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

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 every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ~~[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.

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

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

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.

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

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.

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.

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.

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

Readers are cautioned against unduly relying on forward-looking statements which, by their nature, involve numerous assumptions, risks and uncertainties that may cause such statements not to occur, or results to differ materially from those expressed or implied. These assumptions include: future commodity prices and differentials; foreign exchange rates; ability to access credit facilities and shelf prospectuses; assumptions contained in the Company’s corporate guidance ~~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; receipt, timing and terms of securityholder, stock exchange, regulatory and court approvals required in connection with the Reorganization; director and officer support for the Reorganization; the applicability of certain U.S. and Canadian securities

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

Risks and uncertainties that may affect these business outcomes include: ability to generate sufficient cash flow to meet obligations; commodity price volatility; ability to secure adequate transportation and potential pipeline curtailments; variability and discretion of Encana’s board of directors (the “Board of Directors”) to declare and pay dividends, if any; timing and costs of well, facilities and pipeline construction; business interruption, property and casualty losses or unexpected technical difficulties, including impact of weather; the Company's ability to achieve the anticipated benefits of the Reorganization; receipt of securityholder, stock exchange, regulatory and court approvals required in connection with the Reorganization and satisfaction of other conditions; risks relating to the new company following the Reorganization, including triggering provisions in certain agreements; publicity resulting from the Reorganization and impacts to the Company’s business and share price; counterparty and credit risk; impact of a downgrade in credit rating and its impact on access to sources of liquidity; fluctuations in currency and interest rates; risks inherent in the Company’s corporate guidance; failure to achieve cost and efficiency initiatives; risks inherent in marketing operations; risks associated with technology; changes in or interpretation of royalty, tax, environmental, greenhouse gas, carbon, accounting and other laws or regulations; risks associated with existing and potential lawsuits and regulatory actions made against the Company; impact of disputes arising with its partners, including suspension of certain obligations and inability to dispose of assets or interests in certain arrangements; the Company’s ability to acquire or find additional reserves; imprecision of reserves estimates and estimates of recoverable quantities, including future net revenue estimates; risks associated with past and future acquisitions or divestitures of certain assets or other transactions or receipt of amounts contemplated under the transaction agreements (such transactions may include third-party capital investments, farm-outs or partnerships, which Encana may refer to from time to time as “partnerships” or “joint ventures” and the funds received in respect thereof which Encana may refer to from time to time as “proceeds”, “deferred purchase price” and/or “carry capital”, regardless of the legal form) as a result of various conditions not being met; and other risks described herein and in Item 1A. Risk Factors of the Annual Report on Form 10-K for the fiscal year ended December 31, ~~2017~~2018 (“~~2017~~2018 Annual Report on Form 10-K”) and risks and uncertainties impacting Encana's business as described from time to time in the Company's other periodic filings with the SEC.

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

The reader should read carefully the risk factors described herein and in Item 1A. Risk Factors of the ~~2017~~2018 Annual Report on Form 10-K for a description of certain risks that could, among other things, cause actual results to differ from these forward-looking statements.

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

Condensed Consolidated ~~Stateme~~ntStatement of Changes in Shareholders’ Equity (unaudited)

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,~~2018, which are included in Item 8 of Encana’s ~~2017~~2018 Annual Report on Form 10-K.

The interim Condensed Consolidated Financial Statements have been prepared following the same accounting policies and methods of computation as the annual audited Consolidated Financial Statements for the year ended December 31, ~~2017,~~2018, except as noted below in Note 2. The disclosures provided below are incremental to those included with the annual audited Consolidated Financial Statements.

These unaudited interim Condensed Consolidated Financial Statements reflect, in the opinion of Management, all normal and recurring adjustments ~~with the exception of an out-of-period adjustment for the nine months ended September 30, 2017 as described in Note 6, which are~~ 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.

On January 1, ~~2018,~~2019, 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:~~

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

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~~As of ~~Operations (For~~February 14, 2019, Encana’s segmented results reflect the ~~three months ended September 30)~~business combination as discussed in Note 8.

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

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 no0 contract asset or liability balances during the periods presented. As at September 30, ~~2018,~~2019, receivables and accrued revenues from contracts with customers were ~~$764~~$980 million ($~~676~~662 million as at December 31, ~~2017)~~2018).

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

The Company’s gathering and processing services are provided on an interruptible basis with transaction prices that are for fixed prices and/or variable consideration. Variable consideration received is related to recovery of plant operating costs or escalation of the fixed price based on a consumer price index. As the service contracts are interruptible, with service provided on an “as available” basis, there are 0 unsatisfied performance obligations remaining at September 30, 2019.

As at September 30, ~~2018,~~2019, all remaining performance obligations are priced at market index prices or are variable volume delivery contracts. As such, the variable consideration is allocated entirely to the wholly unsatisfied performance obligation or promise to deliver units of production, and revenue is recognized at the amount for which the Company has the right to invoice the product delivered.

~~Performance obligations arising from arrangements to gather and process natural gas on behalf of third parties are typically satisfied over time as~~ As the ~~service is provided to the customer. Payment from the customer is due~~period between when the product sales are transferred and Encana receives payments is generally 30 to 60 days, there is no financing element associated with customer ~~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~~contracts. In addition, Encana does not disclose unsatisfied performance obligations for customer contracts with ~~transaction prices that are for fixed prices and/or variable~~terms less than 12 months.

consideration. Variable consideration received is related to recovery of plant operating costs or escalation of the fixed price based on a consumer price index. As the service contracts are interruptible, with service provided on an “as available” basis, there are no unsatisfied performance obligations remaining at September 30, 2018.

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

The unrealized foreign exchange (gain) loss on translation of U.S. dollar financing debt issued from Canada for the nine months ended September 30, 2017 disclosed in the table above included an out-of-period adjustment in respect of unrealized losses on a foreign-denominated capital lease obligation since December 2013. The cumulative impact recognized within foreign exchange (gain) loss in the Company’s Condensed Consolidated Statement of Earnings for the nine months ended September 30, 2017 was $68 million, before tax ($47 million, after tax). Encana determined that the adjustment was not material to the Condensed Consolidated Financial Statements for the period ended September 30, 2017 or any prior periods.

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.

On June 28, 2019, Alberta Bill 3, the Job Creation Tax Cut (Alberta Corporate Tax Amendment) Act, was signed into law resulting in a reduction of the Alberta corporate tax rate from 12 percent to 11 percent effective July 1, 2019, with further 1 percent rate reductions to take effect every year on January 1 until the general corporate tax rate is 8 percent on January 1, 2022. During the nine months ended September 30, 2019, the deferred tax expense of $140 million includes an adjustment of $55 million resulting from the re-measurement of the Company’s deferred tax position due to the Alberta tax rate reduction.

During the nine months ended September 30, 2018, the current income tax recovery was primarily due to the resolution of certain tax items relating to prior taxation years. During the three and nine months ended September 30, ~~2017,~~2019, the ~~current income~~deferred tax ~~recovery~~expense was primarily due to net earnings before income tax in the ~~successful resolution~~respective periods and the impact of ~~certain~~the Alberta tax ~~items previously assessed by the taxing authorities relating to prior taxation years.~~rate reduction discussed above. During the three months ended September 30, 2018, the deferred tax expense was primarily due to the changes in the estimated annual effective income tax rate. ~~During~~

The effective tax rate of 37.3 percent for the ~~three~~nine months ended September 30, ~~2017,~~2019 is higher than the ~~deferred~~Canadian statutory tax ~~expense was~~rate of 26.6 percent primarily due to the ~~changes in~~re-measurement of the ~~estimated annual effective income~~Company’s deferred tax position resulting from the Alberta tax rate ~~arising from gains recognized on foreign exchange and divestitures, including allocated goodwill.~~

reduction discussed above, partially offset by partnership tax allocations in excess of funding. The effective tax rate of 343.8 percent for the nine months ended September 30, 2018, iswas higher than the Canadian statutory tax rate of 27 percent primarily due to the ~~current year~~resolution of certain tax items ~~discussed above. The effective tax rate~~relating to prior taxation years.

On February 13, 2019, Encana completed the business combination with Newfield Exploration Company, a Delaware corporation (“Newfield”), pursuant to its Agreement and Plan of ~~17.7 percent~~Merger with Newfield (the “Merger”). As a result of the Merger, Newfield stockholders received 2.6719 Encana common shares for ~~the nine months ended September 30, 2017 is lower than the Canadian statutory rate~~each share of ~~27 percent primarily due~~Newfield common stock that was issued and outstanding immediately prior to the ~~items discussed above.~~

~~During the nine months ended September 30, 2018, there was no change to the provisional tax adjustment recognized in 2017 resulting from the re-measurement~~effective date of the ~~Company’s tax position due to~~Merger. Encana issued approximately 543.4 million common shares representing a ~~reduction~~value of $3.5 billion and paid approximately $5 million in cash in respect of Newfield’s cash-settled incentive awards. Following 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~~acquisition, Newfield’s senior notes totaling $2.45 billion remained outstanding. Transaction costs of approximately $33 million were included in ~~interpretation and assumptions of the U.S. Tax Reform made by the Company.~~

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

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

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

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

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

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

For the nine months ended September 30, ~~2018,~~2019, acquisitions in the Canadian and USA Operations were ~~$17 million (2017~~nil (2018 - ~~$31~~$17 million) and ~~nil (2017~~$66 million (2018 - ~~$19 million)~~nil), respectively, which primarily included seismic purchases, water rights and purchases with oil and liquids rich potential.

In the Canadian Operations, divestitures during the nine months ended September 30, 2018 were $55 million, which primarily included the sale of the Pipestone midstream assets located in Alberta. During the nine months ended September 30, 2017, divestitures in the Canadian Operations were $26 million, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets.

~~In the USA Operations, divestitures during~~For the three and nine months ended September 30, 2019, divestitures in the USA Operations were $171 million and $177 million, respectively, which primarily included the sale of the Company’s Arkoma natural gas assets. For the three and nine months ended September 30, 2018, divestitures in the USA Operations were $26 million and $34 million, respectively, which primarily included the sale of certain properties that did not complement Encana’s existing portfolio of assets. During the three months ended September 30, 2017, divestitures in the USA Operations comprised the sale of the Piceance natural gas assets in northwestern Colorado for proceeds of approximately $605 million, after closing and other adjustments.

During the nine months ended September 30, ~~2017,~~2018, divestitures in the ~~USA~~Canadian Operations were ~~$684~~$55 million, which primarily included the sale of ~~the Piceance natural gas~~certain Pipestone assets ~~and the sale of the Tuscaloosa Marine Shale assets~~located in ~~Mississippi and Louisiana.~~Alberta.

Amounts received from the Company’s divestiture transactions have been deducted from the respective Canadian and U.S. full cost pools, except for divestitures that result in a significant alteration between capitalized costs and proved reserves in a country cost centre. For divestitures that result in a gain or loss and constitute a business, goodwill is allocated to the divestiture. Accordingly, for the three and nine months ended September 30, 2017, Encana recognized a gain of approximately $406 million, before tax, on the sale of the Company’s Piceance assets in the U.S. cost centre and allocated goodwill of $216 million.pools.

Canadian and USA Operations property, plant and equipment include internal costs directly related to exploration, development and construction activities of ~~$159~~ $171million, which have been capitalized during the nine months ended September 30, ~~2018 (2017~~2019 (2018 - ~~$146~~$159 million). ~~Included in Corporate and Other are $58 million ($63 million as at December 31, 2017) of international property costs, which have been fully impaired.~~

The Company has ~~several~~2 lease arrangements that are accounted for as ~~capital~~finance leases, ~~including~~which include an office building and an offshore production platform.

As at September 30, ~~2018,~~2019, the total carrying value of assets under ~~capital~~finance lease was ~~$43~~$39 million ($4641 million as at December 31, ~~2017)~~2018), net of accumulated amortization of ~~$673~~$667 million ($~~684~~650 million as at December 31, ~~2017)~~2018). ~~Liabilities~~Long-term liabilities for the ~~capital~~finance lease arrangements are included in other liabilities and provisions in the Condensed Consolidated Balance Sheet and are disclosed in Note ~~11.~~13.

As at ~~September 30,~~December 31, 2018, Corporate and Other property, plant and equipment and total assets ~~include~~included a carrying value of ~~$1,200~~$1,133 million ~~($1,255 million as at December 31, 2017)~~ related to The Bow office ~~building, which is under a 25-year lease agreement.~~building. Upon adoption of Topic 842 on January 1, 2019, 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~~office building was determined to be ~~derecognized~~an operating lease as ~~disclosed~~discussed in Note ~~11.~~2. As at September 30, 2019, other assets included a ROU asset of $896 million related to The Bow office building.

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

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

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

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

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

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

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

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

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

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

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

As at September 30, ~~2018,~~2019, total long-term debt had a carrying value of $7,024 million and a fair value of $7,825 million (as at December 31, 2018 - carrying value of $4,198 million and a fair value of ~~$4,766 million (as at December 31, 2017 - carrying value of $4,197 million and a fair value of $5,042~~$4,511 million). The estimated fair value of long-term borrowings is categorized within Level 2 of the fair value hierarchy and has been determined based on market information of long-term debt with similar terms and maturity, or by discounting future payments of interest and principal at interest rates expected to be available to the Company at period end.

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

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

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.

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.~~

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. NoNaN Class A Preferred Shares are outstanding.

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

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

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

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

During the nine months ended September 30, ~~2018, Encana issued 40,057~~2019, the Company purchased approximately 149.4 million common shares ~~totaling $0.5~~under its current NCIB for total consideration of approximately $1,037 million. Of the amount paid, $816 million was charged to share capital and $221 million was charged to retained earnings.

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

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

OnFebruary 28, 2019, Encana suspended its dividend reinvestment plan (“DRIP”). During the twelve months ended December 31, ~~2017,~~2018, Encana issued ~~58,480~~69,329 common shares totaling $0.6 million under the DRIP.

During the three months ended September 30, ~~2018,~~2019, Encana declared and paid dividends of $0.01875 per common share totaling $24 million (2018 - $0.015 per common share totaling $14 ~~million (2017 - $0.015 per common share totaling $15~~ million). During the nine months ended September 30, ~~2018,~~2019, Encana declared and paid dividends of $0.05625 per common share totaling $77 million (2018 - $0.045 per common share totaling $43 ~~million (2017 - $0.045 per common share totaling $44~~ million).

For the three and nine months ended September 30, 2018, the dividends paid included $0.1 million and $0.5 million, respectively, in common shares issued in lieu of cash dividends under the ~~DRIP (for the three and nine months ended September 30, 2017 - $0.2 million and $0.5 million, respectively).~~ DRIP.

On October ~~31, 2018,~~30, 2019, the Board of Directors declared a dividend of ~~$0.015~~$0.01875 per common share payable on December 31, ~~2018~~2019 to common shareholders of record as of December ~~14, 2018.~~13, 2019.

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 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.

For the nine months ended September 30, 2018, the Company purchased approximately 20.7 million common shares for total consideration of approximately $250 million. Of the amount paid, $102 million was charged to share capital and $148 million was charged to accumulated deficit.

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

Encana has share-based compensation plans that allow employees to purchase common shares of the Company. Option exercise prices are not less than the market value of the common shares on the date the options are granted. All options outstanding as at September 30, ~~2018~~2019 have associated Tandem Stock Appreciation Rights (“TSARs”) attached. In lieu of exercising the option, the associated TSARs give the option holder the right to receive a cash payment equal to the excess of the market price of Encana’s common shares at the time of the exercise over the original grant price.

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

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

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 September 30, 2018, Encana had a capital lease obligation of $259 million ($314 million as at December 31, 2017) related to the PFC.

Veresen Midstream Limited Partnership (“VMLP”) provides gathering, compression and processing services under various agreements related to the Company’s development of liquids and natural gas production in the Montney play. As at September 30, ~~2018,~~2019, VMLP provides approximately ~~1,240~~1,206 MMcf/d of natural gas gathering and compression and ~~977~~939 MMcf/d of natural gas processing under long-term service agreements with remaining terms ranging from up to 1312 to 2726 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~~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 ~~$2,425~~$2,359 million as at September 30, ~~2018.~~2019. The estimate comprises the take or pay volume commitments and the potential payout of minimum costs. The take or pay volume commitments associated with certain gathering and processing assets are included in Note 2124 under Transportation and Processing. The potential payout requirement is highly uncertain as the amount is contingent on future production estimates, pace of development and the amount of capacity contracted to third parties. As at September 30, ~~2018,~~2019, there were no0 accounts payable and accrued liabilities outstanding related to the take or pay commitment.

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

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

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

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

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

As at September 30, ~~2018,~~2019, the liability for share-based payment transactions totaled ~~$357~~$65 million ($~~327~~165 million as at December 31, ~~2017)~~2018), of which ~~$290~~$36 million ($~~152~~131 million as at December 31, ~~2017)~~2018) is recognized in accounts payable and accrued liabilities and ~~$67~~$29 million ($~~175~~34 million as at December 31, ~~2017)~~2018) is recognized in other liabilities and provisions in the Condensed Consolidated Balance Sheet.

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

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

Of the total benefit plans expense, ~~$17~~$20 million ~~(2017~~(2018 - ~~$18~~$17 million) was included in operating expense and $6 million ~~(2017~~(2018 - $6 million) was included in administrative ~~expense and a gain~~expense. Excluding service costs, net defined periodic benefit costs of ~~nil (2017~~$6 million (2018 - ~~$6 million) was included~~nil) were recorded in other (gains) losses, net.

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

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

Recurring fair value measurements are performed for risk management assets and liabilities and other derivative contracts, as discussed further in Note ~~19.~~22. These items are carried at fair value in the Condensed Consolidated Balance Sheet and are classified within the three levels of the fair value hierarchy in the following tables. There have been no significant transfers between the hierarchy levels during the period.

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

The Company’s Level 1 and Level 2 risk management assets and liabilities consist of commodity fixed price contracts, fixed price swaptions, NYMEX costless collars, NYMEX call options, NYMEX three-way options, foreign currency swaps and basis swaps with terms to ~~2023.~~2025. Level 2 also includes financial guarantee contracts as discussed in Note ~~19.~~22. The fair values of these contracts are based on a market approach and are estimated using inputs which are either directly or indirectly observable ~~at the reporting date,~~from active markets, such as exchange and other published prices, broker quotes and observable trading ~~activity.~~ activity throughout the term of the instruments.

