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FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

[✓]     QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2016

OR

[    ]    TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from --- to ---

Commission file number 0-12014

IMPERIAL OIL LIMITED

(Exact name of registrant as specified in its charter)

 

CANADA						98-0017682
(State or other jurisdiction						(I.R.S. Employer
of incorporation or organization)						Identification No.)
505 Quarry Park Boulevard S.E.
Calgary, Alberta, Canada						T2C 5N1
(Address of principal executive offices)						(Postal Code)

Registrant’s telephone number, including area code: 1-800-567-3776

 

 

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 91 days.

YES      ✓    NO           

The registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

YES      ✓    NO           

The registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer (see the definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act of 1934).

 

Large accelerated filer      ✓		Accelerated filer
Non-accelerated filer		Smaller reporting company

The registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act of 1934).

YES              NO      ✓   

The number of common shares outstanding, as of September 30, 2016 was 847,599,011.

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Table of contents

 

				Page
PART I.		FINANCIAL INFORMATION			3
Item 1.		Financial statements			3
		Consolidated statement of income			3
		Consolidated statement of comprehensive income			4
		Consolidated balance sheet			5
		Consolidated statement of cash flows			6
		Notes to the consolidated financial statements			7
Item 2.		Management’s discussion and analysis of financial condition and results of operations			15
Item 3.		Quantitative and qualitative disclosures about market risk			19
Item 4.		Controls and procedures			19
PART II.		OTHER INFORMATION			20
Item 1.		Legal proceedings			20
Item 2.		Unregistered sales of equity securities and use of proceeds			20
Item 6.		Exhibits			20
SIGNATURES					21

 

 

In this report all dollar amounts are expressed in Canadian dollars unless otherwise stated. This report should be read in conjunction with the company’s annual report on Form 10-K for the year ended December 31, 2015.

The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports.

 

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PART I.  FINANCIAL INFORMATION

Item 1.   Financial statements

 Consolidated statement of income (U.S. GAAP, unaudited)

 

		Third Quarter								Nine Months      to September 30
millions of Canadian dollars		2016				2015				2016				2015
Revenues and other income
Operating revenues (a) (b)			6,568				7,111				17,967				20,553
Investment and other income (note 3)			874				44				945				106
Total revenues and other income			7,442				7,155				18,912				20,659
Expenses
Exploration (note 11)			16				19				75				52
Purchases of crude oil and products (c)			3,857				4,053				10,884				11,653
Production and manufacturing (d)			1,261				1,351				3,842				4,105
Selling and general (d)			275				267				812				803
Federal excise tax (a)			434				416				1,237				1,180
Depreciation and depletion			398				400				1,229				1,052
Financing costs (note 5)			19				12				52				20
Total expenses			6,260				6,518				18,131				18,865
Income (loss) before income taxes			1,182				637				781				1,794
Income taxes			179				158				60				774
Net income (loss)			1,003				479				721				1,020
Per-share information (Canadian dollars)
Net income (loss) per common share - basic (note 8)			1.18				0.56				0.85				1.20
Net income (loss) per common share - diluted (note 8)			1.18				0.56				0.85				1.20
Dividends per common share			0.15				0.14				0.44				0.40
(a)    Federal excise tax included in operating revenues.			434				416				1,237				1,180
(b)    Amounts from related parties included in operating revenues.*			448				856				1,457				2,399
(c)    Amounts to related parties included in purchases of crude oil and products.*			623				663				1,540				2,046
(d)    Amounts to related parties included in production and manufacturing,          and selling and general expenses.			133				106				394				333

*Note: Restated 2015.

The information in the notes to consolidated financial statements is an integral part of these statements.

 

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 Consolidated statement of comprehensive income (U.S. GAAP, unaudited)

 

		Third Quarter								Nine Months    to September 30
millions of Canadian dollars		2016				2015				2016				2015
Net income (loss)			1,003				479				721				1,020
Other comprehensive income (loss), net of income taxes
Post-retirement benefit liability adjustment (excluding amortization)			-				-				100				(176)
Amortization of post-retirement benefit liability adjustment included in net periodic benefit costs			34				42				108				126
Total other comprehensive income (loss)			34				42				208				(50)
Comprehensive income (loss)			1,037				521				929				970

The information in the notes to consolidated financial statements is an integral part of these statements.

