Edgar Filing: EXXON MOBIL CORP

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2018

☐ 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 1-2256

EXXON MOBIL CORPORATION

(Exact name of registrant as specified in its charter)

NEW JERSEY		13-5409005
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification Number)

5959 LAS COLINAS BOULEVARD, IRVING, TEXAS 75039-2298

(Address of principal executive offices) (Zip Code)

(972) 940-6000

(Registrant's telephone number, including area code)

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

Indicate by check mark whether the registrant has submitted electronically 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 ☐

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

Large accelerated filer

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date.

Class		Outstanding as of September 30, 2018
Common stock, without par value		4,233,807,170

EXXON MOBIL CORPORATION

FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2018

TABLE OF CONTENTS

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements
Condensed Consolidated Statement of Income Three and nine months ended September 30, 2018 and 2017	3
Condensed Consolidated Statement of Comprehensive Income Three and nine months ended September 30, 2018 and 2017	4
Condensed Consolidated Balance Sheet As of September 30, 2018 and December 31, 2017	5

Condensed Consolidated Statement of Cash Flows Nine months ended September 30, 2018 and 2017	6
Condensed Consolidated Statement of Changes in Equity Nine months ended September 30, 2018 and 2017	7
Notes to Condensed Consolidated Financial Statements	8
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	16
Item 3. Quantitative and Qualitative Disclosures About Market Risk	24
Item 4. Controls and Procedures	24

PART II. OTHER INFORMATION
Item 1. Legal Proceedings	25
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	26
Item 6. Exhibits	26
Index to Exhibits	27
Signature	28

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

EXXON MOBIL CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF INCOME
(millions of dollars)

			Three Months Ended		Nine Months Ended
			September 30,		September 30,
			2018	2017	2018	2017
Revenues and other income
	Sales and other operating revenue		74,187	59,350	211,079	171,850
	Income from equity affiliates		1,960	1,472	5,599	4,707
	Other income		458	278	1,639	1,291
		Total revenues and other income	76,605	61,100	218,317	177,848
Costs and other deductions
	Crude oil and product purchases		41,776	31,432	119,391	91,985
	Production and manufacturing expenses		9,097	7,952	26,506	23,578
	Selling, general and administrative expenses		2,892	2,632	8,632	7,693
	Depreciation and depletion		4,658	4,880	13,717	14,051
	Exploration expenses, including dry holes		292	284	911	1,087
	Non-service pension and postretirement benefit expense		307	475	952	1,267
	Interest expense		200	111	551	415
	Other taxes and duties		8,303	7,751	24,825	22,115
		Total costs and other deductions	67,525	55,517	195,485	162,191
Income before income taxes			9,080	5,583	22,832	15,657
	Income taxes		2,634	1,498	7,617	4,218
Net income including noncontrolling interests			6,446	4,085	15,215	11,439
	Net income attributable to noncontrolling interests		206	115	375	109
Net income attributable to ExxonMobil			6,240	3,970	14,840	11,330


Earnings per common share (dollars)			1.46	0.93	3.47	2.66

Earnings per common share - assuming dilution (dollars)			1.46	0.93	3.47	2.66

The information in the Notes to Condensed Consolidated Financial Statements is an integral part of these statements.

EXXON MOBIL CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(millions of dollars)

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

Net income including noncontrolling interests				6,446	4,085	15,215	11,439
Other comprehensive income (net of income taxes)
	Foreign exchange translation adjustment			124	2,342	(2,720)	5,424
	Adjustment for foreign exchange translation (gain)/loss
			included in net income	-	-	186	234
	Postretirement benefits reserves adjustment
			(excluding amortization)	(3)	(145)	(394)	(329)
	Amortization and settlement of postretirement benefits reserves
			adjustment included in net periodic benefit costs	223	311	689	850
		Total other comprehensive income		344	2,508	(2,239)	6,179
Comprehensive income including noncontrolling interests				6,790	6,593	12,976	17,618
	Comprehensive income attributable to
			noncontrolling interests	311	372	205	700
Comprehensive income attributable to ExxonMobil				6,479	6,221	12,771	16,918

The information in the Notes to Condensed Consolidated Financial Statements is an integral part of these statements.