As at September 30, ~~2018,~~2019, the Company’s Level 3 risk management assets and liabilities consist of WTI three-way options and WTI costless collars with terms to ~~2019.~~2020. The WTI three-way options are a combination of a sold call, bought put and a sold put. The WTI costless collars are a combination of a sold call and a bought put. These contracts allow the Company to participate in the upside of commodity prices to the ceiling of the call option and provide the Company with complete (collars) or partial (three-way) downside price protection through the put options. The fair values of the WTI three-way options and WTI costless collars are based on the income approach and are modelled using observable and unobservable inputs such as implied volatility. The unobservable inputs are obtained from third parties whenever possible and reviewed by the Company for reasonableness.

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

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

A 10 percent increase or decrease in implied volatility for the WTI options would cause aan approximate corresponding $7$9 million ($26 million as at December 31, ~~2017)~~2018) increase or decrease to net risk management assets and liabilities.

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

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 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 ~~and Mont Belvieu-based~~ contracts such as fixed price contracts, fixed price swaptions, options and costless collars. Encana has also entered into basis swaps to manage against widening price differentials between various production areas and benchmark price points.

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

Foreign exchange risk arises from changes in foreign currency exchange rates that may affect the fair value or future cash flows of the Company’s financial assets or liabilities. To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts. As at September 30, ~~2018,~~2019, Encana has entered into ~~$179~~$250 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$~~0.7606~~0.7516 to C$1, which mature monthly through the remainder of ~~2018~~2019 and ~~$350~~$425 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$~~0.7579~~0.7483 to C$1, which mature monthly throughout ~~2019.~~2020.

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

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

Risk management assets and liabilities arise from the use of derivative financial instruments and are measured at fair value. See Note 1821 for a discussion of fair value measurements.

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~~NYSE and the TSX, over-the-counter traded contracts expose Encana to counterparty credit risk. This credit risk exposure is mitigated through the use of credit policies approved by the Board of Directors governing the Company’s credit portfolio including credit practices that limit transactions according to counterparties’ credit quality. Mitigation strategies may include master netting arrangements, requesting collateral and/or transacting credit derivatives. The Company executes commodity derivative financial instruments under master agreements that have netting provisions that provide for offsetting payables against receivables. As a result of netting provisions, the Company’s maximum exposure to loss under derivative financial instruments due to credit risk is limited to the net amounts due from the counterparties under the derivative contracts, as disclosed in Note ~~18.~~21. As at September 30, ~~2018,~~2019, the Company had no0 significant credit derivatives in place and held no0 collateral.

As at September 30, ~~2018,~~2019, cash equivalents include high-grade, short-term securities, placed primarily with financial institutions and companies with strong investment grade ratings. Any foreign currency agreements entered into are with major financial institutions that have investment grade credit ratings.

A substantial portion of the Company’s accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risks. As at September 30, ~~2018,~~2019, approximately 9296 percent ~~(92~~(97 percent as at December 31, ~~2017)~~2018) of Encana’s accounts receivable and financial derivative credit exposures were with investment grade counterparties.

As at September 30, ~~2018,~~2019, Encana had ~~two~~3 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 September 30, 2018, these~~These counterparties accounted for 6920 percent, 13 percent and 1113 percent of the fair value of the outstanding in-the-money net risk management contracts. As at December 31, ~~2017,~~2018, Encana had ~~three~~4 counterparties whose net settlement position accounted for 5630 percent, 1113 percent, 12 percent and 1110 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~~two to ~~six~~five years with a fair value recognized of ~~$15~~$10 million as at September 30, ~~2018~~2019 ($1914 million as at December 31, ~~2017)~~2018). The

maximum potential amount of undiscounted future payments is ~~$258~~$154 million as at September 30, ~~2018,~~2019, and is considered unlikely.

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

The following table outlines the Company’s commitments as at September 30, ~~2018:~~2019:

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

Included within transportation and processing in the table above are certain commitments associated with midstream service agreements with VMLP as described in Note ~~15.~~17. Divestiture transactions can reduce certain commitments disclosed above.

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~~unfavorable outcome is reasonably possible, the Company discloses the nature and a range of potential exposures. If an ~~unfavourable~~unfavorable outcome were to occur, there exists the possibility of a material impact on the Company’s consolidated net earnings or loss for the period in which the effect becomes reasonably estimable. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. Such accruals are based on the Company’s information known about the matters, estimates of the outcomes of such matters and experience in handling similar matters.

~~Agreement to Acquire~~In conjunction with the acquisition of Newfield ~~Exploration Company~~

as described in Note 8, various legal claims and actions arising in the normal course of Newfield’s operations were assumed by Encana. On ~~November 1, 2018, Encana announced that it has~~March 29, 2019, Newfield and its wholly-owned subsidiary entered into ~~a definitive merger agreement~~an Agreement and Mutual Release with Sapura Energy Berhad, formerly known as SapuraKencana Petroleum Berhad, and Sapura Exploration and Production Inc., formerly known as SapuraKencana Energy Inc. (collectively, “Sapura”) to ~~acquire all~~settle arbitration claims arising from Sapura’s purchase of Newfield’s Malaysian business in February 2014. Under the Agreement and Mutual Release, Newfield and its wholly-owned subsidiary paid Sapura $22.5 million. The settlement amount including legal fees was included in the purchase price allocation as part of the ~~issued~~current liabilities assumed by Encana at the acquisition date. Although the outcome of any remaining legal claims and ~~outstanding shares of common stock~~actions assumed by Encana following the acquisition of Newfield ~~Exploration~~cannot be predicted with certainty, the Company ~~(“Newfield”) in an all-stock transaction. Under the terms~~does not expect these matters to have a material adverse effect on Encana’s financial position, cash flows or results of the merger agreement, Newfield shareholders will receive 2.6719 common shares of Encana for each share of Newfield common stock. The transaction has been unanimously approved by the Board of Directors of both Encana and Newfield and is subject to the terms and conditions set forth in the merger agreement. The transaction is expected to close in the first quarter of 2019.

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

The MD&A is intended to provide a narrative description of Encana’s business from management’s perspective. This MD&A should be read in conjunction with the unaudited interim Condensed Consolidated Financial Statements and accompanying notes for the period ended September 30, ~~2018~~2019 (“Consolidated Financial Statements”), which are included in Part I, Item 1 of this Quarterly Report on Form 10-Q and the audited Consolidated Financial Statements and accompanying notes and MD&A for the year ended December 31, ~~2017,~~2018, which are included in Items 8 and 7, respectively, of the ~~2017~~2018 Annual Report on Form ~~10-K.~~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:

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~~combination of profitable growth and generating ~~profitable growth.~~cash flows in excess of capital expenditures. The Company is pursuing the key business objectives of ~~exercising~~preserving balance sheet strength, maximizing profitability through operational and capital efficiencies, returning capital to shareholders through sustainable dividends, and driving cash flow through a disciplined capital allocation strategy by investing in a limited number of core assets ~~growing~~with high margin ~~liquids volumes, maximizing profitability through operating efficiencies and reducing costs, and preserving balance sheet strength.~~liquids.

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

Encana continually reviews and evaluates its strategy and changing market conditions. In ~~2018,~~2019, Encana ~~continues to focus~~is focusing on quality cash flow growth from high margin, scalable, ~~projects~~top tier assets located in some of the best plays in North America, referred to as the “Core Assets”~~, comprising Montney~~. As at September 30, 2019, these comprised Permian and ~~Duvernay in Canada and Eagle Ford and Permian~~Anadarko in the U.S., and Montney in Canada. These ~~world-class~~top tier assets form a multi-basin portfolio of oil, NGLs and natural gas producing plays enabling flexible and efficient investment of ~~capital.~~capital into high margin liquids plays that support sustainable cash flow generation. The ~~Company rapidly deploys successful ideas~~Company’s other upstream assets, including Eagle Ford, Duvernay, Williston and ~~practices across these assets, becoming more efficient as innovative and sustainable technical improvements are implemented.~~Uinta continue to deliver operating cash flows for the Company.

For additional information on Encana’s strategy, its reporting segments and the plays in which the Company operates as at December 31, 2018, refer to Items 1 and 2 of the ~~2017~~2018 Annual Report on Form 10-K. On February 13, 2019, Encana completed the acquisition of Newfield; as such, the post-acquisition results of operations of Newfield are included in the Company’s interim consolidated results beginning February 14, 2019. For additional information on the business combination and segmented results, refer to Notes 8 and 3, respectively, to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. For additional information on the reserves volumes acquired with the Newfield acquisition, refer to Exhibit 99.4 in the Company’s Current Report on Form 8-K filed on February 28, 2019 regarding Supplemental Pro Forma Oil, Natural Gas Liquids and Natural Gas Reserves Information as of December 31, 2018.

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

During the first nine months of ~~2018,~~2019, Encana focused on executing its ~~2018~~2019 capital plan, ~~maintaining operational efficiencies achieved~~generating cash from operating activities and returning capital to shareholders through dividends and share buybacks. Since the completion of the Newfield acquisition in ~~2017~~February, the Company has fully integrated the businesses and ~~minimizing~~is on track to exceed the ~~effect of inflationary costs.~~synergies previously announced from the strategic combination. Higher upstream product revenues in the first nine months of ~~2018~~2019 compared to ~~2017 resulting~~2018 resulted from higher ~~liquids benchmark prices and~~ production ~~volumes. Higher oil and NGL benchmark prices contributed to increases in Encana’s~~volumes, partially offset by lower average realized ~~oil and NGL~~ prices, excluding the impact of ~~40 percent and 35 percent, respectively. Liquids~~risk management activities. Total production volumes increased by 3260 percent compared to ~~2017.~~2018 primarily due to the Newfield acquisition and successful drilling programs. Decreases in average realized liquids and natural gas prices of 23 percent and nine percent, respectively, were primarily due to lower benchmark prices. Encana ~~is also focused~~continues to focus on optimizing realized prices from 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.~~markets.

~~Generated cash from operating activities of $1,741 million, Non-GAAP Cash Flow of $1,575 million and Non-GAAP Cash Flow Margin of $16.63 per BOE, including the tax items noted above.~~

On ~~November 1, 2018,~~October 31, 2019, the Company announced its intention to complete a corporate reorganization (the “Reorganization”) which includes (i) a proposed plan of arrangement under the Canada Business Corporations Act involving, among others, Encana, ~~announced that it has entered into~~Encana securityholders and a ~~definitive merger agreement~~wholly-owned subsidiary of Encana to be named Ovintiv Inc. (“Ovintiv”), pursuant to which, among other things, Encana will complete a share consolidation on the basis of one post-consolidation share for each five pre-consolidation shares and Ovintiv will ultimately acquire all of the issued and outstanding Encana common shares in exchange for shares of ~~common stock~~Ovintiv on a one-for-one basis and become the parent company of ~~Newfield Exploration Company (“Newfield”) in an all-stock transaction. Under~~Encana and its subsidiaries (collectively, the ~~terms~~“Arrangement”), and (ii) as soon as practicable following the Arrangement, Ovintiv migrating out of Canada and becoming a Delaware corporation. Following completion of the ~~merger agreement, Newfield shareholders~~Reorganization, Ovintiv and its subsidiaries will ~~receive 2.6719 common shares of Encana for each share of Newfield common stock. The transaction has been unanimously approved~~continue to carry on the business currently conducted by ~~the Board of Directors of both~~ Encana and ~~Newfield~~its subsidiaries. Subject to receipt of securityholder, stock exchange and ~~is subject to~~court approvals, as well as the ~~terms and~~satisfaction of other conditions ~~set forth in~~precedent, the ~~merger agreement. The transaction~~Reorganization is expected to ~~close~~be completed in ~~the first quarter of 2019.~~2020.

On October 1, 2018, Encana announced an agreement to sell its San Juan assets, comprising approximately 182,000 net acres in New Mexico, to DJR Energy, LLC for total consideration of approximately $480 million. The transaction is expected to close in the fourth quarter of 2018, with an effective date of April 1, 2018, and is subject to the satisfaction of normal closing conditions and customary closing adjustments.2019 Outlook

The oil and gas industry is cyclical and commodity prices are inherently volatile. Oil prices ~~for the remainder of 2018~~during 2019 are expected to reflect global supply and demand dynamics as well as the geopolitical and macroeconomic environment. ~~The original OPEC agreement implemented~~At a meeting in 2017 to limit output and the drawdowns of oil storage inventory levels were generally supportive of oil prices in the first half of 2018. Trade disputes and oil supply outages in recent months resulting from geopolitical instability in major producing countries has created additional uncertainty for oil and gas supply which could impact prices for the remainder of the year. As well, prices could be impacted as a result of decisions made byDecember 2018, OPEC and certain non-OPEC countries (collectively “OPEC”) agreed to ~~increase future~~reduce crude oil ~~production.~~production, beginning in January 2019 for an initial period of six months, seeking to balance the global oil market in response to changing fundamentals. In July 2019, OPEC agreed to extend production cuts for an additional period of nine months from July 2019 to March 2020. Risks to the global economy, including trade disputes, U.S. sanctions policy, U.S. production growth, and ~~certain non-OPEC~~potential oil supply outages in major producing countries ~~are expected~~resulting from geopolitical instability, could further contribute to price volatility in 2019. OPEC is scheduled to meet again in December ~~2018~~2019 to review production levels ~~and decide on a framework for permanent cooperation with allied producers to seek a balanced and sustainable global oil market. The~~which could potentially result ~~of this meeting could further~~in other supply adjustments and contribute to price ~~fluctuations in 2019.~~fluctuations.

Natural gas prices in ~~2018~~2019 will be affected by the timing of supply and demand growth and the effects of seasonal weather. Natural gas prices in western Canada have seen significant negative price pressure as strong supply ~~reached multi-year highs, surpassing~~continues to surpass regional demand and ~~stressing~~stress effective pipeline capacity. ~~Relatively strong condensate prices may also lend support~~Despite initial price strength related to ~~activity levels resulting~~lower than normal storage in 2019, mild summer weather and continued ~~downward pressure on natural gas prices for the remainder of 2018. Potential for improvement in U.S. natural gas prices remains limited due to continued substantial~~ production increases in ~~Northeast~~both the northeast U.S. and associated gas production in the Permian ~~Basin.~~Basin are putting downward pressure on U.S. natural gas prices. As a result, potential for improvement in longer-term U.S. natural gas prices remains limited.

Encana is well positioned ~~to be flexible~~ in the current price environment to balance moderate liquids growth with the generation of cash flows in ~~order to continue to achieve strong returns.~~excess of capital expenditures. The Company enters into derivative financial instruments which mitigate price volatility and help sustain revenues during periods of lower prices. A portion of the Company’s production is sold at prevailing market prices which also allows Encana to participate in potential price increases. As at September 30, ~~2018,~~2019, the Company has hedged approximately ~~137~~175.5 Mbbls/d of expected crude oil and condensate production and ~~1,017~~864 MMcf/d of expected natural gas production for the remainder of the year. Additional information on Encana’s hedging program can be found in Note 1922 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Markets for crude oil and natural gas are exposed to different price risks. While the market price for crude oil tends to move in the same direction as the global market, ~~the Permian Basin is experiencing wider~~regional differentials ~~due to temporary local export capacity constraints.~~may develop. Natural gas prices may vary between geographic regions depending on local supply and demand conditions. Encana proactively utilizes transportation contracts to diversify the Company’s downstream markets, ~~and reduce~~reducing significant exposure to any given market. Through a combination of derivative financial instruments and transportation capacity, Encana has mitigated the majority of its exposure to Midland and AECO pricing in ~~2018 and~~ 2019. In addition, Encana continues to seek new markets to yield higher returns.

The Company released updated Corporate Guidance on November 1, 2018, revising its guidance range downward for transportation and processing expense from $7.40 to $7.75 per BOE to $7.20 to $7.40 per BOE to reflect lower cost structures than anticipated. The Company also updated itsCompany’s full year ~~capital investment~~2019 guidance ~~to approximately $2.0 billion from~~ranges discussed within Capital Investment, Production and Operating Expenses in this Outlook section reflect the previous guidance range of $1.8 to $1.9 billion reflecting higher costs associated with diesel fuel, steel tariffs and delays in sourcing local sand in Eagle Ford. The updated full year capital investment guidance of approximately $2.0 billion includes current year expenditures on the Pipestone liquids hub and the San Juan assets totaling approximately $55 million. The liquids hub divestiture and previously announced sale of the San Juan assets are expected to generate proceeds totaling approximately $515 million.

~~Encana’s updated 2018 Corporate~~Reportable Guidance ~~can be accessed on the Company’s website at~~ ~~www.encana.com~~.

Encana is on track to meet its updated full year 2019 capital investment guidance of ~~approximately $2.0 billion.~~$2.55 billion to $2.65 billion and expects to fund its capital program from 2019 cash generated from operating activities. During the first nine months of ~~2018,~~2019, the Company spent ~~$1.6 billion,~~$2,052 million, of which ~~$718~~$728 million was directed to Permian ~~where the Company has drilled 81~~with 84 net wells drilled, $556 million was directed to Anadarko with 51 net wells drilled since the Newfield acquisition closed on February 13, 2019, and ~~$445~~$270 million was directed to Montney with ~~108~~58 net wells drilled. Capital investment in ~~Permian~~the Core Assets is expected to be optimized by Encana’s cube development approach to maximize returns and recovery. Capital investment ~~in Montney~~for the remainder of 2019 is expected to be primarily allocated to ~~both Cutbank Ridge and Pipestone~~the Core Assets with a focus on ~~growing condensate volumes. The remainder of the capital investment, primarily directed~~maximizing returns from high margin liquids and to ~~Eagle Ford and Duvernay, is expected~~other upstream assets to optimize ~~production and margins.~~operating free cash flows.