 

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 Consolidated balance sheet (U.S. GAAP, unaudited)

 

		As at  Sept 30				As at   Dec 31
millions of Canadian dollars		2016				2015
Assets
Current assets
Cash			248				203
Accounts receivable, less estimated doubtful accounts (a)			1,702				1,581
Inventories of crude oil and products			941				1,190
Materials, supplies and prepaid expenses			547				424
Deferred income tax assets (b)			-				272
Total current assets			3,438				3,670
Long-term receivables, investments and other long-term assets			1,224				1,414
Property, plant and equipment,			53,626				54,203
less accumulated depreciation and depletion			(16,884	)			(16,404)
Property, plant and equipment, net			36,742				37,799
Goodwill			186				224
Other assets, including intangibles, net (b)			60				63
Assets held for sale (note 10)			444				-
Total assets			42,094				43,170
Liabilities
Current liabilities
Notes and loans payable (c)			271				1,952
Accounts payable and accrued liabilities (a) (b) (note 7)			2,898				2,989
Income taxes payable			452				452
Total current liabilities			3,621				5,393
Long-term debt (d) (note 6)			7,039				6,564
Other long-term obligations (e) (note 7)			3,444				3,597
Deferred income tax liabilities (b)			4,008				4,191
Total liabilities			18,112				19,745
Shareholders’ equity
Common shares at stated value (f)			1,566				1,566
Earnings reinvested			24,036				23,687
Accumulated other comprehensive income (loss) (note 9)			(1,620	)			(1,828)
Total shareholders’ equity			23,982				23,425
Total liabilities and shareholders’ equity			42,094				43,170

(a)	Accounts payable and accrued liabilities included amounts payable to related parties of $83 million (2015 - accounts receivable, less estimated doubtful accounts included amounts receivable from related parties of $129 million).

(b)	Deferred tax assets and liabilities have been prospectively classified as non-current. Prior periods were not restated (note 12).

(c)	Notes and loans payable included amounts to related parties of $75 million (2015 - $75 million).

(d)	Long-term debt included amounts to related parties of $6,447 million (2015 - $5,952 million).

(e)	Other long-term obligations included amounts to related parties of $114 million (2015 - $146 million).

(f)	Number of common shares authorized and outstanding were 1,100 million and 848 million, respectively (2015 - 1,100 million and 848 million, respectively).

The information in the notes to consolidated financial statements is an integral part of these statements.

 

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 Consolidated statement of cash flows (U.S. GAAP, unaudited)

 

										Nine Months
Inflow (outflow)		Third Quarter								to September 30
millions of Canadian dollars		2016				2015				2016				2015
Operating activities
Net income (loss)			1,003				479				721				1,020
Adjustments for non-cash items:
Depreciation and depletion			398				400				1,229				1,052
(Gain) loss on asset sales (note 3)			(909	)			(29	)			(952	)			(80	)
Deferred income taxes and other			215				86				35				358
Changes in operating assets and liabilities:
Accounts receivable			275				403				(121	)			(163	)
Inventories, materials, supplies and prepaid expenses			(7	)			(65	)			112				(228	)
Income taxes payable			(13	)			58				-				390
Accounts payable and accrued liabilities			(241	)			(271	)			(59	)			(634	)
All other items - net (a)			51				43				299				47
Cash flows from (used in) operating activities			772				1,104				1,264				1,762
Investing activities
Additions to property, plant and equipment			(189	)			(647	)			(893	)			(2,431	)
Proceeds from asset sales (note 3)			1,194				28				1,244				118
Additional investments			-				-				(1	)			(32	)
Cash flows from (used in) investing activities			1,005				(619	)			350				(2,345	)
Financing activities
Short-term debt - net			(1,591	)			(30	)			(1,679	)			(29	)
Long-term debt issued (note 6)			-				-				495				1,106
Reduction in capitalized lease obligations			(6	)			(7	)			(21	)			(13	)
Dividends paid			(127	)			(110	)			(364	)			(330	)
Cash flows from (used in) financing activities			(1,724	)			(147	)			(1,569	)			734
Increase (decrease) in cash			53				338				45				151
Cash at beginning of period			195				28				203				215
Cash at end of period (b)			248				366				248				366
(a)       Included contribution to registered pension plans.			(44	)			(46	)			(120	)			(178	)

(b)	Cash is composed of cash in bank and cash equivalents at cost. Cash equivalents are all highly liquid securities with the maturity of three months or less when purchased.

 NON-CASH TRANSACTIONS

 In 2015, a capital lease of approximately $480 million was not included in “Additions to property, plant and equipment” or “Long-term debt issued” lines

 on the consolidated statement of cash flows.

 The information in the notes to consolidated financial statements is an integral part of these statements.

 

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Notes to consolidated financial statements (unaudited)

1.  Basis of financial statement preparation

These unaudited consolidated financial statements have been prepared in accordance with Generally Accepted Accounting Principles of the United States of America (GAAP) and follow the same accounting policies and methods of computation as, and should be read in conjunction with, the most recent annual consolidated financial statements filed with the U.S. Securities and Exchange Commission (SEC) in the company’s 2015 annual report on Form 10-K. In the opinion of the company, the information furnished herein reflects all known accruals and adjustments necessary for a fair statement of the results for the periods reported herein. All such adjustments are of a normal recurring nature. The company’s exploration and production activities are accounted for under the “successful efforts” method.

The results for the nine months ended September 30, 2016, are not necessarily indicative of the operations to be expected for the full year.

All amounts are in Canadian dollars unless otherwise indicated.