EXXON MOBIL CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEET
(millions of dollars)

				Sept. 30,	Dec. 31,
				2018	2017
Assets
	Current assets
		Cash and cash equivalents		5,669	3,177
		Notes and accounts receivable – net		27,880	25,597
		Inventories
			Crude oil, products and merchandise	14,617	12,871
			Materials and supplies	4,144	4,121
		Other current assets		1,665	1,368
			Total current assets	53,975	47,134
	Investments, advances and long-term receivables			40,427	39,160
	Property, plant and equipment – net			249,153	252,630
	Other assets, including intangibles – net			11,073	9,767
			Total assets	354,628	348,691

Liabilities
	Current liabilities
		Notes and loans payable		19,413	17,930
		Accounts payable and accrued liabilities		41,714	36,796
		Income taxes payable		4,161	3,045
			Total current liabilities	65,288	57,771
	Long-term debt			20,624	24,406
	Postretirement benefits reserves			21,448	21,132
	Deferred income tax liabilities			27,084	26,893
	Long-term obligations to equity companies			4,625	4,774
	Other long-term obligations			18,728	19,215
			Total liabilities	157,797	154,191

Commitments and contingencies (Note 3)

Equity
	Common stock without par value
		(9,000 million shares authorized, 8,019 million shares issued)		15,254	14,656
	Earnings reinvested			419,155	414,540
	Accumulated other comprehensive income			(18,370)	(16,262)
	Common stock held in treasury
		(3,785 million shares at September 30, 2018 and
		3,780 million shares at December 31, 2017)		(225,674)	(225,246)
			ExxonMobil share of equity	190,365	187,688
	Noncontrolling interests			6,466	6,812
			Total equity	196,831	194,500
			Total liabilities and equity	354,628	348,691

The information in the Notes to Condensed Consolidated Financial Statements is an integral part of these statements.

EXXON MOBIL CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
(millions of dollars)

				Nine Months Ended
				September 30,
				2018	2017
Cash flows from operating activities
	Net income including noncontrolling interests			15,215	11,439
	Depreciation and depletion			13,717	14,051
	Changes in operational working capital, excluding cash and debt			(25)	(547)
	All other items – net			(1,500)	(2,288)
			Net cash provided by operating activities	27,407	22,655

Cash flows from investing activities
	Additions to property, plant and equipment			(13,480)	(10,901)
	Proceeds associated with sales of subsidiaries, property, plant and
		equipment, and sales and returns of investments		3,239	1,695
	Additional investments and advances			(1,113)	(1,950)
	Other investing activities including collection of advances			492	1,962
			Net cash used in investing activities	(10,862)	(9,194)

Cash flows from financing activities
	Additions to long-term debt			-	60
	Additions to short-term debt			-	1,735
	Reductions in short-term debt			(4,279)	(4,971)
	Additions/(reductions) in commercial paper, and debt with three
		months or less maturity (1)		1,626	339
	Cash dividends to ExxonMobil shareholders			(10,296)	(9,712)
	Cash dividends to noncontrolling interests			(192)	(139)
	Changes in noncontrolling interests			(374)	(90)
	Common stock acquired			(430)	(515)
			Net cash used in financing activities	(13,945)	(13,293)
Effects of exchange rate changes on cash				(108)	441
Increase/(decrease) in cash and cash equivalents				2,492	609
Cash and cash equivalents at beginning of period				3,177	3,657
Cash and cash equivalents at end of period				5,669	4,266

Supplemental Disclosures
	Income taxes paid			6,740	4,611
	Cash interest paid			839	965

2017 Noncash Transactions

In the first nine months of 2017, the Corporation completed the acquisitions of InterOil Corporation and of companies that own certain oil and gas properties in the Permian Basin and other assets. These transactions included a significant noncash component associated with the issuance of a combined 96 million shares of Exxon Mobil Corporation common stock in acquisition consideration.