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

~~As part of the Company’s long-term growth strategy, Encana has significantly shifted its production mix~~Encana’s shift to a more balanced portfolio ~~in the recent years, thereby reducing~~has reduced the extent of exposure to commodity market volatility ~~of a particular commodity.~~and positioned the Company to generate sustainable future cash flows. During the first nine months of ~~2018,~~2019, average liquids production volumes were ~~159.9~~295.2 Mbbls/d, or 53 percent of total production volumes, and average natural gas production volumes were ~~1,123~~1,562 MMcf/d, or 47 percent of total production volumes. The Company has updated its full year 2019 production volume guidance ranges for liquids to 297.0 Mbbls/d to 301.0 Mbbls/d and for natural gas to 1,560 MMcf/d to 1,575 MMcf/d. ~~The Company expects to deliver substantial liquids growth for the remainder of the year. The Company~~Encana is on track to meet ~~the~~its updated full year ~~2018~~2019 production volume guidance ranges ~~for liquids production volumes~~as the Company executes the remainder 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 by year end as a result of the Company’s growth~~its capital plans for Montney. Encana’s growth plans for Montney are supported by third party processing plants commissioned in 2017 and the second quarter of 2018, as well as the completion of the Pipestone liquids hub at the end of the third quarter.its Core Assets.

~~Efficiency improvements~~For 2019, Encana lowered its guidance range for Total Costs to $12.60 per BOE to $12.90 per BOE and ~~lower service costs are expected~~expects Total Costs for the year to be ~~maintained through the support of the Company’s culture of innovation~~approximately $12.75 per BOE. Total Costs includes production, mineral and ~~its focus on continuous improvement in operational execution. As activity in the industry accelerates, Encana expects to continue pursuing innovative ways to reduce~~other taxes, upstream transportation and processing expense, upstream operating expense and administrative ~~expenses. Operating costs in~~expense. Total Costs excludes the impact of long-term incentive and restructuring costs. In the first nine months of ~~2018 are on track to meet~~2019, Total Costs of $12.66 per BOE were below the full year ~~updated 2018~~2019 guidance ~~ranges. Transportation~~range as integration synergies were realized. Upstream transportation and processing expense was ~~$7.39~~$6.46 per BOE, while upstream operating expense and administrative expense, excluding long-term incentive costs and restructuring costs, were ~~$3.35~~$3.40 per BOE and ~~$1.34~~$1.57 per BOE, respectively.

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

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

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

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

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

	Three months ended September 30,									Nine months ended September 30,								Three months ended September 30,									Nine months ended September 30,
	Production Volumes ⁽¹⁾					Realized Prices ⁽²⁾				Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾				Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾					Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾
	2018		2017		2018			2017		2018		2017		2018		2017		2019		2018			2019		2018		2019		2018			2019			2018

Oil (Mbbls/d, $/bbl)
Canadian Operations		0.3		0.6	$		60.32	$	31.66		0.4		0.5	$	57.83	$	37.25		0.7		0.3		$	58.24	$	60.32		0.5		0.4		$	51.55		$	57.83
USA Operations		95.2		74.6			66.84		45.78		87.3		72.9		65.66		47.07		177.6		95.2			55.26		66.84		159.0		87.3			56.47			65.66
China Operations ⁽³⁾																			0.5		-			60.35		-		2.0		-			66.37			-
Total		95.5		75.2			66.82		45.66		87.7		73.4		65.62		47.01		178.8		95.5			55.29		66.82		161.5		87.7			56.58			65.62

NGLs – Plant Condensate (Mbbls/d, $/bbl)
Canadian Operations		36.3		22.8			64.82		46.41		31.2		20.7		64.61		47.74		45.9		36.3			50.73		64.82		42.9		31.2			51.74			64.61
USA Operations		4.7		5.1			55.23		36.63		3.8		3.1		55.12		38.95		12.6		4.7			41.70		55.23		10.0		3.8			43.93			55.12
Total		41.0		27.9			63.73		44.61		35.0		23.8		63.60		46.59		58.5		41.0			48.78		63.73		52.9		35.0			50.26			63.60

NGLs – Other (Mbbls/d, $/bbl)
Canadian Operations		14.4		4.5			30.25		22.68		12.5		4.7		28.87		21.47		17.0		14.4			5.39		30.25		16.3		12.5			10.66			28.87
USA Operations		27.8		19.9			28.27		18.37		24.7		19.3		24.08		18.11		74.9		27.8			7.48		28.27		64.5		24.7			12.01			24.08
Total		42.2		24.4			28.95		19.16		37.2	��	24.0		25.69		18.77		91.9		42.2			7.09		28.95		80.8		37.2			11.74			25.69

Total NGLs (Mbbls/d, $/bbl)
Canadian Operations		50.7		27.3			54.99		42.52		43.7		25.4		54.41		42.84
USA Operations		32.5		25.0			32.15		22.13		28.5		22.4		28.16		21.01
Total		83.2		52.3			46.07		32.75		72.2		47.8		44.07		32.61

Total Oil & NGLs (Mbbls/d, $/bbl)																																		��
Canadian Operations		51.0		27.9			55.03		42.28		44.1		25.9		54.44		42.74		63.6		51.0			38.65		55.03		59.7		44.1			40.52			54.44
USA Operations		127.7		99.6			58.01		39.83		115.8		95.3		56.45		40.95		265.1		127.7			41.12		58.01		233.5		115.8			43.65			56.45
China Operations ⁽³⁾																			0.5		-			60.35		-		2.0		-			66.37			-
Total		178.7		127.5			57.16		40.37		159.9		121.2		55.90		41.33		329.2		178.7			40.67		57.16		295.2		159.9			43.18			55.90

Natural Gas (MMcf/d, $/Mcf)
Canadian Operations		1,038		736			1.96		1.73		975		802		2.09		2.21		1,038		1,038			1.54		1.96		1,027		975			1.95			2.09
USA Operations		159		203			2.19		2.90		148		306		2.25		3.10		617		159			1.67		2.19		535		148			1.89			2.25
Total		1,197		939			1.99		1.98		1,123		1,108		2.11		2.46		1,655		1,197			1.59		1.99		1,562		1,123			1.93			2.11

Total Production (MBOE/d, $/BOE)
Canadian Operations		224.1		150.4			21.62		16.29		206.5		159.5		21.46		18.06		236.7		224.1			17.12		21.62		230.8		206.5			19.14			21.46
USA Operations		154.1		133.6			50.30		34.13		140.5		146.3		48.90		33.15		367.9		154.1			32.43		50.30		322.8		140.5			34.72			48.90
China Operations ⁽³⁾																			0.5		-			60.35		-		2.0		-			66.37			-
Total		378.2		284.0			33.30		24.67		347.0		305.8		32.57		25.28		605.1		378.2			26.46		33.30		555.6		347.0			28.36			32.57

Production Mix (%)
Oil & Plant Condensate		36		36							35		32						39		36							39		35
NGLs – Other		11		9							11		8						15		11							14		11
Total Oil & NGLs		47		45							46		40						54		47							53		46
Natural Gas		53		55							54		60						46		53							47		54

Core Assets Production
Production Growth
Year Over Year (%) ⁽⁴⁾
Total Oil & NGLs																			84									85
Natural Gas																			38									39
Total Production																			60									60

Core Assets Production ⁽⁵⁾
Oil (Mbbls/d)		93.5		71.9							85.5		69.3						118.2		62.1							106.9		57.4

NGLs – Plant Condensate (Mbbls/d)		40.8		27.4							34.9		23.2						48.6		33.0							44.7		27.3
NGLs – Other (Mbbls/d)		41.1		22.9							36.0		22.3						80.2		32.7							70.5		28.4
Total NGLs (Mbbls/d)		81.9		50.3							70.9		45.5

Total Oil & NGLs (Mbbls/d)		175.4		122.2							156.4		114.8						247.0		127.8							222.1		113.1

Natural Gas (MMcf/d)		1,138		754							1,054		775						1,416		1,028							1,325		948

Total Production (MBOE/d)		364.9		248.0							332.0		244.0						482.8		299.1							442.9		271.0

% of Total Encana Production		96		87							96		80						80		79							80		78

Oil revenues increased ~~$270~~$322 million compared to the third quarter of ~~2017~~2018 primarily due to:

Oil revenues increased ~~$630~~$923 million compared to the first nine months of ~~2017~~2018 primarily due to:

NGL revenues ~~increased $198~~decreased $32 million compared to the third quarter of ~~2017~~2018 primarily due to:

•

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

~~Higher average NGL production volumes of 30.9 Mbbls/d increased revenues by $106 million. Higher volumes were due to successful drilling programs in Montney and Permian (36.1 Mbbls/d),~~ partially offset ~~by natural declines in Duvernay and Eagle Ford (3.6 Mbbls/d).~~by:

•

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

•

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

Nine months ended September 30, ~~2018~~2019 versus September 30, ~~2017~~2018

NGL revenues increased ~~$443~~$116 million compared to the first nine months of ~~2017~~2018 primarily due to:

Higher average realized NGL prices of $11.46 per bbl, or 35 percent, increased revenues by $195 million. The increase reflected higher WTI and Edmonton Condensate benchmark prices which were up 35 percent and 32 percent, respectively, as well as benchmark prices for other NGLs; and

•

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

•

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

~~Higher average NGL production volumes of 24.4 Mbbls/d increased revenues by $248 million. Higher volumes were primarily due to successful drilling programs in Montney and Permian (29.7 Mbbls/d),~~ partially offset by natural declines in Duvernay (2.1 Mbbls/d), increased downtime resulting from scheduled plant maintenance for processing liquids rich volumes in Montney (1.2 Mbbls/d) and asset sales (1.1 Mbbls/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.by:

•

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

•

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

~~Natural Gas~~Sublease Revenues

~~Three months ended September 30,~~

Total Revenues

1,871

1,262

5,161

3,558

Total Operating Expenses⁽¹⁾

1,556

1,143

4,535

3,218

Operating Income (Loss)

315

119

626

340

Total Other (Income) Expenses

123

243

356

Net Earnings (Loss) Before Income Tax

192

383

(16

)

Income Tax Expense (Recovery)

143

(55

)

Net Earnings (Loss)

149

240

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

Revenues

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

Benchmark Prices

	Three months ended September 30,				Nine months ended September 30,
(average for the period)	2019		2018		2019		2018

Oil & NGLs
WTI ($/bbl)	$	56.45	$	69.50	$	57.06	$	66.75
Houston ($/bbl)		61.14		73.51		62.84		70.16
Edmonton Condensate (C$/bbl)		68.70		87.34		70.21		85.30

Natural Gas
NYMEX ($/MMBtu)	$	2.23	$	2.90	$	2.67	$	2.90
AECO (C$/Mcf)		1.04		1.35		1.39		1.41
Dawn (C$/MMBtu)		2.81		3.79		3.26		3.73

Production Volumes and Realized Prices

	Three months ended September 30,									Nine months ended September 30,
	Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾					Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾
	2019		2018			2019		2018		2019		2018			2019			2018

Oil (Mbbls/d, $/bbl)
Canadian Operations		0.7		0.3		$	58.24	$	60.32		0.5		0.4		$	51.55		$	57.83
USA Operations		177.6		95.2			55.26		66.84		159.0		87.3			56.47			65.66
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		178.8		95.5			55.29		66.82		161.5		87.7			56.58			65.62

NGLs – Plant Condensate (Mbbls/d, $/bbl)
Canadian Operations		45.9		36.3			50.73		64.82		42.9		31.2			51.74			64.61
USA Operations		12.6		4.7			41.70		55.23		10.0		3.8			43.93			55.12
Total		58.5		41.0			48.78		63.73		52.9		35.0			50.26			63.60

NGLs – Other (Mbbls/d, $/bbl)
Canadian Operations		17.0		14.4			5.39		30.25		16.3		12.5			10.66			28.87
USA Operations		74.9		27.8			7.48		28.27		64.5		24.7			12.01			24.08
Total		91.9		42.2			7.09		28.95		80.8		37.2			11.74			25.69

Total Oil & NGLs (Mbbls/d, $/bbl)																	��
Canadian Operations		63.6		51.0			38.65		55.03		59.7		44.1			40.52			54.44
USA Operations		265.1		127.7			41.12		58.01		233.5		115.8			43.65			56.45
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		329.2		178.7			40.67		57.16		295.2		159.9			43.18			55.90

Natural Gas (MMcf/d, $/Mcf)
Canadian Operations		1,038		1,038			1.54		1.96		1,027		975			1.95			2.09
USA Operations		617		159			1.67		2.19		535		148			1.89			2.25
Total		1,655		1,197			1.59		1.99		1,562		1,123			1.93			2.11

Total Production (MBOE/d, $/BOE)
Canadian Operations		236.7		224.1			17.12		21.62		230.8		206.5			19.14			21.46
USA Operations		367.9		154.1			32.43		50.30		322.8		140.5			34.72			48.90
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		605.1		378.2			26.46		33.30		555.6		347.0			28.36			32.57

Production Mix (%)
Oil & Plant Condensate		39		36							39		35
NGLs – Other		15		11							14		11
Total Oil & NGLs		54		47							53		46
Natural Gas		46		53							47		54

Production Growth
Year Over Year (%) ⁽⁴⁾
Total Oil & NGLs		84									85
Natural Gas		38									39
Total Production		60									60

Core Assets Production ⁽⁵⁾
Oil (Mbbls/d)		118.2		62.1							106.9		57.4
NGLs – Plant Condensate (Mbbls/d)		48.6		33.0							44.7		27.3
NGLs – Other (Mbbls/d)		80.2		32.7							70.5		28.4
Total Oil & NGLs (Mbbls/d)		247.0		127.8							222.1		113.1
Natural Gas (MMcf/d)		1,416		1,028							1,325		948
Total Production (MBOE/d)		482.8		299.1							442.9		271.0
% of Total Encana Production		80		79							80		78

(1)	Average daily.

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

(3)

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

(4)	Includes production impacts of acquisitions and divestitures.

(5)	Core Assets production presentation aligns with the Company’s 2019 Core Assets, which include Permian, Anadarko and Montney. Core Assets production for 2018 ~~versus September 30, 2017~~has been updated and reflects Permian and Montney.

Upstream Product Revenues

	Three months ended September 30,

($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas ⁽¹⁾			Total

2018 Upstream Product Revenues	$	587		$	241		$	113		$	219		$	1,160
Increase (decrease) due to:
Sales prices		(77	)		(67	)		(86	)		(54	)		(284	)
Production volumes		399			88			33			78			598
2019 Upstream Product Revenues	$	909		$	262		$	60		$	243		$	1,474

	Nine months ended September 30,

($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas ⁽¹⁾			Total

2018 Upstream Product Revenues	$	1,572		$	607		$	261		$	647		$	3,087
Increase (decrease) due to:
Sales prices		(170	)		(165	)		(161	)		(70	)		(566	)
Production volumes		1,093			284			158			247			1,782
2019 Upstream Product Revenues	$	2,495		$	726		$	258		$	824		$	4,303

(1)

Natural gas revenues ~~increased $46 million compared to~~for the third quarter and the first nine months of ~~2017~~2019 exclude certain other revenue and royalty adjustments with no associated production volumes of $2 million and $12 million, respectively (2018 - royalty adjustments of $6 million and $20 million, respectively).

Oil Revenues

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

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

~~Slightly higher~~

•

Higher average ~~realized natural gas prices~~oil production volumes of ~~$0.01 per Mcf, or one percent,~~83.3 Mbbls/d increased revenues by ~~$10~~$399 million. ~~The increase reflected exposure~~Higher volumes were primarily due to ~~other downstream benchmark prices~~the Newfield acquisition (72.7 Mbbls/d) and successful drilling programs in ~~2018 resulting from the diversification of the Company’s markets,~~Anadarko, Williston and Permian (17.7 Mbbls/d), partially offset by natural declines in Eagle Ford (4.6 Mbbls/d); and

•

Lower average realized oil prices of $11.53 per bbl, or 17 percent, decreased revenues by $77 million. The decrease reflected lower ~~NYMEX~~WTI and ~~AECO~~Houston benchmark prices which were down ~~three~~19 percent and 3417 percent, respectively, ~~and lower~~partially offset by strengthening regional pricing relative to the WTI benchmark price in the USA ~~Operations; and~~Operations.

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

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

•

Higher average ~~natural gas~~oil production volumes of ~~258 MMcf/~~73.8 Mbbls/d increased revenues by ~~$36~~$1,093 million. Higher volumes were primarily due to the Newfield acquisition (64.0 Mbbls/d) and successful drilling programs in Anadarko, Permian and Williston (15.5 Mbbls/d), partially offset by the sale of the San Juan assets in the fourth quarter of 2018 (2.2 Mbbls/d) and natural declines in Eagle Ford (2.2 Mbbls/d); and

•

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

NGL Revenues

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

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

•

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

•

partially offset by:

•

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

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

•

Higher average plant condensate production volumes of 17.9 Mbbls/d increased revenues by $284 million. Higher volumes were primarily due to successful drilling programs in Montney and ~~Permian (347 MMcf/~~Anadarko (12.8 Mbbls/d) and ~~decreased downtime~~the Newfield acquisition (4.7 Mbbls/d); and

•

Higher average other NGL production volumes of 43.6 Mbbls/d increased revenues by $158 million. Higher volumes were primarily ~~resulting from scheduled plant maintenance in Montney in 2017 (54 MMcf/d), partially offset by asset sales (121 MMcf/d), which mainly included certain assets in Wheatland in~~due to the ~~fourth quarter of 2017 and the Piceance natural gas assets in the third quarter of 2017, and natural declines in Duvernay (12 MMcf/~~Newfield acquisition (29.8 Mbbls/d) and successful drilling programs in ~~Other Upstream Operations (11 MMcf/~~Anadarko, Montney and Permian (15.5 Mbbls/d) ~~in the third quarter of 2018.~~;

~~Nine months ended September 30, 2018 versus September 30, 2017~~

~~Natural gas revenues decreased $98 million compared to the first nine months of 2017 primarily due to:~~

partially offset by:

•

Lower average realized ~~natural gas~~plant condensate prices of ~~$0.35~~$13.34 per ~~Mcf,~~bbl, or 1421 percent, decreased revenues by ~~$59~~$165 million. The decrease reflected lower ~~NYMEX~~Edmonton Condensate and ~~AECO~~WTI benchmark prices which were down ~~nine~~18 percent and 4515 percent, respectively, as well as fluctuations in regional pricing relative to the Edmonton Condensate and WTI benchmark prices; and

•

Lower average realized other NGL prices of $13.95 per bbl, or 54 percent, decreased revenues by $161 million reflecting lower other NGL benchmark prices and lower regional ~~pricing in USA Operations, partially offset by exposure to other downstream benchmark prices in 2018 resulting from the diversification of the Company’s markets; and~~

•

~~Production volume changes decreased revenues by $39 million resulting from:~~pricing.