 

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2. Business segments

 

Third Quarter		Upstream								Downstream								Chemical
millions of Canadian dollars		2016				2015				2016				2015				2016				2015
Revenues and other income
Operating revenues (a)			1,316				1,467				4,971				5,344				281				300
Intersegment sales			709				610				253				239				58				60
Investment and other income			1				4				870				40				1				-
			2,026				2,081				6,094				5,623				340				360
Expenses
Exploration			16				19				-				-				-				-
Purchases of crude oil and products			861				879				3,827				3,906				188				176
Production and manufacturing			887				923				323				377				51				51
Selling and general			(1	)			1				238				256				22				23
Federal excise tax			-				-				434				416				-				-
Depreciation and depletion			346				333				46				61				2				3
Financing costs (note 5)			(2	)			2				-				-				-				-
Total expenses			2,107				2,157				4,868				5,016				263				253
Income (loss) before income taxes			(81	)			(76	)			1,226				607				77				107
Income taxes			(55	)			(24	)			224				153				21				29
Net income (loss)			(26	)			(52	)			1,002				454				56				78
Cash flows from (used in) operating activities			432				696				264				313				73				109
Capital and exploration expenditures (b)			149				1,050				38				55				7				17
Third Quarter		Corporate and Other								Eliminations								Consolidated
millions of Canadian dollars		2016				2015				2016				2015				2016				2015
Revenues and other income
Operating revenues (a)			-				-				-				-				6,568				7,111
Intersegment sales			-				-				(1,020	)			(909	)			-				-
Investment and other income			2				-				-				-				874				44
			2				-				(1,020	)			(909	)			7,442				7,155
Expenses
Exploration			-				-				-				-				16				19
Purchases of crude oil and products			-				-				(1,019	)			(908	)			3,857				4,053
Production and manufacturing			-				-				-				-				1,261				1,351
Selling and general			17				(12	)			(1	)			(1	)			275				267
Federal excise tax			-				-				-				-				434				416
Depreciation and depletion			4				3				-				-				398				400
Financing costs (note 5)			21				10				-				-				19				12
Total expenses			42				1				(1,020	)			(909	)			6,260				6,518
Income (loss) before income taxes			(40	)			(1	)			-				-				1,182				637
Income taxes			(11	)			-				-				-				179				158
Net income (loss)			(29	)			(1	)			-				-				1,003				479
Cash flows from (used in) operating activities			3				(14	)			-				-				772				1,104
Capital and exploration expenditures (b)			11				20				-				-				205				1,142

(a)	Included export sales to the United States of $941 million (2015 - $1,168 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

(b)	Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to capital leases, additional investments and acquisitions.

 

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Nine Months to September 30		Upstream								Downstream								Chemical
millions of Canadian dollars		2016				2015				2016				2015				2016				2015
Revenues and other income
Operating revenues (a)			3,699				4,462				13,470				15,191				798				900
Intersegment sales			1,516				1,926				689				763				156				182
Investment and other income			22				22				919				83				1				-
			5,237				6,410				15,078				16,037				955				1,082
Expenses
Exploration			75				52				-				-				-				-
Purchases of crude oil and products			2,584				2,787				10,139				11,172				518				563
Production and manufacturing			2,634				2,826				1,059				1,125				149				154
Selling and general			(3	)			-				729				720				63				65
Federal excise tax			-				-				1,237				1,180				-				-
Depreciation and depletion			1,053				865				158				169				6				8
Financing costs (note 5)			(6	)			5				-				-				-				-
Total expenses			6,337				6,535				13,322				14,366				736				790
Income (loss) before income taxes			(1,100	)			(125	)			1,756				1,671				219				292
Income taxes			(336	)			290				363				437				59				79
Net income (loss)			(764	)			(415	)			1,393				1,234				160				213
Cash flows from (used in) operating activities			32				181				1,028				1,368				205				269
Capital and exploration expenditures (b)			745				2,644				145				276				21				33
Total assets as at September 30			36,975				36,817				4,403				5,645				379				386
Nine Months to September 30		Corporate and Other								Eliminations								Consolidated
millions of Canadian dollars		2016				2015				2016				2015				2016				2015
Revenues and other income
Operating revenues (a)			-				-				-				-				17,967				20,553
Intersegment sales			-				-				(2,361	)			(2,871	)			-				-
Investment and other income			3				1				-				-				945				106
			3				1				(2,361	)			(2,871	)			18,912				20,659
Expenses
Exploration			-				-				-				-				75				52
Purchases of crude oil and products			-				-				(2,357	)			(2,869	)			10,884				11,653
Production and manufacturing			-				-				-				-				3,842				4,105
Selling and general			27				20				(4	)			(2	)			812				803
Federal excise tax			-				-				-				-				1,237				1,180
Depreciation and depletion			12				10				-				-				1,229				1,052
Financing costs (note 5)			58				15				-				-				52				20
Total expenses			97				45				(2,361	)			(2,871	)			18,131				18,865
Income (loss) before income taxes			(94	)			(44	)			-				-				781				1,794
Income taxes			(26	)			(32	)			-				-				60				774
Net income (loss)			(68	)			(12	)			-				-				721				1,020
Cash flows from (used in) operating activities			(1	)			(56	)			-				-				1,264				1,762
Capital and exploration expenditures (b)			37				58				-				-				948				3,011
Total assets as at September 30			674				777				(337	)			(173	)			42,094				43,452

(a)	Included export sales to the United States of $2,704 million (2015 - $3,331 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

(b)	Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to capital leases, additional investments and acquisitions.