(1) Includes a net addition of commercial paper with a maturity of over three months of $0.3 billion in 2018 and a net reduction of $0.5 billion in 2017. The gross amount of commercial paper with a maturity of over three months issued was $3.1 billion in 2018 and $2.7 billion in 2017, while the gross amount repaid was $2.8 billion in 2018 and $3.2 billion in 2017.

The information in the Notes to Condensed Consolidated Financial Statements is an integral part of these statements.

	EXXON MOBIL CORPORATION
	CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
	(millions of dollars)

			ExxonMobil Share of Equity
							Accumulated
								Other		Common
								Compre-		Stock		ExxonMobil		Non-
			Common		Earnings			hensive		Held in		Share of		controlling		Total
			Stock		Reinvested			Income		Treasury		Equity		Interests		Equity

Balance as of December 31, 2016				12,157		407,831			(22,239)		(230,424)		167,325		6,505		173,830
	Amortization of stock-based awards			635		-			-		-		635		-		635
	Other			(87)		-			-		-		(87)		(54)		(141)
	Net income for the period			-		11,330			-		-		11,330		109		11,439
	Dividends - common shares			-		(9,712)			-		-		(9,712)		(139)		(9,851)
	Other comprehensive income			-		-			5,588		-		5,588		591		6,179
	Acquisitions, at cost			-		-			-		(596)		(596)		(90)		(686)
	Issued for acquisitions			2,078		-			-		5,711		7,789		-		7,789
	Dispositions			-		-			-		4		4		-		4
Balance as of September 30, 2017				14,783		409,449			(16,651)		(225,305)		182,276		6,922		189,198

Balance as of December 31, 2017				14,656		414,540			(16,262)		(225,246)		187,688		6,812		194,500
	Amortization of stock-based awards			605		-			-		-		605		-		605
	Other			(7)		-			-		-		(7)		(8)		(15)
	Net income for the period			-		14,840			-		-		14,840		375		15,215
	Dividends - common shares			-		(10,296)			-		-		(10,296)		(192)		(10,488)
	Cumulative effect of accounting
		change		-		71			(39)		-		32		15		47
	Other comprehensive income			-		-			(2,069)		-		(2,069)		(170)		(2,239)
	Acquisitions, at cost			-		-			-		(430)		(430)		(366)		(796)
	Dispositions			-		-			-		2		2		-		2
Balance as of September 30, 2018				15,254		419,155			(18,370)		(225,674)		190,365		6,466		196,831



			Nine Months Ended September 30, 2018									Nine Months Ended September 30, 2017
					Held in									Held in
	Common Stock Share Activity		Issued		Treasury			Outstanding				Issued		Treasury		Outstanding
			(millions of shares)									(millions of shares)

	Balance as of December 31			8,019		(3,780)			4,239				8,019		(3,871)		4,148
		Acquisitions		-		(5)			(5)				-		(7)		(7)
		Issued for acquisitions		-		-			-				-		96		96
		Dispositions		-		-			-				-		-		-
	Balance as of September 30			8,019		(3,785)			4,234				8,019		(3,782)		4,237

The information in the Notes to Condensed Consolidated Financial Statements is an integral part of these statements.

EXXON MOBIL CORPORATION

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Basis of Financial Statement Preparation

These unaudited condensed consolidated financial statements should be read in the context of the consolidated financial statements and notes thereto filed with the Securities and Exchange Commission in the Corporation's 2017 Annual Report on Form 10-K. In the opinion of the Corporation, 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. Prior data has been reclassified in certain cases to conform to the current presentation basis.

The Corporation's exploration and production activities are accounted for under the "successful efforts" method.