Lower production volumes in the USA Operations (158 MMcf/d) decreased revenues by $134 million primarily due to the sale of the Piceance natural gas assets in the third quarter of 2017 (173 MMcf/d), partially offset by a successful drilling program in Permian in 2018 (25 MMcf/d).

Higher production volumes in Canadian Operations (173 MMcf/d) increased revenues by $95 million resulting from a successful drilling program in Montney (242 MMcf/d) and decreased downtime resulting from scheduled plant maintenance in Montney in 2017 (27 MMcf/d), partially offset by asset sales (66 MMcf/d), which mainly include certain assets in Wheatland in the fourth quarter of 2017, and lower volumes in Other Upstream Operations (30 MMcf/d).

~~Gains (Losses) on Risk Management, Net~~

~~commodity price positions as at September 30, 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 tables provide the effects of Encana’s risk management activities on revenues.~~

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Realized Gains (Losses) on Risk Management

Commodity Price ⁽¹⁾

Oil

$
(87
)

$
14

$
(208
)

$
30

NGLs ⁽²⁾

(47
)

4

(105
)

5

Natural Gas

56

21

216

(4
)
Other ⁽³⁾

1

2

2

5

Total

(77
)

41

(95
)

36

Unrealized Gains (Losses) on Risk Management

(164
)

(76
)

(422
)

396

Total Gains (Losses) on Risk Management, Net

$
(241
)

$
(35
)

$
(517
)

$
432

Three months ended September 30,

Nine months ended September 30,

(Per-unit)

2018

2017

2018

2017

Realized Gains (Losses) on Risk Management

Commodity Price ⁽¹⁾

Oil ($/bbl)

$
(9.77
)

$
2.12

$
(8.68
)

$
1.51

NGLs ($/bbl) ⁽²⁾

$
(6.21
)

$
0.58

$
(5.32
)

$
0.33

Natural Gas ($/Mcf)

$
0.51

$
0.25

$
0.70

$
(0.01
)
Total ($/BOE)

$
(2.23
)

$
1.50

$
(1.02
)

$
0.37

~~(1)~~

~~Includes realized gains and losses related to the Canadian and USA Operations.~~

~~(2)~~

~~Includes plant condensate.~~

~~(3)~~

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

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

~~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 September 30,

Nine months ended September 30,

($ millions)
2018

2017

2018

2017

Market Optimization
$
317

$
224

$
909

$
614

~~Three months ended September 30, 2018 versus September 30, 2017~~

~~Market Optimization revenues increased $93 million compared to the third 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 ($137 million), partially offset by lower natural gas benchmark prices ($44 million).

~~Nine months ended September 30, 2018 versus September 30, 2017~~

~~Market Optimization revenues increased $295 million compared to the first nine months 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 ($472 million), partially offset by lower natural gas benchmark prices ($177 million).

Sublease Revenues

~~Sublease revenues primarily~~

Total Revenues

1,871

1,262

5,161

3,558

Total Operating Expenses⁽¹⁾

1,556

1,143

4,535

3,218

Operating Income (Loss)

315

119

626

340

Total Other (Income) Expenses

123

243

356

Net Earnings (Loss) Before Income Tax

192

383

(16

)

Income Tax Expense (Recovery)

143

(55

)

Net Earnings (Loss)

149

240

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

Revenues

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

Benchmark Prices

	Three months ended September 30,				Nine months ended September 30,
(average for the period)	2019		2018		2019		2018

Oil & NGLs
WTI ($/bbl)	$	56.45	$	69.50	$	57.06	$	66.75
Houston ($/bbl)		61.14		73.51		62.84		70.16
Edmonton Condensate (C$/bbl)		68.70		87.34		70.21		85.30

Natural Gas
NYMEX ($/MMBtu)	$	2.23	$	2.90	$	2.67	$	2.90
AECO (C$/Mcf)		1.04		1.35		1.39		1.41
Dawn (C$/MMBtu)		2.81		3.79		3.26		3.73

Production Volumes and Realized Prices

	Three months ended September 30,									Nine months ended September 30,
	Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾					Production Volumes ⁽¹⁾				Realized Prices ⁽²⁾
	2019		2018			2019		2018		2019		2018			2019			2018

Oil (Mbbls/d, $/bbl)
Canadian Operations		0.7		0.3		$	58.24	$	60.32		0.5		0.4		$	51.55		$	57.83
USA Operations		177.6		95.2			55.26		66.84		159.0		87.3			56.47			65.66
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		178.8		95.5			55.29		66.82		161.5		87.7			56.58			65.62

NGLs – Plant Condensate (Mbbls/d, $/bbl)
Canadian Operations		45.9		36.3			50.73		64.82		42.9		31.2			51.74			64.61
USA Operations		12.6		4.7			41.70		55.23		10.0		3.8			43.93			55.12
Total		58.5		41.0			48.78		63.73		52.9		35.0			50.26			63.60

NGLs – Other (Mbbls/d, $/bbl)
Canadian Operations		17.0		14.4			5.39		30.25		16.3		12.5			10.66			28.87
USA Operations		74.9		27.8			7.48		28.27		64.5		24.7			12.01			24.08
Total		91.9		42.2			7.09		28.95		80.8		37.2			11.74			25.69

Total Oil & NGLs (Mbbls/d, $/bbl)																	��
Canadian Operations		63.6		51.0			38.65		55.03		59.7		44.1			40.52			54.44
USA Operations		265.1		127.7			41.12		58.01		233.5		115.8			43.65			56.45
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		329.2		178.7			40.67		57.16		295.2		159.9			43.18			55.90

Natural Gas (MMcf/d, $/Mcf)
Canadian Operations		1,038		1,038			1.54		1.96		1,027		975			1.95			2.09
USA Operations		617		159			1.67		2.19		535		148			1.89			2.25
Total		1,655		1,197			1.59		1.99		1,562		1,123			1.93			2.11

Total Production (MBOE/d, $/BOE)
Canadian Operations		236.7		224.1			17.12		21.62		230.8		206.5			19.14			21.46
USA Operations		367.9		154.1			32.43		50.30		322.8		140.5			34.72			48.90
China Operations ⁽³⁾		0.5		-			60.35		-		2.0		-			66.37			-
Total		605.1		378.2			26.46		33.30		555.6		347.0			28.36			32.57

Production Mix (%)
Oil & Plant Condensate		39		36							39		35
NGLs – Other		15		11							14		11
Total Oil & NGLs		54		47							53		46
Natural Gas		46		53							47		54

Production Growth
Year Over Year (%) ⁽⁴⁾
Total Oil & NGLs		84									85
Natural Gas		38									39
Total Production		60									60

Core Assets Production ⁽⁵⁾
Oil (Mbbls/d)		118.2		62.1							106.9		57.4
NGLs – Plant Condensate (Mbbls/d)		48.6		33.0							44.7		27.3
NGLs – Other (Mbbls/d)		80.2		32.7							70.5		28.4
Total Oil & NGLs (Mbbls/d)		247.0		127.8							222.1		113.1
Natural Gas (MMcf/d)		1,416		1,028							1,325		948
Total Production (MBOE/d)		482.8		299.1							442.9		271.0
% of Total Encana Production		80		79							80		78

(1)	Average daily.

(2)	Average per-unit prices, excluding the ~~sublease~~impact of ~~office space in~~ risk management activities.

(3)

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~~Company acquired its China Operations as ~~a percentage of oil and natural gas production revenues. Property taxes are generally assessed based on the value~~part of the ~~underlying assets.~~Newfield business combination on February 13, 2019. Subsequently, the Company terminated its production sharing contract with CNOOC and exited its China Operations effective July 31, 2019. Production from China Operations is presented for the period from February 14, 2019 through July 31, 2019.

(4)	Includes production impacts of acquisitions and divestitures.

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

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Canadian Operations

$
4

$
6

$
12

$
16

USA Operations

41

21

97

64

Total

$
45

$
27

$
109

$
80

Three months ended September 30,

Nine months ended September 30,

($/BOE)

2018

2017

2018

2017

Canadian Operations

$
0.20

$
0.42

$
0.22

$
0.37

USA Operations

$
2.91

$
1.69

$
2.53

$
1.59

Total

$
1.31

$
1.01

$
1.15

$
0.95

~~Three months ended September 30, 2018 versus September 30, 2017~~48

~~Production, mineral and other taxes increased $18 million compared to~~

Upstream Product Revenues

	Three months ended September 30,

($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas ⁽¹⁾			Total

2018 Upstream Product Revenues	$	587		$	241		$	113		$	219		$	1,160
Increase (decrease) due to:
Sales prices		(77	)		(67	)		(86	)		(54	)		(284	)
Production volumes		399			88			33			78			598
2019 Upstream Product Revenues	$	909		$	262		$	60		$	243		$	1,474

	Nine months ended September 30,

($ millions)	Oil			NGLs - Plant Condensate			NGLs - Other			Natural Gas ⁽¹⁾			Total

2018 Upstream Product Revenues	$	1,572		$	607		$	261		$	647		$	3,087
Increase (decrease) due to:
Sales prices		(170	)		(165	)		(161	)		(70	)		(566	)
Production volumes		1,093			284			158			247			1,782
2019 Upstream Product Revenues	$	2,495		$	726		$	258		$	824		$	4,303

(1)	Natural gas revenues for the third quarter and the first nine months of ~~2017~~2019 exclude certain other revenue and royalty adjustments with no associated production volumes of $2 million and $12 million, respectively (2018 - royalty adjustments of $6 million and $20 million, respectively).

Oil Revenues

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

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

•

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

•

Lower average realized oil prices of $11.53 per bbl, or 17 percent, decreased revenues by $77 million. The decrease reflected lower WTI and ~~higher production volumes in Permian ($~~Houston benchmark prices which were down 19 ~~million)~~percent and ~~lower production taxes in 2017 from tax recoveries~~17 percent, respectively, partially offset by strengthening regional pricing relative to the WTI benchmark price in the USA ~~Operations ($4 million);~~Operations.

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

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

•

Higher average oil production volumes of 73.8 Mbbls/d increased revenues by $1,093 million. Higher volumes were primarily due to the Newfield acquisition (64.0 Mbbls/d) and successful drilling programs in Anadarko, Permian and Williston (15.5 Mbbls/d), partially offset by:

~~Asset sales ($3 million), which mainly include certain~~ the sale of the San Juan assets ~~in Wheatland~~ in the fourth quarter of ~~2017~~2018 (2.2 Mbbls/d) and natural declines in Eagle Ford (2.2 Mbbls/d); and

•

NGL Revenues

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

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

•

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

•

partially offset by:

•

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

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

•

partially offset by:

•

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

Natural Gas Revenues

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

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

•

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

•

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

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

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

•

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

•

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

Gains (Losses) on Risk Management, Net

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

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

	Three months ended September 30,						Nine months ended September 30,
($ millions)	2019			2018			2019			2018

Realized Gains (Losses) on Risk Management
Commodity Price ⁽¹⁾
Oil	$	10		$	(87	)	$	56		$	(208	)
NGLs - Plant Condensate		9			(40	)		24			(98	)
NGLs - Other		28			(7	)		61			(7	)
Natural Gas		73			56			156			216
Other ⁽²⁾		2			1			4			2
Total		122			(77	)		301			(95	)

Unrealized Gains (Losses) on Risk Management		(41	)		(164	)		(385	)		(422	)
Total Gains (Losses) on Risk Management, Net	$	81		$	(241	)	$	(84	)	$	(517	)

	Three months ended September 30,						Nine months ended September 30,
(Per-unit)	2019			2018			2019			2018

Realized Gains (Losses) on Risk Management
Commodity Price ⁽¹⁾
Oil ($/bbl)	$	0.63		$	(9.77	)	$	1.27		$	(8.68	)
NGLs - Plant Condensate ($/bbl)	$	1.77		$	(10.84	)	$	1.66		$	(10.31	)
NGLs - Other ($/bbl)	$	3.28		$	(1.72	)	$	2.76		$	(0.63	)
Natural Gas ($/Mcf)	$	0.48		$	0.51		$	0.37		$	0.70
Total ($/BOE)	$	2.17		$	(2.23	)	$	1.96		$	(1.02	)

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

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

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

Market Optimization Revenues

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

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018

Market Optimization	$	294	$	317	$	870	$	909

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

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

•

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

partially offset by:

•

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

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

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

•

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

partially offset by:

•

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

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

Price optimization activities and additional third-party purchases to meet sales commitments in the USA Operations in the third quarter of ~~2017 and lower natural gas prices ($2 million).~~2019.

Sublease Revenues

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

~~Nine~~

Operating Expenses

Production, Mineral and Other Taxes

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

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018

Canadian Operations	$	3	$	4	$	11	$	12
USA Operations		63		41		176		97
Total	$	66	$	45	$	187	$	109

	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018

Canadian Operations	$	0.15	$	0.20	$	0.18	$	0.22
USA Operations	$	1.85	$	2.91	$	1.99	$	2.53
Total	$	1.18	$	1.31	$	1.23	$	1.15

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

Production, mineral and other taxes increased $21million compared to the third quarter of 2018 ~~versus September 30, 2017~~

~~Production, mineral and other taxes increased $29 million compared to the first nine months of 2017~~ primarily due to:

•

Higher ~~liquids prices in Permian and Eagle Ford and higher~~ production volumes ~~in Permian~~as a result of the Newfield acquisition ($3631 million);

partially offset by:

•

Lower production tax mainly as a result of lower commodity prices ($7 million) and ~~lower production taxes in 2017 from tax recoveries in~~ the ~~USA Operations ($6 million);~~

~~partially offset by~~:

~~Asset sales ($14 million), which mainly include certain~~sale of the San Juan assets ~~in Wheatland~~ in the fourth quarter of ~~2017~~2018 ($2 million).

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

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

•

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

partially offset by:

•

Lower production tax mainly as a result of lower commodity prices ($21 million) and the ~~Piceance natural gas~~sale of the San Juan assets in the ~~third~~fourth quarter of ~~2017.~~2018 ($5 million).

~~Transportation and Processing~~

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

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Canadian Operations

$
211

$
138

$
608

$
403

USA Operations

34

31

92

141

Upstream Transportation and Processing

245

169

700

544

Market Optimization

33

30

99

73

Total

$
278

$
199

$
799

$
617

Three months ended September 30,

Nine months ended September 30,

($/BOE)

2018

2017

2018

2017

Canadian Operations

$
10.26

$
10.00

$
10.78

$
9.26

USA Operations

$
2.38

$
2.55

$
2.39

$
3.53

Upstream Transportation and Processing

$
7.05

$
6.50

$
7.39

$
6.52

Transportation and Processing

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018

Canadian Operations	$	211	$	211	$	640	$	608
USA Operations		125		34		340		92
Upstream Transportation and Processing		336		245		980		700

Market Optimization		62		33		168		99
Total	$	398	$	278	$	1,148	$	799

	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018

Canadian Operations	$	9.68	$	10.26	$	10.15	$	10.78
USA Operations	$	3.72	$	2.38	$	3.86	$	2.39
Upstream Transportation and Processing	$	6.05	$	7.05	$	6.46	$	7.39

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

Transportation and processing expense increased $120 million compared to the third quarter of 2018 ~~versus September 30, 2017~~

~~Transportation and processing expense increased $79 million compared to the third quarter of 2017~~ primarily due to:

•

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

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

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

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

•

Higher production volumes as a result of the Newfield acquisition and successful drilling in Anadarko ($251 million), growth in Montney and Permian ($5185 million), ~~higher downstream processing~~rate escalation in certain transportation contracts relating to previously divested assets and incremental transportation costs ~~due to~~associated with third-party purchased volumes ($64 million), and higher ~~volumes primarily in Montney and Permian and~~ costs relating to the diversification of the Company’s downstream markets ($488 million);

partially offset by:

~~Asset sales ($11 million), which mainly include the Piceance natural gas assets in the third quarter of 2017and certain assets in Wheatland in the fourth quarter of 2017 and the lower~~

•

Lower U.S./Canadian dollar exchange rate ($618 million).

~~Nine months ended September 30,~~, lower commodity prices ($16 million) and lower activity in Deep Panuke where the Company ceased production in the second quarter of 2018 ~~versus September 30, 2017~~($11 million).

~~Transportation and processing expense increased $182 million~~

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

Operating

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

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019			2018

Canadian Operations	$	32	$	34	$	96		$	98
USA Operations		151		80		414			238
China Operations ⁽¹⁾		4		-		16			-
Upstream Operating Expense		187		114		526			336

Market Optimization		6		8		21			25
Corporate & Other		-		2		(2	)		11
Total	$	193	$	124	$	545		$	372

	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019			2018

Canadian Operations	$	1.45	$	1.61	$	1.51		$	1.70
USA Operations	$	4.48	$	5.56	$	4.70		$	6.16
China Operations ⁽¹⁾	$	66.11	$	-	$	27.53		$	-
Upstream Operating Expense ⁽²⁾	$	3.35	$	3.22	$	3.46		$	3.51

(1)

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

(2)	Upstream Operating Expense per BOE for the third quarter and first nine months of ~~2017~~2019 includes long-term incentive costs of $0.01/BOE and $0.06/BOE, respectively (2018 - $0.15/BOE and $0.16/BOE, respectively).

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

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

~~Higher volumes~~

•

The Newfield acquisition and ~~gathering and processing fees~~growth in ~~Montney and~~Anadarko, as well as higher activity in Permian ($~~125~~79 million), higher downstream processing and transportation costs due to higher volumes primarily in Montney and Permian and costs relating to the diversification of the Company’s downstream markets ($139 million) and the higher U.S./Canadian dollar exchange rate ($6 million);

partially offset by:

Asset sales ($71 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 lower volumes in Other Upstream Operations ($16 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.

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Canadian Operations

$
34

$
36

$
98

$
89

USA Operations

80

81

238

252

Upstream Operating Expense

114

117

336

341

Market Optimization

8

11

25

23

Corporate & Other

2

4

11

13

Total

$
124

$
132

$
372

$
377

Three months ended September 30,

Nine months ended September 30,

($/BOE)

2018

2017

2018

2017

Canadian Operations

$
1.61

$
2.50

$
1.70

$
1.97

USA Operations

$
5.56

$
6.57

$
6.16

$
6.17

Upstream Operating Expense ⁽¹⁾

$
3.22

$
4.41

$
3.51

$
3.98

~~(1)~~

Upstream Operating Expense per BOE for the third quarter and first nine months of 2018 includes long-term incentive costs of $0.15/BOE and $0.16/BOE, respectively (2017 - $0.45/BOE and $0.13/BOE, respectively).