 

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3.  Investment and other income

Investment and other income included gains and losses on asset sales as follows:

 

		Third Quarter								Nine Months     to September 30
millions of Canadian dollars		2016				2015				2016				2015
Proceeds from asset sales			1,194				28				1,244				118
Book value of assets sold (a)			285				(1	)			292				38
Gain (loss) on asset sales, before tax (b)			909				29				952				80
Gain (loss) on asset sales, after tax (b)			774				26				808				65

(a)	Third quarter ended September 30, 2015, included a post close adjustment relating to conventional assets divested in 2014.

(b)

Third quarter and nine months ended September 30, 2016, included gains of $0.8 billion ($0.7 billion, after tax) from the sale of company-owned Esso retail sites in British Columbia, Alberta, Saskatchewan, Manitoba, Ontario, Quebec, Nova Scotia and Newfoundland. The sale and transition of the company’s remaining sites are anticipated to close by year-end 2016 (note 10).

Subsequent to the quarter, on November 1, 2016, the company completed the sale of its general aviation business and converted to an unbranded wholesaler operating model for approximately $177 million, having an approximate net book value of $18 million.

4.  Employee retirement benefits

The components of net benefit cost were as follows:

 

		Third Quarter								Nine Months     to September 30
millions of Canadian dollars		2016				2015				2016				2015
Pension benefits:
Current service cost			50				56				152				158
Interest cost			82				77				240				231
Expected return on plan assets			(101	)			(101	)			(300	)			(294	)
Amortization of prior service cost			2				4				7				12
Amortization of actuarial loss			39				50				121				149
Net benefit cost			72				86				220				256
Other post-retirement benefits:
Current service cost			4				4				12				12
Interest cost			7				7				20				19
Amortization of actuarial loss			3				3				10				9
Net benefit cost			14				14				42				40

5.  Financing costs and additional notes and loans payable information

 

		Third Quarter								Nine Months     to September 30
millions of Canadian dollars		2016				2015				2016				2015
Debt-related interest			32				30				95				73
Capitalized interest			(11	)			(20	)			(37	)			(58	)
Net interest expense			21				10				58				15
Other interest			(2	)			2				(6	)			5
Total financing costs			19				12				52				20

In March 2016, the company extended the maturity date of its existing $500 million 364-day short-term unsecured committed bank credit facility to March 2017. The company has not drawn on the facility.

 

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6.   Long-term debt

millions of Canadian dollars		As at Sept 30 2016				As at  Dec 31  2015
Long-term debt			6,447				5,952
Capital leases			592				612
Total long-term debt			7,039				6,564

In August 2016, the company extended the maturity date of its existing $500 million stand-by long-term bank credit facility to October 31, 2017.

Subsequent to September 30, 2016, in October 2016, the company reduced the amount of its existing $500 million stand-by long-term bank credit facility to $250 million and extended the maturity date to November 30, 2018.

In the nine months ended September 30, 2016, the company increased its long-term debt by $495 million by drawing on an existing facility with an affiliated company of Exxon Mobil Corporation. The increased debt was used to supplement normal operations and capital projects.

In July 2015, the company entered into a long-term capital lease related to the Woodland pipeline for approximately $480 million. A commitment related to this obligation was previously reported as a firm capital commitment in the company’s 2014 Form 10-K.

7.   Other long-term obligations

millions of Canadian dollars		As at Sept 30 2016				As at  Dec 31  2015
Employee retirement benefits (a)			1,255				1,470
Asset retirement obligations and other environmental liabilities (b)			1,682				1,628
Share-based incentive compensation liabilities			154				134
Other obligations			353				365
Total other long-term obligations			3,444				3,597

(a)	Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2015 - $59 million).

(b)	Total asset retirement obligations and other environmental liabilities also included $117 million in current liabilities (2015 - $116 million).

 

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8.   Net income (loss) per-share

		Third Quarter								Nine Months      to September 30
		2016				2015				2016				2015
Net income (loss) per common share - basic
Net income (loss) (millions of Canadian dollars)			1,003				479				721				1,020
Weighted average number of common shares outstanding (millions of shares)			847.6				847.6				847.6				847.6
Net income (loss) per common share (dollars)			1.18				0.56				0.85				1.20
Net income (loss) per common share - diluted
Net income (loss) (millions of Canadian dollars)			1,003				479				721				1,020
Weighted average number of common shares outstanding (millions of shares)			847.6				847.6				847.6				847.6
Effect of share-based awards (millions of shares)			3.2				3.3				3.0				3.1
Weighted average number of common shares outstanding assuming dilution (millions of shares)			850.8				850.9				850.6				850.7
Net income (loss) per common share (dollars)			1.18				0.56				0.85				1.20