2. Accounting Changes

Effective January 1, 2018, ExxonMobil adopted the Financial Accounting Standards Board’s standard, Revenue from Contracts with Customers (Topic 606), as amended. The standard establishes a single revenue recognition model for all contracts with customers, eliminates industry and transaction specific requirements, and expands disclosure requirements. The standard was adopted using the Modified Retrospective method, under which prior year results are not restated, but supplemental information is provided for any material impacts of the standard on 2018 results. The adoption of the standard did not have a material impact on any of the lines reported in the Corporation’s financial statements. The cumulative effect of adoption of the standard was de minimis. The Corporation did not elect any practical expedients that require disclosure. See Note 9.

Effective January 1, 2018, ExxonMobil adopted the Financial Accounting Standards Board’s Update, Financial Instruments – Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities. The standard requires investments in equity securities other than consolidated subsidiaries and equity method investments to be measured at fair value with changes in the fair value recognized through net income. The Corporation elected a modified approach for equity securities that do not have a readily determinable fair value. This modified approach measures investments at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. The cumulative effect adjustment related to the adoption of this standard increased equity $47 million. The portion of unrealized gains and losses recognized during the reporting period on equity securities still held at September 30, 2018 and the carrying value of equity securities without readily determinable fair values at September 30, 2018 were not significant to the Corporation. The standard also expanded disclosures related to financial instruments. See Note 7.

Effective January 1, 2018, ExxonMobil adopted the Financial Accounting Standards Board’s Update, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The update requires separate presentation of the service cost component from other components of net benefit costs. The other components are reported in a new line on the Corporation’s Statement of Income, “Non-service pension and postretirement benefit expense.” The Corporation elected to use the practical expedient which uses the amounts disclosed in the pension and other postretirement benefit plan note for the prior comparative periods as the estimation basis for applying the retrospective presentation requirements, as it is impracticable to determine the amounts capitalized in those periods. Beginning in 2018, the other components of net benefit costs are included in the Corporate and financing segment. The estimated after-tax impact from the change in segmentation is an increase in Corporate and financing expenses of about $100 million for the third quarter and $300 million for the first nine months of 2018. The increase in the Corporate and financing expenses is offset by lower expenses across the operating segments. Additionally, only the service cost component of net benefit costs is eligible for capitalization in situations where it is otherwise appropriate to capitalize employee costs in connection with the construction or production of an asset.

The impact of the retrospective presentation change on ExxonMobil's Consolidated Statement of Income for the three months and nine months ended September 30, 2017, is shown below.

	Three Months Ended			Nine Months Ended
	September 30, 2017			September 30, 2017
	As Reported	Change	As Adjusted	As Reported	Change	As Adjusted
	(millions of dollars)

Production and manufacturing expenses	8,334	(382)	7,952	24,586	(1,008)	23,578
Selling, general and administrative expenses	2,725	(93)	2,632	7,952	(259)	7,693
Non-service pension and postretirement benefit expense	-	475	475	-	1,267	1,267

Effective January 1, 2019, ExxonMobil will adopt the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. The standard requires all leases with an initial term greater than one year to be recorded on the balance sheet as a right of use asset and a lease liability. We expect to use a transition method that applies the new lease standard at January 1, 2019, and recognizes any cumulative-effect adjustments to the opening balance of 2019 retained earnings.

The Corporation acquired lease accounting software to facilitate implementation, and is currently configuring and testing the software. Based on leases outstanding at the end of 2017, the Corporation estimates the operating lease right of use asset and lease liability would have been in the range of $4 billion to $5 billion at that time. The effect on the Corporation’s balance sheet as a result of implementing the standard on January 1, 2019, could differ considerably depending on operating leases commenced in 2018 as well as interest rates and other factors such as the expiry or renewal of leases during the year.