~~Three months ended September 30, 2018 versus September 30, 2017~~

~~Operating expense decreased $8 million compared to the third quarter of 2017 primarily due to:~~

Lower long-term incentive costs ~~in 2018~~ resulting from ~~the smaller change~~a decrease in Encana’s share price in the third quarter of ~~2018 compared to 2017 ($10 million) and asset sales~~2019 ($8 million), ~~which mainly include~~ lower activity in Eagle Ford ($5 million) and the ~~Piceance natural gas~~sale of the San Juan assets ~~in the third quarter of 2017 and certain assets in Wheatland~~ in the fourth quarter of ~~2017;~~2018 ($3 million).

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

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

•

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

partially offset by:

~~Higher activity in Montney and Permian ($13 million).~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~•

~~Operating expense decreased $5 million compared to the first nine months of 2017 primarily due to:~~

~~Asset sales ($43 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;~~

~~partially offset by:~~

~~Higher activity in Montney and Permian ($35 million) and higher~~Lower long-term incentive costs resulting from ~~the increase~~a decrease in Encana’s share price in the first nine months of ~~2018~~2019 ($612 million).

~~Further information on Encana’s long-term incentives can be found~~, lower activity in ~~Note 16 to~~Eagle Ford ($11 million), the sale of the ~~Consolidated Financial Statements included~~ San Juan assets in ~~Part I, Item 1 of this Quarterly Report on Form 10-Q.~~

~~Purchased Product~~

Three months ended September 30,

Nine months ended September 30,

($ millions)
2018

2017

2018

2017

Market Optimization
$
282

$
202

$
803

$
565

~~Three months ended September 30, 2018 versus September 30, 2017~~

~~Purchased product expense increased $80 million compared to~~ the ~~third~~fourth quarter of ~~2017 primarily due to:~~

~~Higher third-party volumes purchased, primarily related to natural gas, for optimization activities~~2018 ($7 million) and ~~long-term marketing arrangements associated with the Company’s previous divestitures ($131 million), partially offset by~~ lower ~~natural gas benchmark prices ($51 million).~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~

~~Purchased product expense increased $238 million compared to the first nine months of 2017 primarily due to:~~

~~Higher third-party volumes purchased, primarily related to natural gas, for optimization activities~~salaries and ~~long-term marketing arrangements associated with the Company’s previous divestitures ($444 million), partially offset by lower natural gas benchmark prices ($206 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.

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Canadian Operations

$
95

$
53

$
257

$
170

USA Operations

241

139

628

368

Upstream DD&A

336

192

885

538

Market Optimization

-

1

1

1

Corporate & Other

13

17

38

51

Total

$
349

$
210

$
924

$
590

Three months ended September 30,

Nine months ended September 30,

($/BOE)

2018

2017

2018

2017

Canadian Operations

$
4.57

$
3.84

$
4.55

$
3.89

USA Operations

$
17.05

$
11.31

$
16.39

$
9.22

Upstream DD&A

$
9.65

$
7.35

$
9.34

$
6.44

~~Three months ended September 30, 2018 versus September 30, 2017~~

~~DD&A increased $139 million compared to the third quarter of 2017 primarily due to:~~

~~Higher depletion rates in the USA and Canadian Operations ($79 million and $23 million, respectively) and higher volumes in the USA and Canadian Operations ($24 million and $22 million, respectively).~~

~~The depletion rates in the Canadian and USA Operations increased $0.73 per BOE and $5.74 per BOE, respectively, compared to the third quarter of 2017 primarily due to:~~

~~Higher capital spending resulting from an increased capital program in 2018 and transfers of unproved property costs of previously acquired assets which have been evaluated for proved reserves.~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~

~~DD&A increased $334 million compared to the first nine months of 2017 primarily due to:~~

~~Higher depletion rates in the USA and Canadian Operations ($265 million and $42 million, respectively) and higher volumes~~benefits in the Canadian Operations ($425 million).

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

~~The depletion rates~~

Purchased Product

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

	Three months ended September 30,					Nine months ended September 30,
($ millions)		2019		2018		2019		2018

Market Optimization		$	264	$	282	$	784	$	803

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

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

•

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

partially offset by:

•

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

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

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

•

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

partially offset by:

•

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

Changing market conditions resulting in additional third-party purchases to meet sales commitments in the Canadian ~~and USA~~ Operations ~~increased $0.66 per BOE and $7.17 per BOE, respectively, compared to~~in the first ~~nine months~~quarter of ~~2017 primarily due to:~~2019; and

~~Higher capital spending resulting from an increased capital program in 2018, transfers of unproved property costs of previously acquired assets which have been evaluated for proved reserves~~

Price optimization activities and ~~lower reserve volumes from the sale of the Piceance natural gas assets~~additional third-party purchases to meet sales commitments in the USA Operations in the third quarter of ~~2017.~~2019.

~~Administrative~~

~~Administrative expense represents costs associated with corporate functions provided by Encana staff~~56

Depreciation, Depletion & Amortization

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

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

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

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

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018

Canadian Operations	$	100	$	95	$	287	$	257
USA Operations		438		241		1,141		628
Upstream DD&A		538		336		1,428		885

Market Optimization		-		-		-		1
Corporate & Other		7		13		26		38
Total	$	545	$	349	$	1,454	$	924

	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018

Canadian Operations	$	4.61	$	4.57	$	4.56	$	4.55
USA Operations	$	12.93	$	17.05	$	12.95	$	16.39
Upstream DD&A	$	9.67	$	9.65	$	9.45	$	9.34

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

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

•

Higher production volumes in the ~~Calgary and Denver offices. Costs primarily include salaries and benefits, general office, information technology and long-term incentive costs.~~

Three months ended September 30,

Nine months ended September 30,

2018

2017

2018

2017

Administrative ($ millions)
$
57

$
86

$
187

$
168

Administrative ($/BOE) ⁽¹⁾
$
1.64

$
3.31

$
1.98

$
2.02

~~(1)~~

Administrative expense per BOE for the third quarter and first nine months of 2018 includes long-term incentive costs of $0.47/BOE and $0.64/BOE, respectively (2017 - $1.68/BOE and $0.44/BOE, respectively).

~~Three months ended September 30, 2018 versus September 30, 2017~~

Administrative expense in the third quarter of 2018 decreased $29 million compared to the third quarter of 2017 primarily due to lower long-term incentive costs in 2018 resulting from the smaller change in Encana’s share price in the third quarter of 2018 compared to 2017USA Operations ($~~26 million).~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~

Administrative expense in the first nine months of 2018 increased $19 million compared to the first nine months of 2017 primarily due to higher long-term incentive costs resulting from the increase in Encana’s share price in the first nine months of 2018 ($25337 million), partially offset by ~~legal costs incurred~~lower depletion rates in ~~2017~~the USA Operations ($5141 million).

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

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

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

•

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

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

Administrative

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

	Three months ended September 30,				Nine months ended September 30,
($ millions)	2019		2018		2019		2018

Administrative, excluding Long-Term Incentive and
Restructuring Costs	$	76	$	40	$	237	$	126
Long-term incentive costs		1		17		18		61
Restructuring costs		4		-		134		-
Total Administrative	$	81	$	57	$	389	$	187

	Three months ended September 30,				Nine months ended September 30,
($/BOE)	2019		2018		2019		2018

Administrative, excluding Long-Term Incentive and
Restructuring Costs	$	1.38	$	1.17	$	1.57	$	1.34
Long-term incentive costs		0.01		0.47		0.12		0.64
Restructuring costs		0.07		-		0.88		-
Total Administrative	$	1.46	$	1.64	$	2.57	$	1.98

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

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

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

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

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

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

~~Other (Income) Expenses~~

Three months ended September 30,

Nine months ended September 30,

($ millions)
2018

2017

2018

2017

Interest
$
92

$
101

$
265

$
268

Foreign exchange (gain) loss, net

(23
)

(210
)

93

(294
)
(Gain) loss on divestitures, net

-

(406
)

(4
)

(405
)
Other (gains) losses, net

5

(11
)

2

(46
)
Total Other (Income) Expenses
$
74

$
(526
)

$
356

$
(477
)

Other (Income) Expenses

	Three months ended September 30,						Nine months ended September 30,
($ millions)	2019			2018			2019			2018

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

Interest

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

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

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

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

Foreign Exchange (Gain) Loss, Net

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

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

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

Interest expense primarily includes interest on Encana’s long-term debt arising from U.S. dollar denominated unsecured notes. Encana also incurs interest on the Company’s long-term obligation for The Bow office building and capital leases. Further details on changes in interest can be found in Note 5 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.•

~~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 third quarter of 2018, Encana recorded a lower net foreign exchange gain compared to 2017 ($187 million). The change was primarily due to lower unrealized foreign exchange gains on the translation of U.S. dollar financing debt issued from Canada compared to 2017 ($113 million) and unrealized foreign exchange losses on the translation of intercompany notes compared to gains in 2017 ($64 million).

~~In the first nine months of 2018, Encana recorded a net foreign exchange loss compared to a net gain in 2017 ($387 million). The change was primarily due to unrealized~~Unrealized foreign exchange losses on the translation of U.S. dollar financing debt issued from Canada compared to gains in ~~2017~~2018 ($~~403~~142 million);

partially offset by:

•

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

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

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

•

Unrealized foreign exchange gains on the translation of U.S. dollar financing debt issued from Canada compared to losses in 2018 ($255 million), realized foreign exchange gains on the settlement of U.S. dollar financing debt issued from Canada compared to losses in 2018 ($23 million) and unrealized foreign exchange gains on the translation of U.S. dollar risk management contracts issued from Canada compared to ~~gains~~losses in ~~2017~~2018 ($6020 million)~~, partially offset by~~;

partially offset by:

•

Higher unrealized foreign exchange losses on the translation of intercompany notes compared to 2018 ($108 million) and lower realized foreign exchange gains on the settlement of intercompany notes compared to ~~losses in 2017~~2018 ($6517 million).

~~(Gain) Loss on Divestitures, Net~~

Amounts received from the Company’s divestiture transactions are deducted from the respective Canadian and U.S. full cost pools, except for divestitures that result in a significant alteration between capitalized costs and proved reserves in a country cost centre, in which case a gain or loss is recognized. Additional information on gains on divestitures can be found in Note 8 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Gain on divestitures in the third quarter and first nine months of 2017 primarily includes the before tax gain on the sale of the Piceance natural gas assets. Further information on divestitures can be found in the Liquidity and Capital Resources section of this MD&A.

~~Other (Gains) Losses, Net~~

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

Other gains in the first nine months of 2017 primarily includes interest received of $33 million resulting from the successful resolution of certain tax items previously assessed by the tax authorities relating to prior taxation years.

Other (Gains) Losses, Net

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

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

Income Tax

	Three months ended September 30,					Nine months ended September 30,
($ millions)	2019			2018		2019		2018

Current Income Tax Expense (Recovery)	$	(1	)	$	-	$	3	$	(61	)
Deferred Income Tax Expense (Recovery)		44			6		140		6
Income Tax Expense (Recovery)	$	43		$	6	$	143	$	(55	)

Effective Tax Rate	22.4%			13.3%		37.3%		343.8%

Income Tax Expense (Recovery)

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

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

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

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

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

Effective Tax Rate

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

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

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

Three months ended September 30,

Nine months ended September 30,

($ millions)

2018

2017

2018

2017

Current Income Tax Expense (Recovery)

$
-

$
1

$
(61
)

$
(56
)
Deferred Income Tax Expense (Recovery)

6

227

6

283

Income Tax Expense (Recovery)

$
6

$
228

$
(55
)

$
227

Effective Tax Rate

13.3
%

43.7
%

343.8
%

17.7
%

~~Income Tax Expense (Recovery)~~61

~~Three months ended September 30, 2018 versus September 30, 2017~~

~~In the third quarter of 2018, Encana recorded a lower income tax expense compared to 2017 primarily due to a lower deferred tax expense as a result of:~~

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

~~A reduction in the U.S. federal corporate tax rate to 21 percent from 35 percent resulting from U.S. Tax Reform; and~~

~~Changes in the estimated annual effective income tax rate in 2017 arising from gains recognized on foreign exchange and divestitures, including allocated goodwill.~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~

In the first nine months of 2018, Encana recorded a lower deferred income tax expense compared to 2017 primarily due to lower net earnings before income tax compared to 2017 and U.S. Tax Reform, as discussed above. The deferred tax expense in the first nine months of 2017 was primarily due to changes in the estimated annual effective income tax rate as discussed above.

There has been no change in 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. Additional information on U.S. Tax Reform can be found in Note 7 to the Consolidated Financial Statements included in Item 8 of the 2017 Annual Report on Form 10-K.

~~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. These items resulted in an effective tax rate for the third quarter of 2018 which is lower than the Canadian statutory rate of 27 percent and an effective tax rate for the first nine months of 2018 that is above the Canadian statutory rate.

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.

~~Liquidity and Capital Resources~~

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 September 30, ~~2018, $229~~2019, $17 million in cash and cash equivalents was held by U.S. subsidiaries. The cash held by U.S. subsidiaries is accessible and may be subject to additional Canadian income taxes and U.S. withholding taxes if repatriated.

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

	As at September 30,				As at September 30,
($ millions, except as indicated)	2018		2017		2019			2018

Cash and Cash Equivalents	$	615	$	889	$	138		$	615
Available Credit Facility – Encana ⁽¹⁾		2,500		3,000		2,500			2,500
Available Credit Facility – U.S. Subsidiary ⁽¹⁾		1,500		1,500		1,500			1,500
Issuance of U.S. Commercial Paper						(740	)		-
Total Liquidity	$	4,615	$	5,389	$	3,398		$	4,615

Long-Term Debt, including current portion	$	4,198	$	4,197
Total Shareholders’ Equity	$	6,494	$	6,965
Long-Term Debt, including current portion⁽²⁾					$	7,024		$	4,198
Total Shareholders’ Equity⁽³⁾					$	9,921		$	6,494

Debt to Capitalization (%) ⁽²⁾	39			38
Debt to Adjusted Capitalization (%) ⁽³⁾	23			22
Debt to Capitalization (%) ⁽⁴⁾						41			39
Debt to Adjusted Capitalization (%) ⁽⁵⁾						28			23

(1)	Collectively, the “Credit Facilities”.

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

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

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

~~(3)~~(5)

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

~~In the first quarter of 2018,~~As at September 30, 2019, the Company ~~amended the capacity~~had $740 million of commercial paper outstanding under its ~~Encana Credit Facility from $3.0 billion~~U.S. CP program to provide for short‑term funding requirements, which is supported by Encana’s $2.5 billion revolving credit facility. Further details on the U.S. CP program can be found in the Sources and ~~extended the maturity for both Credit Facilities to July 2022.~~Uses of Cash section of this MD&A.

Encana is currently in compliance with, and expects that it will continue to be in compliance with, all financial covenants under the Credit Facilities. Management monitors Debt to Adjusted Capitalization, which is a non-GAAP measure defined in the Non-GAAP Measures section of this MD&A, as a proxy for Encana’s financial covenant under the Credit Facilities, which requires debt to adjusted capitalization to be less than 60 percent. As at September 30, 2019, Debt to Adjusted Capitalization was 28 percent. The definitions used in the covenant under the Credit Facilities adjust capitalization forcumulative 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 1213 to the Consolidated Financial Statements included in Item 8 of the ~~2017~~2018 Annual Report on Form ~~10-K.~~10‑K.

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

Sources and Uses of Cash

In the third quarter and first nine months of ~~2018,~~2019, Encana primarily generated cash through operating activities. The following table summarizes the sources and uses of the Company’s cash and cash equivalents.

		Three months ended September 30,				Nine months ended September 30,						Three months ended September 30,					Nine months ended September 30,
($ millions)	Activity Type	2018		2017		2018			2017		Activity Type	2019			2018		2019			2018

Sources of Cash and Cash Equivalents
Sources of Cash, Cash Equivalents and Restricted Cash
Cash from operating activities	Operating	$	885	$	357	$	1,741		$	681	Operating	$	756		$	885	$	2,191		$	1,741
Proceeds from divestitures	Investing		24		625		89			710	Investing		171			24		177			89
Corporate acquisition, net of cash and restricted cash acquired											Investing		-			-		94			-
Net issuance of revolving long-term debt											Financing		-			-		740			-
Other	Investing		-		14		72			93	Investing		-			-		-			72
			909		996		1,902			1,484			927			909		3,202			1,902

Uses of Cash and Cash Equivalents
Capital expenditures	Investing		523		473		1,626			1,287	Investing		566			523		2,052			1,626
Acquisitions	Investing		15		2		17			50	Investing		25			15		66			17
Net repayment of revolving long-term debt											Financing		21			-		-			-
Repayment of long-term debt											Financing		-			-		500			-
Purchase of common shares	Financing		50		-		250			-	Financing		213			50		1,250			250
Dividends on common shares	Financing		14		14		43			43	Financing		24			14		77			43
Other	Investing/Financing		31		21		68			61	Investing/Financing		164			31		181			68
			633		510		2,004			1,441			1,013			633		4,126			2,004
Foreign Exchange Gain (Loss) on Cash and Cash Equivalents Held in Foreign Currency			3		8		(2	)		12

Increase (Decrease) in Cash and Cash Equivalents		$	279	$	494	$	(104	)	$	55
Foreign Exchange Gain (Loss) on Cash, Cash Equivalents and Restricted Cash Held in Foreign Currency											Foreign Exchange Gain (Loss) on Cash, Cash Equivalents and Restricted Cash Held in Foreign Currency		-			3		4			(2	)
Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash											Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	$	(86	)	$	279	$	(920	)	$	(104	)

Operating Activities

Cash from operating activities in the third quarter and first nine months of ~~2018~~2019 was ~~$885~~$756 million and ~~$1,741~~$2,191 million, respectively, and was primarily a reflection of ~~recovering liquids prices,~~the impacts from the Newfield acquisition, increases in production volumes, the ~~Company’s efforts in maintaining cost efficiencies achieved in previous years~~effects of the commodity price mitigation program and changes in ~~non-cash~~non‑cash working ~~capital.~~ capital, partially offset by lower average realized commodity prices.