9.   Other comprehensive income (loss) information

Changes in accumulated other comprehensive income (loss):

 

millions of Canadian dollars		2016				2015
Balance at January 1			(1,828	)			(2,059)
Post-retirement benefits liability adjustment:
Current period change excluding amounts reclassified from accumulated other comprehensive income			100				(176)
Amounts reclassified from accumulated other comprehensive income			108				126
Balance at September 30			(1,620	)			(2,109)

Amounts reclassified out of accumulated other comprehensive income (loss) - before-tax income (expense):

 

		Third Quarter								Nine Months      to September 30
millions of Canadian dollars		2016				2015				2016				2015
Amortization of post-retirement benefits liability adjustment included in net periodic benefit cost (a)			(44	)			(57	)			(138	)			(170)

(a)	This accumulated other comprehensive income component is included in the computation of net periodic benefit cost (note 4).

Income tax expense (credit) for components of other comprehensive income (loss):

 

		Third Quarter								Nine Months      to September 30
millions of Canadian dollars		2016				2015				2016				2015
Post-retirement benefits liability adjustments:
Post-retirement benefits liability adjustment (excluding amortization)			-				-				37				(61)
Amortization of post-retirement benefits liability adjustment included in net periodic benefit cost			10				15				30				44
Total			10				15				67				(17)

 

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10.  Assets held for sale

On March 8, 2016, the company announced that it had entered into agreements which will result in the sale and transition of its remaining company-owned Esso retail stations to a branded wholesaler operating model for approximately $2.8 billion. Under the branded wholesaler model, Imperial supplies fuel to independent third parties who own and/or operate the sites in alignment with Esso brand standards. The company’s gain on sale, which is subject to final closing adjustments, is anticipated to be in the range of $2.0 billion to $2.1 billion ($1.7 billion to $1.8 billion after tax).

During the third quarter, the company completed the sale of a number of sites in British Columbia, Alberta, Saskatchewan, Manitoba, Ontario, Quebec, Nova Scotia and Newfoundland for approximately $1.2 billion (note 3). Subsequent to the quarter, the company completed the sale of additional sites in British Columbia, Alberta, Ontario and Quebec for approximately $1.6 billion, having an approximate net book value of $0.4 billion. The remaining transactions are anticipated to close by year-end 2016.

The major classes of assets classified as held for sale within the Downstream segment at September 30, 2016, were as follows:

millions of Canadian dollars		As at  Sept 30  2016
Assets held for sale
Accounts receivable and prepaid expenses			3
Inventories			11
Net property, plant and equipment			411
Goodwill			19
Total assets held for sale			444

11.  Accounting for suspended exploratory well costs

For the category of exploratory well costs at year-end 2015 that were capitalized for a period greater than 12 months, a total of $24 million was expensed in the first nine months of 2016.

 

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12. Recently issued accounting standards

In May 2014, the Financial Accounting Standards Board (FASB) issued a new standard, Revenue from Contracts with Customers. The standard establishes a single revenue recognition model for all contracts with customers, eliminates industry specific requirements and expands disclosure requirements. The standard will be adopted beginning January 1, 2018. Imperial continues to evaluate the standard and its effect on the company’s financial statements.

In February 2016, the FASB issued a new standard, Leases. The standard requires all leases with an initial term greater than one year be recorded on the balance sheet as an asset and lease liability. The standard is required to be adopted beginning January 1, 2019. Imperial is evaluating the standard and its effect on the company’s financial statements.

Effective September 30, 2016, Imperial early adopted Accounting Standards Update (ASU) no. 2015-17 Income Taxes (Topic 740): Balance sheet classification of deferred taxes, on a prospective basis. This update eliminates the requirement to classify deferred tax assets and liabilities as current and non-current, and instead requires all deferred tax assets and liabilities to be classified as non-current.

The balance sheet classification of deferred income tax asset / (liability) is shown below.

millions of Canadian dollars		As at Sept 30 2016				As at      Dec 31  2015
Deferred income tax asset			-				272
Other assets, including intangibles, net			35				-
Accounts payable and accrued liabilities			-				(41)
Deferred income tax liabilities			(4,008)				(4,191)
Net deferred tax liabilities			(3,973)				(3,960)

 

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Item 2.

Management’s discussion and analysis of financial condition and results of operations

Operating results

Third quarter 2016 vs. third quarter 2015

The company’s net income for the third quarter of 2016 was $1,003 million or $1.18 per-share on a diluted basis, compared to net income of $479 million or $0.56 per-share for the same period last year. Third quarter 2016 results included a $716 million ($0.84 per-share) gain from the sale of retail sites.

Upstream recorded a net loss in the third quarter of $26 million, compared to a net loss of $52 million in the same period of 2015. Results in the third quarter of 2016 mainly reflect the impact of higher Syncrude volumes of about $90 million and lower operating expenses, partially offset by lower realizations of about $90 million.

