas [Member] | NYMEX Call Options, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Term	Dec. 31, 2019
Maximum [Member] | Natural Gas [Member] | NYMEX Call Options, Maturing In Two Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2020
Maximum [Member] | Natural Gas [Member] | Basis Contracts, Maturing Remainder of Year [Member]
Derivative [Line Items]
Term	Dec. 31, 2018
Maximum [Member] | Natural Gas [Member] | Basis Contracts, Maturing Next Twelve Months [Member]
Derivative [Line Items]
Term	Dec. 31, 2019
Maximum [Member] | Natural Gas [Member] | Basis Contracts, Maturing In Two Years [Member[
Derivative [Line Items]
Term	Dec. 31, 2020
Maximum [Member] | Natural Gas [Member] | Basis Contracts, Maturing After Three Years [Member]
Derivative [Line Items]
Term	Dec. 31, 2023

XML

Financial Instruments and Risk Management (Earnings Impact of Realized and Unrealized Gains (Losses) On Risk Management Positions) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	$ (25)	$ (27)
Unrealized Gain (Loss) on Derivatives	50	364
Realized and Unrealized Gain (Loss) on Risk Management	25	337
Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	(32)	(24)
Unrealized Gain (Loss) on Derivatives	68	362
Realized and Unrealized Gain (Loss) on Risk Management	36	338
Transportation and Processing [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives		(4)
Realized and Unrealized Gain (Loss) on Risk Management		(4)
Foreign Currency Gain (Loss) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gain (Loss) on Derivatives	7	1
Unrealized Gain (Loss) on Derivatives	(18)	2
Realized and Unrealized Gain (Loss) on Risk Management	$ (11)	$ 3

XML

Financial Instruments And Risk Management (Reconciliation Of Unrealized Risk Management Positions) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Derivative [Line Items]
Risk Management and Other Derivative Guarantee, at Fair Value, Net, Start of year	$ 183
Fair Value of Contracts Realized During the Period	25	$ 27
Risk Management And Other Derivative Guarantee, At Fair Value, Net, Before Premiums, End of Period	234
Risk Management and Other Derivative Guarantee, at Fair Value, Net, End of Period	231
Unrealized Gain (Loss) on Derivatives	50	364
Premiums Received on Unexpired Options	(3)
Commodity Contract [Member]
Derivative [Line Items]
Increase (Decrease) in Derivative Assets and Liabilities	25	337
Other Derivative Contracts [Member]
Derivative [Line Items]
Increase (Decrease) in Derivative Assets and Liabilities	1
Fair Value of Contracts Realized During the Period	(1)	(2)
Unrealized Gain (Loss) on Derivatives	$ 0	$ 0

XML

Financial Instruments And Risk Management (Unrealized Risk Management Position) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Risk Management, Current asset	$ 226	$ 205
Risk Management, Long-term asset	290	246
Risk Management, Total asset	516	451
Risk Management, Current liability	250	236
Risk Management, Long-term liability	17	13
Risk Management, Total liability	267	249
Guarantor Obligations, Current Carrying Value	18	19
Risk Management and Other Derivative Guarantee, at Fair Value, Net	231	183
Accounts Payable and Accrued Liabilities [Member]
Derivatives, Fair Value [Line Items]
Guarantor Obligations, Current Carrying Value	5	5
Other Liabilities and Provisions [Member]
Derivatives, Fair Value [Line Items]
Guarantor Obligations, Current Carrying Value	$ 13	$ 14

XML

Supplementary Information (Net Change in Non-Cash Working Capital) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Supplementary Information [Abstract]
Accounts receivable and accrued revenues	$ (2)	$ 70
Accounts payable and accrued liabilities	(7)	(134)
Income tax payable and receivable	1	(96)
Net change in non-cash working capital	$ (8)	$ (160)

XML

Supplementary Information (Non-Cash Activity) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Asset retirement obligation incurred	$ 5.0	$ 3.0	$ 11.0
Asset retirement obligation change in estimated future cash outflows			88.0
Property, plant and equipment accruals	9.0	44.0
Capitalized long-term incentives	(9.0)	11.0
Capitalized long-term incentives	(36.0)	11.0
Property additions/dispositions	49.0	$ 6.0
Common Shares Issued under Dividend Reinvestment Plan	$ 0.3		$ 0.6

XML

Commitments and Contingencies (Details) $ in Millions	Mar. 31, 2018 USD ($)
Long-term Commitment [Line Items]
Operating Leases, Future Minimum Payments, Remainder of Fiscal Year	$ 13
Operating Leases, Future Minimum Payments, Due in Two Years	16
Operating Leases, Future Minimum Payments, Due in Three Years	16
Operating Leases, Future Minimum Payments, Due in Four Years	15
Operating Leases, Future Minimum Payments, Due in Five Years	15
Operating Leases, Future Minimum Payments, Due Thereafter	46
Operating Leases, Future Minimum Payments Due	121
Total Commitment, Due Remainder of Fiscal Year	624
Total Commitment, Due in Second Year	754
Total Commitment, Due in Third Year	703
Total Commitment, Due in Fourth Year	603
Total Commitment, Due in Fifth Year	566
Total Commitment, Due Thereafter	2,504
Total Commitment	5,754
Transportation And Processing Commitments [Member]
Long-term Commitment [Line Items]
Purchase Obligation, Remainder of Fiscal Year	446
Purchase Obligation, Due in Second Year	692
Purchase Obligation, Due in Third Year	663
Purchase Obligation, Due in Fourth Year	579
Purchase Obligation, Due in Fifth Year	551
Purchase Obligation, Due Thereafter	2,458
Purchase Obligation	5,389
Drilling And Field Services Commitments [Member]
Long-term Commitment [Line Items]
Purchase Obligation, Remainder of Fiscal Year	165
Purchase Obligation, Due in Second Year	46
Purchase Obligation, Due in Third Year	24
Purchase Obligation, Due in Fourth Year	9
Purchase Obligation	$ 244

XML

Label	Element	Value
Cash	us-gaap_Cash	$ 45,000,000
Cash	us-gaap_Cash	39,000,000
Cash Equivalents, at Carrying Value	us-gaap_CashEquivalentsAtCarryingValue	478,000,000
Cash Equivalents, at Carrying Value	us-gaap_CashEquivalentsAtCarryingValue	$ 394,000,000