Additional detail on changes in non-cash working capital can be found in Note 2023 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. Encana expects it will continue to meet the payment terms of its suppliers.

Non-GAAP Cash Flow in the third quarter and first nine months of ~~2018~~2019 was ~~$589~~ $817million and ~~$1,575~~$2,116 million, ~~respectively. Non-GAAP Cash Flow~~respectively, and was primarily impacted by the items affecting cash from operating activities which are discussed below and in the Results of Operations section of this MD&A.

Three months ended September 30, ~~2018~~2019 versus September 30, ~~2017~~2018

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

•

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

partially offset by:

•

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

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

Net cash from operating activities increased ~~$528 million compared to the third quarter of 2017 primarily due to:~~

~~Higher realized commodity prices ($286 million), higher production volumes ($228 million) and changes in non-cash working capital ($215 million);~~

~~partially offset by:~~

~~Realized losses on risk management in revenues in the third quarter of 2018 compared to realized gains in 2017 ($118 million) and higher transportation and processing expense ($79 million).~~

~~Nine months ended September 30, 2018 versus September 30, 2017~~

~~Net cash from operating activities increased $1,060~~ $450million compared to the first nine months of ~~2017~~2018 primarily due to:

~~Higher realized commodity prices ($581million), higher production volumes ($394 million) and changes in non-cash working capital ($390million);~~

•

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

partially offset by:

~~Higher transportation and processing expense ($182~~million), realized losses on risk management in revenues in the first nine months of 2018 compared to realized gains in 2017 ($131 million) and lower interest income recorded in other gains ($27 million).

•

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

Investing Activities

Cash used in investing activities in the first nine months of ~~2018~~2019 was ~~$1,482~~ $1,965million primarily due to capital expenditures. Capital expenditures inincreased $426 million compared to the first nine months of 2018 ~~increased $339 million compared to 2017~~ due to an increase in the Company’s capital program for ~~2018. This increase~~2019 relating to the Anadarko asset acquired in the Newfield acquisition ($556 million). Cash from operating activities exceeded capital expenditures by $139 million.

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

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

Divestitures in the first nine months of 2019 were $177 million, which primarily included the sale of the Company’s Arkoma Basin natural gas assets in ~~Montney ($221 million) and Eagle Ford ($70 million).~~

Oklahoma, comprising approximately 140,000 net acres. Proceeds from the sale of the Arkoma Basin natural gas assets were used to reduce the Company’s long-term debt. Divestitures in the first nine months of 2018 were $89 million, which primarily included the sale of ~~the~~certain Pipestone ~~midstream~~ assets in Alberta. Divestitures in the first nine months of 2017 were $710 million, which primarily included the sale of the Piceance natural gas assets in northwestern Colorado and the sale of the Tuscaloosa Marine Shale assets in Mississippi and Louisiana. Divestitures also included the sale of certain properties that did not complement Encana's existing portfolio of assets.

~~Acquisitions in the first nine months of 2018 and 2017 were $17 million and $50 million, respectively, which primarily included purchases with oil and liquids rich potential.~~

Capital expenditures and acquisition and divestiture activity are summarized in Notes 3, 8 and 89 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

Financing Activities

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

Net cash used in financing activities in the first nine months of ~~2018~~2019 increased ~~$257~~$789 million compared to the first nine months of ~~2017. The change was~~2018 primarily due to the purchase of common shares under a NCIB ($787 million) and substantial issuer bid ($213 million) as discussed below, repayment of long‑term debt ($500 million), as well as increased dividends paid ($34 million) in the first nine months of 2019 compared to the first nine months of 2018, partially offset by the net issuance of commercial paper under the Company’s U.S. CP program ($~~250~~740 million) ~~as discussed~~. Further detail on Encana’s U.S. CP program can be found below.

Encana’s long-term debt ~~including the current portion of $500 million which is due May 2019,~~ totaled ~~$4,198~~$7,024 million at September 30, ~~2018~~2019 and ~~$4,197~~$4,198 million at December 31, ~~2017. There was no current portion~~2018. On May 15, 2019, the Company repaid the $500 million 6.50 percent senior note using proceeds from the U.S. CP program.

Following the completion of ~~long-term debt~~the Newfield acquisition on February 13, 2019, Newfield’s senior notes totaling $2.45 billion remained outstanding ~~at December 31, 2017. As~~as at September 30, ~~2018, over 73~~2019. These include a $750 million 5.75 percent senior note due January 30, 2022, a $1.0 billion 5.625 percent senior note due July 1, 2024 and a $700 million 5.375 percent senior note due January 1, 2026. For additional information on long-term debt, refer to Note 12 to the Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q. The increase in long‑term debt resulting from the Newfield acquisition increased the Company’s ~~debt is not due until 2030 and beyond.~~ debt-based metrics. Further details on the Company’s debt-based metrics can be found in the Non-GAAP Measures section of this MD&A.

The Company ~~continues to have full~~has access to ~~the Credit Facilities,~~two credit facilities totaling $4.0 billion, which remain committed through July 2022. The Credit Facilities provide financial flexibility and allow the Company to fund its operations, development activities or capital ~~program.~~programs. At September 30, ~~2018, Encana had~~2019, no amounts were outstanding ~~balance~~ under the Credit Facilities. During the first nine months of 2019, the Company utilized its U.S. CP program which is supported by Encana’s $2.5 billion revolving credit facility. At September 30, 2019, Encana had $740 million of commercial paper outstanding under its U.S. CP program with an average term of 48 days and a weighted average interest rate of approximately 2.63 percent.

The Credit Facilities, together with cash and ~~$144~~cash equivalents less any outstanding commercial paper, provide Encana with total liquidity of $3.4 billion. At September 30, 2019, Encana also had approximately $153 million in undrawn letters of credit issued in the normal course of business primarily as collateral security, to support future abandonment liabilities and for transportation arrangements.

Encana ~~renewed its~~has filed a Canadian shelf prospectus ~~in August 2018~~ and ~~has access to~~ a U.S. shelf registration statement, ~~filed in 2017, whereby~~under which the Company may issue from time to time, debt securities, common shares, Class A preferred shares, subscription receipts, warrants, units, share purchase contracts and share purchase units in Canada and/or the U.S. At September 30, ~~2018,~~2019, $6.0 billion remained accessible under the Canadian shelf prospectus. The ability to issue securities under the Canadian shelf prospectus or U.S. shelf registration statement is dependent upon market ~~conditions.~~conditions and securities law requirements.

Dividends

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

	Three months ended September 30,				Nine months ended September 30,				Three months ended September 30,					Nine months ended September 30,
($ millions, except as indicated)	2018		2017		2018		2017			2019		2018		2019		2018

Dividend Payments(1)	$	14	$	15	$	43	$	44		$	24	$	14	$	77	$	43
Dividend Payments ($/share)	$	0.015	$	0.015	$	0.045	$	0.045		$	0.01875	$	0.015	$	0.05625	$	0.045

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

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

Substantial Issuer Bid

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

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

Normal Course Issuer Bid

On February ~~26, 2018, Encana~~27, 2019, the Company announced it received approval from the TSX to ~~commence~~purchase up to approximately 149.4 million common shares, for cancellation, pursuant to a NCIB ~~that enables~~over a 12-month period commencing March 4, 2019 and ending March 3, 2020. In first nine months of 2019, the Company used cash on hand to purchase, for cancellation, ~~up to 35~~approximately 149.4 million common shares ~~over a 12-month period from February 28, 2018 to February 27, 2019. The number~~for total consideration of ~~shares authorized for purchase represents~~ approximately ~~3.6 percent of Encana’s issued and outstanding common~~$1,037 million.

~~shares as at February 20, 2018. The Company has authorization from its Board to spend up to $400 million on the NCIB. For~~

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

For additional information on the NCIB, refer to Note 1315 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~~2018 Annual Report on Form 10-K.

Commitments and Contingencies

For information on commitments and contingencies, refer to Note 2124 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, Total Costs, Debt to Adjusted Capitalization and Net Debt to Adjusted EBITDA. Management’s use of these measures is discussed further below.

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

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

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

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

	Three months ended September 30,						Nine months ended September 30,
($ millions, except as indicated)	2019			2018			2019			2018

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

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

Total Costs

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

Three months ended September 30,

Nine months ended September 30,

($ millions, except as indicated)

2018

2017

2018

2017

Cash From (Used in) Operating Activities

$
885

$
357

$
1,741

$
681

(Add back) deduct:

Net change in other assets and liabilities

(17
)

(11
)

(33
)

(27
)
Net change in non-cash working capital

313

98

199

(191
)
Current tax on sale of assets

-

-

-

-

Non-GAAP Cash Flow

$
589

$
270

$
1,575

$
899

Production Volumes (MMBOE)

34.8

26.1

94.7

83.5

Non-GAAP Cash Flow Margin ($/BOE) ⁽¹⁾

$
16.93

$
10.34

$
16.63

$
10.77

	Three months ended September 30,				Nine months ended September 30,
($ millions, except as indicated)	2019		2018		2019		2018

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

(1)	Calculated using whole dollars and volumes.

~~(1)~~

~~Non-GAAP Cash Flow Margin was previously presented as Corporate Margin.~~67

Debt to Adjusted Capitalization

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

($ millions, except as indicated)	September 30, 2018		December 31, 2017		September 30, 2019		December 31, 2018

Long-Term Debt, including current portion	$	4,198	$	4,197	$	7,024	$	4,198
Total Shareholders’ Equity		6,494		6,728		9,921		7,447
Equity Adjustment for Impairments at December 31, 2011		7,746		7,746		7,746		7,746
Adjusted Capitalization	$	18,438	$	18,671	$	24,691	$	19,391
Debt to Adjusted Capitalization	23%		22%		28%		22%

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

Net Debt to Adjusted EBITDA

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

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

($ millions, except as indicated)	September 30, 2018			December 31, 2017			September 30, 2019			December 31, 2018

Long-Term Debt, including current portion	$	4,198		$	4,197		$	7,024		$	4,198
Less:
Cash and cash equivalents		615			719			138			1,058
Net Debt		3,583			3,478			6,886			3,140

Net Earnings (Loss)		(190	)		827			1,270			1,069
Add back (deduct):
Depreciation, depletion and amortization		1,167			833			1,802			1,272
Impairments		-			-			-		-
Accretion of asset retirement obligation		31			37			36			32
Interest		360			363			371			351
Unrealized (gains) losses on risk management		376			(442	)		(556	)		(519	)
Foreign exchange (gain) loss, net		108			(279	)		13			168
(Gain) loss on divestitures, net		(3	)		(404	)		(5	)		(5	)
Other (gains) losses, net		6			(42	)		39			17
Income tax expense (recovery)		321			603			292			94
Adjusted EBITDA (trailing 12-month)	$	2,176		$	1,496		$	3,262		$	2,479
Net Debt to Adjusted EBITDA (times)		1.6			2.3			2.1			1.3

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

Item 3: Quantitative and ~~Qualitati~~veQualitative 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~~2018 Annual Report on Form 10-K. To partially mitigate exposure to commodity price risk, the Company may enter into various derivative financial instruments including futures, forwards, swaps, options and costless collars. The use of these derivative instruments is governed under formal policies and is subject to limits established by the Board of Directors and may vary from time to time. Both exchange traded and over-the-counter traded derivative instruments may be subject to margin-deposit requirements, and the Company may be required from time to time to deposit cash or provide letters of credit with exchange brokers or counterparties to satisfy these margin requirements. For additional information relating to the Company’s derivative and financial instruments, see Note 1922 under Part I, Item 1 of this Quarterly Report on Form 10-Q.

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

	September 30, 2018					September 30, 2019
(US$ millions)	10% Price Increase			10% Price Decrease		10% Price Increase			10% Price Decrease
Crude oil price	$	(307	)	$	286	$	(198	)	$	194
NGL price		(20	)		20		(3	)		3
Natural gas price		(47	)		41		(63	)		55

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

The table below summarizes selected foreign exchange impacts on Encana’s financial results when compared to the same periods in ~~2017.~~2018.

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

To partially mitigate the effect of foreign exchange fluctuations on future commodity revenues and expenses, the Company may enter into foreign currency derivative contracts. As at September 30, ~~2018,~~2019, Encana has entered into ~~$179~~$250 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$~~0.7606~~0.7516 to C$1, which mature monthly through the remainder of ~~2018~~2019 and ~~$350~~$425 million notional U.S. dollar denominated currency swaps at an average exchange rate of US$~~0.7579~~0.7483 to C$1, which mature monthly throughout ~~2019.~~2020.

As at September 30, ~~2018,~~2019, Encana had ~~$4.2~~$4.5 billion in U.S. dollar long-term debt and ~~$259~~$181 million in U.S. dollar ~~capital leases~~finance lease obligations issued from Canada that were subject to foreign exchange exposure.

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

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

As at September 30, ~~2018,~~2019, the Company had no floating rate debt ~~and there were no~~of $740 million. Accordingly, the sensitivity in net earnings for each one percent change in interest rates on floating rate ~~derivatives outstanding.~~debt was $5 million (2018 - nil).

Encana’s Chief Executive Officer and Chief Financial Officer performed an evaluation of the Company’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (“Exchange Act”). The Company’s disclosure controls and procedures are designed to ensure that information required to be disclosed by the Company in reports it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the SEC, and to ensure that the information required to be disclosed by the Company in reports that it files or submits under the Exchange Act, is accumulated and communicated to the Company’s management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that the Company’s disclosure controls and procedures were effective as of September 30, ~~2018.~~2019.

~~There were no changes in Encana’s~~For the nine months ended September 30, 2019, management’s assessment of, and conclusion on, the effectiveness of internal control over financial reporting did not include the internal controls of the entities acquired in the Newfield acquisition on February 13, 2019. Newfield’s total assets and total revenues represented approximately 26 percent of the Company’s consolidated total assets at September 30, 2019 and approximately 29 percent and 29 percent of the Company’s consolidated total revenues for the three and nine months ended September 30, 2019, respectively. Under guidelines established by the SEC, companies are permitted to exclude acquisitions from their assessment of internal control over financial reporting for a period of up to one year following an acquisition while integrating the acquired company. The Company is in the process of integrating Newfield’s and the Company’s internal controls over financial reporting. As a result of these integration activities, certain controls will be evaluated and may be changed. Except as noted above, there were no changes in the Company’s internal control over financial reporting that occurred during the ~~second~~third quarter of ~~2018~~2019 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Please refer to Item 3 of the ~~2017~~2018 Annual Report on Form 10-K and Note 2124 of Encana’s Condensed Consolidated Financial Statements under Part I, Item 1 of this Quarterly Report on Form 10-Q.

Encana announced on October 31, 2019 its intention to establish corporate domicile in the United States. In ~~addition~~connection with the Reorganization, Encana entered into an Arrangement and Reorganization Agreement dated October 31, 2019 (the “Agreement”) with 1847432 Alberta ULC (“184Co”), which is currently a wholly-owned subsidiary of Encana and will be a predecessor of Ovintiv following completion of the Reorganization. The Reorganization is being implemented in accordance with the terms of and subject to the ~~other information set forth~~conditions contained in the Agreement, which sets out the terms of the Reorganization. Capitalized terms used in the following discussion and not otherwise defined in this Quarterly Report on Form 10-Q shall have the ~~reader should carefully consider~~meanings given to such terms in the ~~factors discussed in Item 1A. Risk Factors~~Agreement.

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

If the Reorganization is completed, Encana shareholders will become stockholders of a Delaware corporation. Therearesignificantdifferencesbetween theCanada Business Corporations Act (the “CBCA”) and the General Corporation Law of the ~~2017 Annual Report~~State of Delaware (the “DGCL”).For example, under the CBCA, many significant corporate actions such as amending a corporation's articles of incorporation or consummating a merger require the approval of at least two-thirds of the votes cast by shareholders, whereas under the DGCL, in most cases, such actions require the approval of a majority of the voting power of outstanding stock entitled to vote on ~~Form 10-K.~~the matter. Furthermore, shareholders under the CBCA are entitled to appraisal rights under a number of extraordinarycorporateactions,includinganamalgamation withanotherunrelatedcorporation,certainamendmentstoa corporation's articles of incorporation or the sale of all or substantially all of a corporation's assets, whereas under the DGCL, stockholders are only entitled to appraisal rights in connection with certain mergers, consolidations and similar transactions. As shown by the examples above, if the Reorganization is completed, in certain circumstances, holders of shares of common stock of Ovintiv will be afforded different protections under the DGCL than Encana shareholders had under the CBCA.

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

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

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

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

This choice of forum provision may limit a stockholder's ability to bring a claim in a judicial forum that it finds favorable for disputes with Ovintiv or its directors, officers or other matters pertaining to Ovintiv's internal affairs, and may discourage lawsuits with respect to such claims. Alternatively, if a court were to find these provisions of the Ovintiv Certificate of Incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, Ovintiv may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect ~~our~~its business, financial condition or future results, are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial may also adversely affect our business, financial condition and/or operating results.

~~In addition to~~There has been no prior public trading for the ~~risk factors previously disclosed in~~shares of common stock of Ovintiv on the ~~2017 Annual Report on Form 10-K,~~NYSE or the ~~following are risks related to our pending acquisition~~TSX and the market price of ~~Newfield:~~

~~The transactions contemplated by~~ the ~~merger agreement are~~shares of common stock of Ovintiv may be subject to conditions, including certain conditions that may not be satisfied, or completed on a timely basis, if at all. Failure to complete the transactions contemplated by the merger agreement, including the merger, could have material and adverse effects on Encana.volatility.

Completion of the merger is subject to a number of conditions, including, among other things, (i) the receipt of certain approvals of Encana shareholders and Newfield stockholders, (ii) the expiration or termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, (iii) the effectiveness of the registration statement on Form S-4 that Encana is obligated to file with the SEC in connection with the issuance of Encana common shares in the merger, (iv) the authorization for listing ofAlthough the Encana common shares ~~to be issued in the merger~~have historically been listed on the NYSE and the TSX, ~~(v)~~there has been no public trading market for the ~~accuracy~~shares of common stock of Ovintiv. Following the listing of the shares of common stock of Ovintiv on the NYSE and the TSX, and having regard to the share consolidation being completed pursuant to the Reorganization, there can be no assurance that the trading market for such shares will continue to be as active or liquid as was the trading market for the Encana common shares prior to the Reorganization or that the trading price of the shares of common stock of Ovintiv following the Reorganization may not be effectively lower than the trading price of the Encana common shares (including as a result of the share consolidation pursuant to the Reorganization).