West Texas Intermediate (WTI) averaged US$44.94 per barrel in the third quarter of 2016, down from US$46.57 per barrel in the same quarter of 2015. Western Canada Select (WCS) averaged US$31.43 per barrel and US$33.38 per barrel respectively for the same periods. The WTI / WCS differential widened to 30 percent in the third quarter of 2016, from 28 percent in the same period of 2015.

The Canadian dollar averaged US$0.77 in the third quarter of 2016 and was essentially unchanged versus the same period of 2015.

Imperial’s average Canadian dollar realizations for bitumen and synthetic crudes declined essentially in line with the North American benchmarks, adjusted for changes in the exchange rate and transportation costs. Bitumen realizations averaged $30.16 per barrel for the third quarter of 2016, a decrease of $2.45 per barrel versus the third quarter of 2015. Synthetic crude realizations averaged $58.97 per barrel, a decrease of $2.24 per barrel for the same period of 2015.

Gross production of Cold Lake bitumen averaged 157,000 barrels per day in the third quarter, compared to 166,000 barrels in the same period last year. The lower production was mainly due to the timing of steam cycles.

Gross production of Kearl bitumen averaged 159,000 barrels per day in the third quarter (113,000 barrels Imperial’s share) compared to 181,000 barrels per day (128,000 barrels Imperial’s share) during the third quarter of 2015. Lower production was the result of planned and unplanned maintenance activities.

The company’s share of gross production from Syncrude averaged 85,000 barrels per day, up from 59,000 barrels in the third quarter of 2015. Increased production reflects ongoing efforts to improve the reliability of operations.

Downstream net income was $1,002 million in the third quarter, compared to $454 million in the same period of 2015. Earnings increased mainly due to a gain of $716 million from the sale of retail sites, improved refinery operations of $80 million and higher marketing sales volumes of $50 million, partially offset by lower industry margins of about $300 million.

Refinery throughput averaged 407,000 barrels per day, up from 390,000 barrels in the third quarter of 2015. Increased throughput reflects lower maintenance activities than in the same period of 2015.

Petroleum product sales were 505,000 barrels per day, up from 495,000 barrels per day in the third quarter of 2015, with growth concentrated in the higher value commercial and retail channels.

Chemical net income was $56 million in the third quarter, compared to $78 million in the same quarter of 2015.

 

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Net income effects from Corporate and Other were negative $29 million in the third quarter, compared to negative $1 million in the same period of 2015.

Nine months 2016 vs. nine months 2015

Net income in the first nine months of 2016 was $721 million, or $0.85 per-share on a diluted basis, including a gain of $719 million ($0.85 per-share) from the sale of retail sites, versus net income of $1,020 million or $1.20 per-share for the first nine months of 2015.

Upstream recorded a net loss of $764 million for the first nine months of 2016, compared to a net loss of $415 million for the same period last year. The loss in 2016 reflected lower realizations of about $970 million, the impact of the northern Alberta wildfires of about $155 million and higher depreciation expense of about $90 million. These factors were partially offset by higher volumes of about $230 million, the impact of a weaker Canadian dollar of about $130 million, the favourable impact of lower royalties of about $90 million and lower energy cost of about $60 million. Earnings in 2015 reflected the impact associated with the Alberta corporate income tax rate increase of about $327 million.

West Texas Intermediate averaged US$41.54 per barrel in the first nine months of 2016, down from US$51.03 per barrel in the same period last year. Western Canada Select averaged US$27.74 per barrel and US$37.89 per barrel respectively for the same periods. The WTI/WCS differential widened to 33 percent in the first nine months of 2016, up from 26 percent in the same period of 2015.

During the first nine months of 2016, the Canadian dollar weakened relative to the U.S. dollar versus the same period of 2015. The Canadian dollar averaged US$0.76 in the first nine months of 2016, a decrease of almost US$0.04 from the same period of 2015.

Imperial’s average Canadian dollar realizations for bitumen and synthetic crudes declined essentially in line with the North American benchmarks, adjusted for changes in the exchange rate and transportation costs. Bitumen realizations averaged $23.77 (US$18.18) for the first nine months of 2016, a decrease of $12.71 per barrel versus the same period of 2015. Synthetic crude realizations averaged $53.45 (US$40.33) per barrel, a decrease of $9.58 per barrel for the same period of 2015.

Gross production of Cold Lake bitumen averaged 162,000 barrels per day in the first nine months, up from 160,000 barrels from the same period last year. Production from the expansion project offset the impacts from cycle timing.

Gross production of Kearl bitumen averaged 169,000 barrels per day in the first nine months of 2016 (120,000 barrels Imperial’s share) compared to 136,000 barrels per day (96,000 barrels Imperial’s share) for the same period of 2015. The increase was the result of start-up of the expansion project and improved reliability of the initial development.

During the first nine months of 2016, the company’s share of gross production from Syncrude averaged 61,000 barrels per day, consistent with the same period of 2015.

Downstream net income was $1,393 million, up from $1,234 million from the same period of 2015. Earnings increased mainly due to a gain of $719 million from the sale of retail sites, the impact of a weaker Canadian dollar of about $130 million, higher marketing sales volumes of $70 million and lower fuels marketing operating costs of about $50 million, partially offset by lower downstream margins of about $780 million.

Refinery throughput averaged 351,000 barrels per day in the first nine months of 2016, compared to 385,000 barrels in the same period of 2015. Capacity utilization decreased to 83 percent from 92 percent in the same period of 2015, reflecting the more significant scope of turnaround maintenance activity in the current year.

Petroleum product sales were 481,000 barrels per day in the first nine months of 2016, compared to 482,000 barrels per day in the same period of 2015.

Chemical net income was $160 million, compared to $213 million in the same period of 2015.

 

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For the first nine months of 2016, net income effects from Corporate and Other were negative $68 million, versus negative $12 million in 2015, primarily due to lower capitalized interest and the absence of the impact from the Alberta tax rate increase in 2015.

Liquidity and capital resources

Cash flow generated from operating activities was $772 million in the third quarter, compared with $1,104 million in the corresponding period in 2015, reflecting lower earnings, excluding the gain on the sale of retail sites.

Investing activities generated net cash of $1,005 million in the third quarter, compared with cash used in investing activities of $619 million in the same period of 2015, reflecting proceeds from asset sales in 2016 and the completion of major upstream growth projects.

Cash used in financing activities was $1,724 million in the third quarter, compared with $147 million in the third quarter of 2015. Cash from operating activities and proceeds from asset sales were mainly used in the third quarter of 2016 to reduce outstanding short-term debt. Dividends paid in the third quarter of 2016 were $127 million. The per-share dividend paid in the third quarter was $0.15, up from $0.13 in the same period of 2015.

The company’s cash balance was $248 million at September 30, 2016, versus $366 million at the end of the third quarter of 2015.

Cash flow generated from operating activities was $1,264 million in the first nine months of 2016, compared with $1,762 million in the same period of 2015, reflecting lower earnings, excluding the gain on retail sites.

Investing activities generated net cash of $350 million in the first nine months of 2016, compared with cash used in investing activities of $2,345 million in the same period of 2015, reflecting proceeds from asset sales and the completion of major upstream growth projects.

Cash used in financing activities was $1,569 million in the first nine months of 2016, compared with cash provided by financing activities of $734 million in the same period of 2015. Cash from operating activities and proceeds from the asset sales were used to reduce outstanding short-term debt. Dividends paid in the first nine months of 2016 were $364 million. The per-share dividend paid in the first nine months was $0.43, up from $0.39 in the same period of 2015.

Oil and gas reserves

As disclosed in the 2015 Form 10-K, low crude and natural gas prices can impact Imperial’s reserves as reported under the Securities and Exchange Commissions (SEC) rules. Average year-to-date crude prices have been significantly affected by the very low prices experienced during the first quarter of 2016, but have recovered considerably since that time. If the average prices seen during the first nine months of 2016 persist for the remainder of the year, under the SEC definition of proved reserves, certain quantities of oil, such as those associated with all or part of the oil sands operations at Kearl and Cold Lake will not qualify as proved reserves at year-end 2016. Quantities that could be required to be de-booked as proved reserves on an SEC basis amount to approximately 2.6 billion barrels of bitumen at Kearl and approximately 0.4 billion barrels at Cold Lake, and will be determined once the price and costs have been finalized at year-end. Among the factors that would result in these reserves being re-booked as proved reserves at some point in the future are a recovery in average price levels, a further decline in costs, and / or operating efficiencies. Under the terms of government royalty regimes, lower prices can also increase proved reserves attributable to Imperial. The company does not expect the de-booking of reported proved reserves under the SEC definitions to affect the operation of the underlying projects or to alter our outlook for future production volumes.

 

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Impact of oil and gas reserves and prices and margins on testing for impairment

In light of continued weakness in the upstream industry environment during 2016, and as part of Imperial’s annual planning and budgeting process which is currently in progress, the company will perform an assessment of its major long-lived assets, similar to the exercise undertaken in late 2015. The assessment reflects crude and natural gas price outlooks consistent with those that management uses to evaluate investment opportunities and generally consistent with the long-term price forecasts published by third-party industry and government experts. Development of future undiscounted cash flow estimates requires significant management judgement, particularly in cases where an asset’s life is expected to extend decades into the future. An asset group would be impaired if its estimated undiscounted cash flows were less than the asset’s carrying value, and impairment would be measured by the amount by which the carrying value exceeds fair value. Imperial will complete its asset recoverability assessment and analyze the conclusions of that assessment in connection with the preparation and review of the company’s year-end financial statements for inclusion in its 2016 Form 10-K. Until these activities are complete, it is not practicable to reasonably estimate the existence or range of potential future impairments related to the company’s long-lived assets.

Recently issued accounting standards

In May 2014, the Financial Accounting Standards Board (FASB) issued a new standard, Revenue from Contracts with Customers. The standard establishes a single revenue recognition model for all contracts with customers, eliminates industry specific requirements and expands disclosure requirements. The standard will be adopted beginning January 1, 2018. Imperial continues to evaluate the standard and its effect on the company’s financial statements.