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

In addition, ~~the merger agreement contains certain termination rights for both Newfield and Encana. If the merger agreement is terminated under certain circumstances,~~ Encana ~~could be required~~expects to ~~pay Newfield~~incur a ~~termination fee~~number of ~~$300 million. In other circumstances, upon termination of the merger agreement, Encana could be required to pay Newfield $50 million for~~non-recurring costs ~~fees and expenses incurred by Newfield. See our Current Report on Form 8-K filed~~associated with the ~~SEC on November 2, 2018 for a more detailed discussion of~~Reorganization, including legal fees, accountants' fees, proxy solicitor fees, filing fees, mailing expenses and financial printing expenses. There can be no assurance that the ~~conditions to~~actual costs will not exceed those estimated and the actual completion of the ~~merger~~Reorganization may result in additional and ~~termination rights under the merger agreement.~~

~~If the transactions contemplated by the merger agreement are not completed, Encana’s ongoing business may be adversely affected and, without realizing any~~unforeseen expenses. Most of ~~the benefits of having completed the transaction, Encana~~these costs will be ~~subject to a number of risks, including the following: Encana will be required to pay its costs relating to the transaction, such as legal, accounting, financial advisory and printing fees,~~payable whether or not the Reorganization is completed. While it is expected that benefits of the Reorganization achieved by Ovintiv will offset these transaction costs over time, this net benefit may not be achieved in the short-term or at all, particularly if the Reorganization is ~~completed;~~delayed or does not happen at all. These combined factors could adversely affect the business, operating profit and overall financial condition of Ovintiv.

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

Negative publicity resulting from the Reorganization could ~~otherwise have been devoted to pursuing other beneficial opportunities;~~adversely affect Encana's business and the market price of the Encana common shares ~~could be impacted to the extent that the current market price reflects a market assumption that the transaction will be completed; and if the merger agreement is terminated~~ and the ~~Encana Board~~shares of ~~Directors seeks another acquisition, Encana shareholders cannot be certain~~common stock of Ovintiv.

Domestication transactions that ~~Encana will be able to find a party willing to enter into a transaction as attractive to Encana as~~have been undertaken by other companies have in some cases generated significant news coverage, some of which has been negative. Negative publicity generated by the ~~acquisition of Newfield.~~

~~Encana will be subject to business uncertainties while the merger is pending, which~~Reorganization could ~~adversely affect its business.~~

~~In connection with the pendency of the transaction, it is possible that~~cause certain persons with whom Encana has a business relationship ~~may delay or defer certain~~to be more reluctant to do business ~~decisions or might decide to seek to terminate, change or renegotiate their relationships~~ with Encana asprior to the Reorganization, or Ovintiv following the Reorganization. In addition, negative publicity could cause certain of Encana's employees, particularly those in Canada, to perceive uncertainty regarding future opportunities available to them. Either of these events could have a ~~result~~significant adverse impact on Encana's business. Negative publicity could also cause some Encana shareholders to sell Encana common shares or decrease the demand for new investors to purchase such shares, which could have an adverse impact on the price of the ~~transaction, which could negatively affect Encana’s revenues, earnings and cash flows, as well as the market price of Encana’s~~Encana common shares ~~regardless~~and the shares of ~~whether the merger is completed.~~common stock of Ovintiv.

~~Under the terms~~Completion of the ~~merger agreement,~~Reorganization may trigger certain provisions in agreements to which Encana is ~~subject to certain restrictions on~~a party.

While the ~~conduct~~Reorganization will not result in an effective change of ~~its business prior to~~control of Encana, the completion of the ~~transaction, which may adversely affect its ability to execute certain of its business strategies, including the~~

ability in certain cases to enter into certain contracts, acquire or dispose of certain assets or incur certain indebtedness or capital expenditures. Such limitations could negatively affect Encana’s business and operations prior to the completion of the transaction.

In connection with the completion of the merger and the transactions contemplated by the merger agreement, based on the number of issued and outstanding shares of Newfield common stock as of October 29, 2018 and the number of outstanding Newfield equity awards currently estimated to be payable in our common shares in connection with the merger, Encana anticipates issuing up to approximately 547.5 million common shares. The actual number of Encana common shares to be issued in the merger will be determined at the completion of the merger based on the number of shares of Newfield common stock outstanding at the time of the consummation of the merger. The issuance of these new shares could have the effect of depressing the market price of Encana’s common shares, through dilution of earnings per share or otherwise. Any dilution of, or delay of any accretion to, Encana’s earnings per share could cause the price of its common shares to decline or increase at a reduced rate.

The transaction will also dilute the current ownership position and voting interest of Encana’s shareholders. Immediately after the merger is completed, it is expected that current Encana shareholders will own approximately 63.5% and Newfield stockholders will own approximately 36.5% of the combined company’s common shares outstanding, respectively. As a result, current Encana shareholders will have less influence on the policies of the combined company than they currently have.

The market price of Encana common shares could be negatively affected by risks and conditions that apply to Newfield, which may be different from the risks and conditions currently applicable to Encana.

Following the merger, Encana shareholders will own interests in a combined company operating an expanded business with more assets and a different mix of liabilities, in various jurisdictions in which Encana does not currently operate in. There is a risk that various factors, conditions and developments that would not currently affect the price of Encana common shares could, following the merger, negatively affect the price of Encana common shares. In addition, current Encana shareholders may not continue to invest in the combined company or may wish to reduce their investment in the combined company. If, following the merger, significant amounts of Encana common shares are sold, the price of Encana common shares could decline.

~~If the merger is completed, Encana may not achieve the intended benefits and the transaction may disrupt its current plans or operations.~~

There can be no assurance that Encana will be able to successfully integrate Newfield’s assets or otherwise realize the expected benefits of the transaction. Difficulties in integrating Newfield into Encana may result in the combined company performing differently than expected, in operational challenges or in the failure to realize anticipated expense-related efficiencies. Potential difficulties that may be encountered in the integration process include, among other factors: the inability to successfully integrate the businesses of Newfield into Encana in a manner that permits Encana to achieve the full revenue and cost savings anticipated from the transaction; complexities associated with managing a larger, more complex, integrated business; not realizing anticipated operating synergies; integrating personnel from the two companies and the loss of key employees; potential unknown liabilities and unforeseen expenses, delays or regulatory conditions associated with and following completion of the transaction; integrating relationships with vendors and business partners; performance shortfalls at one or both of the companies as a result of the diversion of management’s attention caused by completing the transaction and planning to integrate Newfield’s operations into Encana; and the disruption of, or the loss of momentum in, each company’s ongoing business or inconsistencies between the company’s standards, controls, procedures and policies.

~~Completion of the merger~~Reorganization may trigger certain technical change in control, right of first offer, notice, consent, assignment or other provisions in ~~certain~~ agreements to which ~~Newfield is a party.~~

~~The completion of the transaction may trigger change in control~~Encana or ~~other provisions in certain agreements to which Newfield is~~its subsidiaries are a party. If Encana ~~and Newfield~~and/or Ovintiv are unable to assert that such provisions should not apply, or is unable to comply with or negotiate waivers of those provisions, the counterparties may exercise their rights and remedies under the agreements, including potentially terminating ~~the~~such agreements or seeking monetary damages or, ~~Encana~~

in certain situations, Ovintiv may be required to make an offer to purchase outstanding debt securities of its subsidiary Newfield. Even if Encana ~~and Newfield are~~is able to negotiate waivers, the counterparties may require a fee for such waivers or seek to renegotiate the ~~agreements.~~agreements on terms less favorable to Ovintiv.

~~Encana is expected to incur significant transaction and acquisition-related costs~~Payments in connection with the ~~merger.~~exercise of dissent rights by Encana shareholders may impact Ovintiv's financial resources.

Under the CBCA, Encana ~~has incurred~~shareholders who (i) do not vote in favor of the Reorganization resolution, (ii) deliver to Encana a dissent notice, (iii) continuously hold their Encana common shares through the effective time of the Reorganization, and ~~is expected~~(iv) otherwise comply with the requirements and procedures of Section 190 of the CBCA (as modified by the Interim Order and Plan of Arrangement), are entitled to ~~continue to incur~~receive payment in cash of the "fair value" of their Encana common shares. Should a material number of ~~non-recurring costs associated with negotiating and completing the transaction, combining the operations of the two companies and achieving desired synergies. These costs~~Encana shareholders exercise dissent rights, a substantial cash payment may be ~~substantial and, in many cases, will~~required to be ~~borne by Encana whether or not the transaction is completed. A substantial majority of non-recurring expenses will consist of transaction costs and include, among others, fees paid~~made to financial, legal and other advisors, employee retention, severance and benefit costs and filing fees. Encana will also incur costs related to formulating and implementing integration plans, including facilities and systems consolidation costs and other employment-related costs. Encana continues to assess the magnitude of these costs, and additional unanticipated costs may be incurred in connection with the integration of the two companies’ businesses. The elimination of duplicative costs, as well as the realization of other efficiencies related to the integration of the businesses, may not initially offset integration-related costs or achieve a net benefit in the near term, or at all. Any unanticipated costs and expensessuch dissenting shareholders that could have an adverse effect on ~~Encana’s~~Ovintiv's financial condition and ~~operating results following~~cash resources if the Reorganization is completed. It is a condition precedent to completion of the ~~transaction.~~Reorganization that the time period for the exercise of any dissent rights conferred upon Encana shareholders in respect of the Reorganization shall have expired and Encana shareholders shall not have exercised (or otherwise be deemed to have exercised) dissent rights with respect to that number of Encana common shares that would make it inadvisable to proceed with the implementation of the Reorganization, as determined by Encana in its sole discretion.

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

On ~~February 26, 2018, Encana~~June 10, 2019, the Company announced ~~it had received approval from the TSX~~its intention to purchase, for cancellation, up to 35$213 million of its outstanding common shares through a SIB. The SIB subsequently expired on August 28, 2019 and on August 29, 2019, in accordance with the terms and conditions of the SIB, the Company purchased approximately 47.3 million common shares ~~pursuant to~~at a ~~NCIB over a 12-month period from February 28, 2018 to February 27, 2019.~~price of $4.50 per share for an aggregate purchase price of approximately $213 million.

~~During the three months ended September 30, 2018, the Company purchased 3.9 million common shares for total consideration of approximately $50 million at a weighted average price of $12.86.~~ The following table presents the common shares purchased during the three months ended September 30, ~~2018.~~2019.

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.

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


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

	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	910
	Notes to Condensed Consolidated Financial Statements	1011

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3842
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	6069
Item 4.	Controls and Procedures	6171

	PART II

Item 1.	Legal Proceedings	6272
Item 1A.	Risk Factors	6272
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6479
Item 3.	Defaults Upon Senior Securities	6479
Item 4.	Mine Safety Disclosures	6479
Item 5.	Other Information	6479
Item 6.	Exhibits	6579
Signatures		6680

		As at			As at					As at			As at
		September 30,			December 31,					September 30,			December 31,
(US$ millions)		2018			2017					2019			2018

Assets
Current Assets
Cash and cash equivalents		$	615		$	719				$	138		$	1,058
Accounts receivable and accrued revenues			835			774					1,127			789
Risk management	(Notes 18, 19)		146			205			(Notes 21, 22)		284			554
Income tax receivable			290			573					316			275
			1,886			2,271					1,865			2,676
Property, Plant and Equipment, at cost:	(Note 9)								(Note 10)
Oil and natural gas properties, based on full cost accounting
Proved properties			41,859			40,228					50,094			41,241
Unproved properties			3,964			4,480					3,943			3,730
Other			2,229			2,302			(Note 2)		892			2,122
Property, plant and equipment			48,052			47,010					54,929			47,093
Less: Accumulated depreciation, depletion and amortization			(38,519	)		(38,056	)				(39,803	)		(38,121	)
Property, plant and equipment, net	(Note 3)		9,533			8,954			(Note 3)		15,126			8,972
Other Assets			160			144		(Notes 2, 10, 11)			1,202			147
Risk Management	(Notes 18, 19)		132			246			(Notes 21, 22)		47			161
Deferred Income Taxes			1,019			1,043					521			835
Goodwill	(Note 3)		2,588			2,609			(Notes 3, 8)		2,595			2,553
	(Note 3)	$	15,318		$	15,267			(Note 3)	$	21,356		$	15,344

Liabilities and Shareholders’ Equity
Current Liabilities
Accounts payable and accrued liabilities		$	1,751		$	1,415				$	2,191		$	1,490
Current portion of operating lease liabilities									(Notes 2, 11)		79			-
Income tax payable			1			7					1			1
Risk management	(Notes 18, 19)		450			236			(Notes 21, 22)		10			25
Current portion of long-term debt	(Note 10)		500			-			(Note 12)		-			500
			2,702			1,658					2,281			2,016
Long-Term Debt	(Note 10)		3,698			4,197			(Note 12)		7,024			3,698
Operating Lease Liabilities									(Notes 2, 11)		972			-
Other Liabilities and Provisions	(Note 11)		1,916			2,167		(Notes 2, 11, 13)			548			1,769
Risk Management	(Notes 18, 19)		68			13			(Notes 21, 22)		14			22
Asset Retirement Obligation	(Note 12)		407			470			(Note 14)		414			365
Deferred Income Taxes			33			34					182			27
			8,824			8,539					11,435			7,897
Commitments and Contingencies	(Note 21)								(Note 24)
Shareholders’ Equity
Share capital - authorized unlimited common shares
2018 issued and outstanding: 952.4 million shares (2017: 973.1 million shares)	(Note 13)		4,655			4,757
2019 issued and outstanding: 1,299.2 million shares (2018: 952.5 million shares)									(Note 15)		7,061			4,656
Paid in surplus			1,358			1,358			(Note 15)		1,402			1,358
Accumulated deficit			(581	)		(429	)
Retained earnings											452			435
Accumulated other comprehensive income	(Note 14)		1,062			1,042			(Note 16)		1,006			998
Total Shareholders’ Equity			6,494			6,728					9,921			7,447
		$	15,318		$	15,267				$	21,356		$	15,344

Nine Months Ended September 30, 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)			-			-		39			-		39
Dividends on Common Shares	(Note 13)		-			-		(43	)		-		(43	)
Common Shares Purchased under Normal Course Issuer Bid	(Note 13)		(102	)		-		(148	)		-		(250	)
Common Shares Issued Under Dividend Reinvestment Plan	(Note 13)		-			-		-			-		-
Other Comprehensive Income (Loss)	(Note 14)		-			-		-			20		20
Balance, September 30, 2018		$	4,655		$	1,358	$	(581	)	$	1,062	$	6,494


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


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

Large accelerated filer	~~[X]~~☒	Accelerated filer	~~[ ]~~☐

Non-accelerated filer	~~[ ]~~☐	Smaller reporting company	~~[ ]~~☐

		Emerging growth company	~~[ ]~~☐


Number of registrant’s common shares outstanding as of October ~~26, 2018~~25, 2019			~~952,478,421~~1,299,112,236

		Three Months Ended						Nine Months Ended
		September 30,						September 30,
(US$ millions, except per share amounts)		2018			2017 ⁽¹⁾			2018			2017 ⁽¹⁾

Revenues	(Notes 3, 4)
Product and service revenues		$	1,488		$	880		$	4,025		$	2,751
Gains (losses) on risk management, net	(Note 19)		(241	)		(35	)		(517	)		432
Sublease revenues			15			16			50			50
Total Revenues			1,262			861			3,558			3,233
Operating Expenses	(Note 3)
Production, mineral and other taxes			45			27			109			80
Transportation and processing	(Note 19)		278			199			799			617
Operating	(Notes 16, 17)		124			132			372			377
Purchased product			282			202			803			565
Depreciation, depletion and amortization			349			210			924			590
Accretion of asset retirement obligation	(Note 12)		8			9			24			30
Administrative	(Notes 16, 17)		57			86			187			168
Total Operating Expenses			1,143			865			3,218			2,427
Operating Income (Loss)			119			(4	)		340			806
Other (Income) Expenses
Interest	(Note 5)		92			101			265			268
Foreign exchange (gain) loss, net	(Notes 6, 19)		(23	)		(210	)		93			(294	)
(Gain) loss on divestitures, net	(Note 8)		-			(406	)		(4	)		(405	)
Other (gains) losses, net	(Note 17)		5			(11	)		2			(46	)
Total Other (Income) Expenses			74			(526	)		356			(477	)
Net Earnings (Loss) Before Income Tax			45			522			(16	)		1,283
Income tax expense (recovery)	(Note 7)		6			228			(55	)		227
Net Earnings (Loss)		$	39		$	294		$	39		$	1,056
Net Earnings (Loss) per Common Share
Basic & Diluted	(Note 13)	$	0.04		$	0.30		$	0.04		$	1.09
Dividends Declared per Common Share	(Note 13)	$	0.015		$	0.015		$	0.045		$	0.045
Weighted Average Common Shares Outstanding (millions)
Basic & Diluted	(Note 13)		955.1			973.1			962.2			973.1

Three Months Ended September 30, 2019 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income			Total Shareholders’ Equity

Balance, June 30, 2019		$	7,318		$	1,358	$	327		$	1,012		$	10,015
Net Earnings (Loss)			-			-		149			-			149
Dividends on Common Shares ($0.01875 per share)	(Note 15)		-			-		(24	)		-			(24	)
Common Shares Purchased under Substantial Issuer Bid	(Note 15)		(257	)		44		-			-			(213	)
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			(6	)		(6	)
Balance, September 30, 2019		$	7,061		$	1,402	$	452		$	1,006		$	9,921

Nine Months Ended September 30, 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)			-		-		1,056			-			1,056
Dividends on Common Shares	(Note 13)		-		-		(44	)		-			(44	)
Common Shares Issued Under Dividend Reinvestment Plan	(Note 13)		1		-		-			-			1
Other Comprehensive Income (Loss)	(Note 14)		-		-		-			(174	)		(174	)
Balance, September 30, 2017		$	4,757	$	1,358	$	(186	)	$	1,036		$	6,965

Three Months Ended September 30, 2018 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income		Total Shareholders’ Equity

Balance, June 30, 2018		$	4,674		$	1,358	$	(575	)	$	1,040	$	6,497
Net Earnings (Loss)			-			-		39			-		39
Dividends on Common Shares ($0.015 per share)	(Note 15)		-			-		(14	)		-		(14	)
Common Shares Purchased under Normal Course Issuer Bid	(Note 15)		(19	)		-		(31	)		-		(50	)
Common Shares Issued Under Dividend Reinvestment Plan	(Note 15)		-			-		-			-		-
Other Comprehensive Income (Loss)	(Note 16)		-			-		-			22		22
Balance, September 30, 2018		$	4,655		$	1,358	$	(581	)	$	1,062	$	6,494

Nine Months Ended September 30, 2019 (US$ millions)		Share Capital			Paid in Surplus		Retained Earnings (Accumulated Deficit)			Accumulated Other Comprehensive Income		Total Shareholders’ Equity

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

										Restated
	Reported as at			Impact of						Balances as at
(US$ millions)	December 31, 2018			Adoption						January 1, 2019

Property, Plant and Equipment, at cost:
Oil and natural gas properties, based on full cost accounting
Proved properties	$	41,241		$	-					$	41,241
Unproved properties		3,730			-						3,730
Other		2,122			(1,261	)					861
Property, plant and equipment		47,093			(1,261	)					45,832
Less: accumulated depreciation, depletion and amortization		(38,121	)		128						(37,993	)
Property, plant and equipment, net		8,972			(1,133	)		(1	)		7,839
Other Assets		147			1,015		(1), (2		)		1,162
Deferred Income Taxes		835			(28	)					807
Total Assets		15,344			(146	)					15,198

Current Liabilities
Accounts payable and accrued liabilities		1,490			(12	)		(1	)		1,478
Current portion of operating lease liabilities		-			67			(2	)		67
Income tax payable		1			-						1
Risk management		25			-						25
Current portion of long-term debt		500			-						500
		2,016			55						2,071

Operating Lease Liabilities		-			948			(2	)		948
Other Liabilities and Provisions		1,769			(1,224	)		(1	)		545
Total Liabilities		7,897			(221	)					7,676

Retained Earnings		435			75			(1	)		510
Total Shareholders’ Equity		7,447			75						7,522
Total Liabilities and Shareholders’ Equity	$	15,344		$	(146	)				$	15,198

	Corporate & Other						Consolidated
	2018			2017 ⁽¹⁾			2018			2017 ⁽¹⁾

Revenues
Product and service revenues	$	-		$	-		$	1,488		$	880
Gains (losses) on risk management, net		(164	)		(76	)		(241	)		(35	)
Sublease revenues		15			16			15			16
Total Revenues		(149	)		(60	)		1,262			861

Operating Expenses
Production, mineral and other taxes		-			-			45			27
Transportation and processing		-			-			278			199
Operating		2			4			124			132
Purchased product		-			-			282			202
Depreciation, depletion and amortization		13			17			349			210
Accretion of asset retirement obligation		8			9			8			9
Administrative		57			86			57			86
Total Operating Expenses		80			116			1,143			865
Operating Income (Loss)	$	(229	)	$	(176	)		119			(4	)

Other (Income) Expenses
Interest								92			101
Foreign exchange (gain) loss, net								(23	)		(210	)
(Gain) loss on divestitures, net								-			(406	)
Other (gains) losses, net								5			(11	)
Total Other (Income) Expenses								74			(526	)
Net Earnings (Loss) Before Income Tax								45			522
Income tax expense (recovery)								6			228
Net Earnings (Loss)							$	39		$	294

							Market Optimization
	Marketing Sales						Upstream Eliminations						Total
For the three months ended September 30,	2019			2018			2019			2018			2019			2018

Revenues	$	2,088		$	1,513		$	(1,794	)	$	(1,197	)	$	294		$	316

Operating Expenses
Transportation and processing		173			120			(111	)		(87	)		62			33
Operating		6			8			-			-			6			8
Purchased product		1,947			1,392			(1,683	)		(1,110	)		264			282
Operating Income (Loss)	$	(38	)	$	(7	)	$	-		$	-		$	(38	)	$	(7	)

Preliminary Purchase Price Allocation

Consideration:
Fair value of Encana's common shares issued ⁽¹⁾	$	3,478
Fair value of Newfield liability awards paid in cash ⁽²⁾		5
Total Consideration	$	3,483

Assets Acquired:
Cash and cash equivalents	$	46
Accounts receivable and accrued revenues		486
Other current assets		50
Proved properties		5,903
Unproved properties		838
Other property, plant and equipment		22
Restricted cash		53
Other assets		105
Goodwill ⁽³⁾		22

Liabilities Assumed:
Accounts payable and accrued liabilities ⁽³⁾		(795	)
Long-term debt		(2,603	)
Operating lease liabilities		(76	)
Other long-term liabilities ⁽³⁾		(61	)
Asset retirement obligation		(184	)
Deferred income taxes ⁽³⁾		(323	)
Total Purchase Price	$	3,483

	As at September 30, 2018							As at December 31, 2017							As at September 30, 2019							As at December 31, 2018
			Accumulated							Accumulated							Accumulated							Accumulated
	Cost		DD&A			Net		Cost		DD&A			Net		Cost		DD&A			Net		Cost		DD&A			Net

Canadian Operations
Proved properties	$	14,685	$	(13,869	)	$	816	$	14,555	$	(14,047	)	$	508	$	14,817	$	(13,949	)	$	868	$	13,996	$	(13,261	)	$	735
Unproved properties		255		-			255		311		-			311		223		-			223		237		-			237
Other		27		-			27		43		-			43		20		-			20		27		-			27
		14,967		(13,869	)		1,098		14,909		(14,047	)		862		15,060		(13,949	)		1,111		14,260		(13,261	)		999

USA Operations
Proved properties		27,116		(23,869	)		3,247		25,610		(23,240	)		2,370		35,223		(25,186	)		10,037		27,189		(24,099	)		3,090
Unproved properties		3,709		-			3,709		4,169		-			4,169		3,720		-			3,720		3,493		-			3,493
Other		17		-			17		16		-			16		25		-			25		8		-			8
		30,842		(23,869	)		6,973		29,795		(23,240	)		6,555		38,968		(25,186	)		13,782		30,690		(24,099	)		6,591

Market Optimization		7		(6	)		1		7		(5	)		2		8		(6	)		2		7		(6	)		1
Corporate & Other		2,236		(775	)		1,461		2,299		(764	)		1,535		893		(662	)		231		2,136		(755	)		1,381
	$	48,052	$	(38,519	)	$	9,533	$	47,010	$	(38,056	)	$	8,954	$	54,929	$	(39,803	)	$	15,126	$	47,093	$	(38,121	)	$	8,972

(US$ millions, unless otherwise specified)	As at September 30, 2019

Condensed Consolidated Balance Sheet ⁽¹⁾:
Operating Lease ROU Assets, in Other Assets	$	1,045
Finance Lease ROU Assets, in Other Property Plant and Equipment		39

Operating Lease Liabilities:
Current		79
Long-term		972

Finance Lease Liabilities:
Current, in accounts payable and accrued liabilities		88
Long-term, in other liabilities and provisions		144

Weighted Average Discount Rate
Operating leases	5.42%
Finance leases	5.97%
Weighted Average Remaining Lease Term
Operating leases	16.4 years
Finance leases	3.4 years

	2019			2020			2021			2022			2023			Thereafter			Total

Operating Leases ⁽¹⁾
Expected Future Lease Payments	$	37		$	128		$	112		$	97		$	85		$	1,165		$	1,624
Less: Discounting																				573
Present Value of Future Operating Lease Payments																			$	1,051
Sublease Income (undiscounted)	$	(10	)	$	(41	)	$	(42	)	$	(37	)	$	(37	)	$	(566	)	$	(733	)

Finance Leases
Expected Future Lease Payments	$	25		$	99		$	87		$	8		$	8		$	30		$	257
Less: Discounting																				25
Present Value of Future Finance Lease Payments																			$	232
Sublease Income (undiscounted) ⁽²⁾	$	(2	)	$	(8	)	$	(8	)	$	(8	)	$	(7	)	$	(24	)	$	(57	)

	As at September 30, 2018						As at December 31, 2017				As at September 30, 2019						As at December 31, 2018
	Number (millions)			Amount			Number (millions)		Amount		Number (millions)			Amount			Number (millions)			Amount

Common Shares Outstanding, Beginning of Year		973.1		$	4,757			973.0	$	4,756		952.5		$	4,656			973.1		$	4,757
Common Shares Purchased		(20.7	)		(102	)		-		-		(196.7	)		(1,073	)		(20.7	)		(102	)
Common Shares Issued												543.4			3,478			-			-
Common Shares Issued Under Dividend Reinvestment Plan		-			-			0.1		1		-			-			0.1			1
Common Shares Outstanding, End of Period		952.4		$	4,655			973.1	$	4,757		1,299.2		$	7,061			952.5		$	4,656

	As at September 30, 2018		As at September 30, 2017		As at September 30, 2019		As at September 30, 2018
	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units	US$ Share Units	C$ Share Units

Risk Free Interest Rate	2.18%	2.18%	1.53%	1.53%	1.58%	1.58%	2.18%	2.18%
Dividend Yield	0.46%	0.46%	0.51%	0.53%	1.63%	1.64%	0.46%	0.46%
Expected Volatility Rate ⁽¹⁾	55.44%	51.90%	59.35%	55.21%	44.14%	42.77%	55.44%	51.90%
Expected Term	1.6 yrs	2.0 yrs	1.6 yrs	1.7 yrs	2.9 yrs	2.6 yrs	1.6 yrs	2.0 yrs
Market Share Price	US$13.11	C$16.93	US$11.78	C$14.69	US$4.60	C$6.07	US$13.11	C$16.93

													Three Months Ended						Nine Months Ended
	Three Months Ended September 30,						Nine Months Ended September 30,						September 30,						September 30,
	2018			2017			2018			2017			2019			2018			2019			2018

Total Compensation Costs of Transactions Classified as Cash-Settled	$	36		$	91		$	118		$	84		$	2		$	36		$	46		$	118
Less: Total Share-Based Compensation Costs Capitalized		(11	)		(30	)		(33	)		(30	)		(1	)		(11	)		(16	)		(33	)
Total Share-Based Compensation Expense (Recovery)	$	25		$	61		$	85		$	54		$	1		$	25		$	30		$	85

Recognized on the Condensed Consolidated Statement of Earnings in:
Operating	$	8		$	18		$	24		$	18		$	-		$	8		$	12		$	24
Administrative		17			43			61			36			1			17			18			61
	$	25		$	61		$	85		$	54		$	1		$	25		$	30		$	85

	As at September 30, 2018			As at December 31, 2017			As at September 30, 2019			As at December 31, 2018

Liability for Cash-Settled Share-Based Payment Transactions:
Unvested		$	287		$	274		$	53		$	148
Vested			70			53			12			17
		$	357		$	327		$	65		$	165

Nine Months Ended September 30, ~~2018~~2019 (thousands of units)

TSARs			~~872~~1,244
SARs			~~377~~1,718
PSUs			~~2,546~~7,833
DSUs			45111
RSUs			~~5,358~~11,004

	Pension Benefits				OPEB				Total				Pension Benefits				OPEB				Total
	2018		2017		2018		2017		2018		2017		2019		2018		2019		2018		2019		2018

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

	Defined Benefits						OPEB						Total						Defined Benefits						OPEB						Total
	2018			2017			2018			2017			2018			2017			2019			2018			2019			2018			2019			2018

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

As at September 30, 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
As at September 30, 2019														Level 1 Quoted Prices in Active Markets		Level 2 Other Observable Inputs		Level 3 Significant Unobservable Inputs		Total Fair Value		Netting ⁽¹⁾			Carrying Amount

Risk Management Assets
Commodity Derivatives:
Current assets	$	13	$	200	$	-	$	213	$	(77	)	$	136	$	-	$	256	$	92	$	348	$	(68	)	$	280
Long-term assets		-		144		-		144		(14	)		130		-		59		22		81		(35	)		46
Foreign Currency Derivatives:
Current assets		-		10		-		10		-			10		-		4		-		4		-			4
Long-term assets		-		2		-		2		-			2		-		1		-		1		-			1

Risk Management Liabilities
Commodity Derivatives:
Current liabilities	$	-	$	405	$	122	$	527	$	(77	)	$	450	$	-	$	78	$	-	$	78	$	(68	)	$	10
Long-term liabilities		-		56		26		82		(14	)		68		-		49		-		49		(35	)		14
Foreign Currency Derivatives:
Current liabilities		-		-		-		-		-			-

Other Derivative Contracts
Current in accounts payable and accrued liabilities	$	-	$	5	$	-	$	5	$	-		$	5	$	-	$	2	$	-	$	2	$	-		$	2
Long-term in other liabilities and provisions		-		10		-		10		-			10		-		8		-		8		-			8

	Notional Volumes	Term	Average Price		Fair Value			Notional Volumes	Term	Average Price		Fair Value

Crude Oil and NGL Contracts			US$/bbl							US$/bbl
Fixed Price Contracts
WTI Fixed Price	110.5 Mbbls/d	2018		55.65	$	(175	)	45.0 Mbbls/d	2019		60.24	$	26
WTI Fixed Price	35.0 Mbbls/d	2019		60.31		(134	)	24.0 Mbbls/d	2020		60.05		74
Propane Fixed Price	9.0 Mbbls/d	2018		39.05		(5	)	3.8 Mbbls/d	2019		35.72		11
Propane Fixed Price	4.8 Mbbls/d	2019		34.87		(9	)	1.8 Mbbls/d	2020		21.00		1
Butane Fixed Price	7.0 Mbbls/d	2018		43.49		(7	)
Butane Fixed Price	3.0 Mbbls/d	2019		38.89		(8	)	6.5 Mbbls/d	2019		40.54		10
Ethane Fixed Price	3.0 Mbbls/d	2019		17.19		(1	)	5.3 Mbbls/d	2019		17.23		5

WTI Fixed Price Swaptions ⁽¹⁾	24.0 Mbbls/d	Q1 - Q2 2019		63.13		(42	)	4.0 Mbbls/d	2021		58.00		(4	)

WTI Three-Way Options
Sold call / bought put / sold put	16.0 Mbbls/d	2018	54.49 / 47.17 / 36.88			(25	)	87.5 Mbbls/d	2019	67.72 / 56.47 / 45.86			27
Sold call / bought put / sold put	52.5 Mbbls/d	2019	69.22 / 59.47 / 48.57			(110	)	80.0 Mbbls/d	2020	61.68 / 53.44 / 43.44			54

WTI Costless Collars
Sold call / bought put	10.0 Mbbls/d	2018	57.08 / 45.00			(13	)	43.0 Mbbls/d	2019	65.57 / 56.28			13
Sold call / bought put								15.0 Mbbls/d	2020	68.71 / 50.00			20

Basis Contracts ⁽²⁾		2018				15			2019				(19	)
		2019				27
		2020				(4	)
									2020				(34	)
Crude Oil and NGLs Fair Value Position						(491	)						184

Natural Gas Contracts			US$/Mcf							US$/Mcf
Fixed Price Contracts
NYMEX Fixed Price	1,017 MMcf/d	2018		3.03		(1	)	687 MMcf/d	2019		2.72		19
NYMEX Fixed Price	742 MMcf/d	2019		2.73		(13	)	653 MMcf/d	2020		2.69		64

NYMEX Fixed Price Swaptions ⁽³⁾	300 MMcf/d	Q1 - Q2 2019		2.99		(7	)	180 MMcf/d	2021		2.61		(9	)

NYMEX Three-Way Options
Sold call / bought put / sold put								330 MMcf/d	2020	2.72 / 2.60 / 2.25			7

NYMEX Costless Collars
Sold call / bought put								177 MMcf/d	2019	3.05 / 2.89			8
Sold call / bought put								55 MMcf/d	2020	2.88 / 2.50			4

NYMEX Call Options
Sold call price	230 MMcf/d	2018		3.75		-
Sold call price	230 MMcf/d	2019		3.75		(4	)
Bought call price	230 MMcf/d	2019		3.75		-
Sold call price	230 MMcf/d	2020		3.25		1
Sold call								230 MMcf/d	2019		3.75		-
Bought call								230 MMcf/d	2019		3.75		(1	)
Sold call								230 MMcf/d	2020		3.25		4

Basis Contracts ⁽⁴⁾		2018				35			2019				10
		2019				126			2020				30
		2020				88			2021				(2	)
		2021 - 2023				18			2022 - 2025				(8	)

Other Financial Positions													(1	)
Natural Gas Fair Value Position						243							125

Net Premiums Received on Unexpired Options						(4	)						(7	)

Other Derivative Contracts
Fair Value Position						(15	)						(10	)

Foreign Currency Contracts
Fair Value Position ⁽⁵⁾		2018 - 2019				12			2019 - 2020				5
Total Fair Value Position and Net Premiums Received					$	(255	)					$	297

	Expected Future Payments														Expected Future Payments
(undiscounted)	2018		2019		2020		2021		2022		Thereafter		Total		2019		2020		2021		2022		2023		Thereafter		Total

Transportation and Processing	$	146	$	709	$	688	$	598	$	571	$	2,763	$	5,475	$	197	$	731	$	625	$	594	$	485	$	2,407	$	5,039
Drilling and Field Services		73		66		29		9		-		-		177		64		24		6		-		-		-		94
Operating Leases		4		17		17		16		16		49		119
Building Leases																4		15		14		11		7		15		66
Total	$	223	$	792	$	734	$	623	$	587	$	2,812	$	5,771	$	265	$	770	$	645	$	605	$	492	$	2,422	$	5,199

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
July 1 to July 31, 2018		-	$	-		-		18,190,000
August 1 to August 31, 2018		1,875,000		13.09		1,875,000		16,315,000
September 1 to September 30, 2018		2,000,000		12.65		2,000,000		14,315,000
Total		3,875,000	$	12.86		3,875,000		14,315,000

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

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

ENCANA CORPORATION

By:	/s/ ~~Sherri A. Brillon~~Corey D. Code

	Name:	~~Sherri A. Brillon~~Corey D. Code
	Title:	Executive Vice-President & Chief Financial Officer