In February 2016, the FASB issued a new standard, Leases. The standard requires all leases with an initial term greater than one year be recorded on the balance sheet as an asset and lease liability. The standard is required to be adopted beginning January 1, 2019. Imperial is evaluating the standard and its effect on the company’s financial statements.

Effective September 30, 2016, Imperial early adopted Accounting Standards Update (ASU) no. 2015-17 Income Taxes (Topic 740): Balance sheet classification of deferred taxes, on a prospective basis. This update eliminates the requirement to classify deferred tax assets and liabilities as current and non-current, and instead requires all deferred tax assets and liabilities to be classified as non-current.

The balance sheet classification of deferred income tax asset / (liability) is shown below.

 

millions of Canadian dollars		As at Sept 30 2016				As at Dec 31 2015
Deferred income tax asset			-				272
Other assets, including intangibles, net			35				-
Accounts payable and accrued liabilities			-				(41)
Deferred income tax liabilities			(4,008)				(4,191)
Net deferred tax liabilities			(3,973)				(3,960)

Forward-looking statements

Statements in this report regarding future events or conditions are forward-looking statements. Actual future financial and operating results could differ materially due to the impact of market conditions, changes in law or governmental policy, changes in operating conditions and costs, changes in project schedules, operating performance, demand for oil and gas, commercial negotiations or other technical and economic factors.

 

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Item 3.  Quantitative and qualitative disclosures about market risk

Information about market risks for the nine months ended September 30, 2016, does not differ materially from that discussed on page 22 of the company’s annual report on Form 10-K for the year ended December 31, 2015 and Form 10-Q for the quarters ended March 31, 2016 and June 30, 2016.

Reference is made to Item 2. Management’s discussion and analysis of financial condition and results of operations, sections entitled Oil and gas reserves and Impact of oil and gas reserves and prices and margins on testing for impairment, for discussion on the risks associated with the current pricing environment.

Item 4.  Controls and procedures

As indicated in the certifications in Exhibit 31 of this report, the company’s principal executive officer and principal financial officer have evaluated the company’s disclosure controls and procedures as of September 30, 2016. Based on that evaluation, these officers have concluded that the company’s disclosure controls and procedures are effective in ensuring that information required to be disclosed by the company in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is accumulated and communicated to them in a manner that allows for timely decisions regarding required disclosures and are effective in ensuring that such information is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms.

There has not been any change in the company’s internal control over financial reporting during the last fiscal quarter that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting.

 

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PART II.  OTHER INFORMATION

Item 1.  Legal proceedings

On September 19, 2016, Imperial entered a guilty plea with respect to a charge involving the discharging or causing or permitting the discharge of a contaminant, namely coker stabilizer thermocracked gas, from Imperial’s chemical plant in Sarnia, into the natural environment that caused or was likely to have caused an adverse effect contrary to section 14(1) of the Environmental Protection Act, R.S.O. 1990, c. E.19, as amended, which offence was alleged to have occurred on February 7, 2014. Imperial agreed to pay $650,000 plus a 25 percent victim fine surcharge.

Item 2.  Unregistered sales of equity securities and use of proceeds

Issuer purchases of equity securities

 

		Total number of   shares purchased		Average price       paid per share       (dollars)		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 (a)
July 2016 (July 1 – July 31)		-		-		-		1,000,000
August 2016 (Aug 1 – Aug 31)		-		-		-		1,000,000
September 2016 (Sept 1 – Sept 30)		-		-		-		1,000,000

(a)

On June 22, 2016, the company announced by news release that it had received final approval from the Toronto Stock Exchange for a new normal course issuer bid and will continue its share repurchase program. The new program enables the company to repurchase up to a maximum of 1,000,000 common shares during the period June 27, 2016 to June 26, 2017. The program will end when the company has purchased the maximum allowable number of shares, or on June 26, 2017.

The company will continue to evaluate its share repurchase program in the context of its overall capital activities.

Item 6.     Exhibits

(31.1) Certification by the principal executive officer of the company pursuant to Rule 13a-14(a).

(31.2) Certification by the principal financial officer of the company pursuant to Rule 13a-14(a).

(32.1) Certification by the chief executive officer of the company pursuant to Rule 13a-14(b) and 18 U.S.C. Section 1350.

(32.2) Certification by the chief financial officer of the company pursuant to Rule 13a-14(b) and 18 U.S.C. Section 1350.

 

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SIGNATURES

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

 

				Imperial Oil Limited
				(Registrant)
				/s/ Beverley A. Babcock
Date:    November 1, 2016				-------------------------------------------------
				(Signature)
				Beverley A. Babcock
				Senior Vice-President, Finance and Administration and Controller
				(Principal Accounting Officer)
				/s/ Cathryn Walker
Date:    November 1, 2016				-------------------------------------------------
				(Signature)
				Cathryn Walker
				Assistant Corporate Secretary

 

 

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