3. Litigation and Other Contingencies

Litigation

A variety of claims have been made against ExxonMobil and certain of its consolidated subsidiaries in a number of pending lawsuits. Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The Corporation accrues an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Corporation does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and which are significant, the Corporation discloses the nature of the contingency and, where feasible, an estimate of the possible loss. For purposes of our contingency disclosures, “significant” includes material matters, as well as other matters which management believes should be disclosed. ExxonMobil will continue to defend itself vigorously in these matters. Based on a consideration of all relevant facts and circumstances, the Corporation does not believe the ultimate outcome of any currently pending lawsuit against ExxonMobil will have a material adverse effect upon the Corporation's operations, financial condition, or financial statements taken as a whole.

Other Contingencies

The Corporation and certain of its consolidated subsidiaries were contingently liable at September 30, 2018, for guarantees relating to notes, loans and performance under contracts. Where guarantees for environmental remediation and other similar matters do not include a stated cap, the amounts reflect management’s estimate of the maximum potential exposure. These guarantees are not reasonably likely to have a material effect on the Corporation’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

As of September 30, 2018

Equity

Other

Company

Third Party

Obligations (1)

Obligations

Total

(millions of dollars)

Guarantees

Debt-related

461

524

Other

1,008

4,046

5,054

Total

1,469

4,109

5,578

(1) ExxonMobil share

Additionally, the Corporation and its affiliates have numerous long-term sales and purchase commitments in their various business activities, all of which are expected to be fulfilled with no adverse consequences material to the Corporation’s operations or financial condition.

The operations and earnings of the Corporation and its affiliates throughout the world have been, and may in the future be, affected from time to time in varying degree by political developments and laws and regulations, such as forced divestiture of assets; restrictions on production, imports and exports; price controls; tax increases and retroactive tax claims; expropriation of property; cancellation of contract rights and environmental regulations. Both the likelihood of such occurrences and their overall effect upon the Corporation vary greatly from country to country and are not predictable.

In accordance with a Venezuelan nationalization decree issued in February 2007, a subsidiary of the Venezuelan National Oil Company (PdVSA) assumed the operatorship of the Cerro Negro Heavy Oil Project. The decree also required conversion of the Cerro Negro Project into a “mixed enterprise” and an increase in PdVSA’s or one of its affiliate’s ownership interest in the Project. ExxonMobil refused to accede to the terms proffered by the government, and on June 27, 2007, the government expropriated ExxonMobil’s 41.67 percent interest in the Cerro Negro Project.

ExxonMobil collected awards of $908 million in an arbitration against PdVSA under the rules of the International Chamber of Commerce in respect of an indemnity related to the Cerro Negro Project and $260 million in an arbitration for compensation due for the La Ceiba Project and for export curtailments at the Cerro Negro Project under rules of International Centre for Settlement of Investment Disputes (ICSID). An ICSID arbitration award relating to the Cerro Negro Project’s expropriation ($1.4 billion) was annulled based on a determination that a prior Tribunal failed to adequately explain why the cap on damages in the indemnity owed by PdVSA did not affect or limit the amount owed for the expropriation of the Cerro Negro Project. ExxonMobil filed a new claim seeking to restore the original award of damages for the Cerro Negro Project with ICSID on September 26, 2018.

The net impact of this matter on the Corporation’s consolidated financial results cannot be reasonably estimated. Regardless, the Corporation does not expect the resolution to have a material effect upon the Corporation’s operations or financial condition.

An affiliate of ExxonMobil is one of the Contractors under a Production Sharing Contract (PSC) with the Nigerian National Petroleum Corporation (NNPC) covering the Erha block located in the offshore waters of Nigeria. ExxonMobil's affiliate is the operator of the block and owns a 56.25 percent interest under the PSC. The Contractors are in dispute with NNPC regarding NNPC's lifting of crude oil in excess of its entitlement under the terms of the PSC. In accordance with the terms of the PSC, the Contractors initiated arbitration in Abuja, Nigeria, under the Nigerian Arbitration and Conciliation Act. On October 24, 2011, a three-member arbitral Tribunal issued an award upholding the Contractors' position in all material respects and awarding damages to the Contractors jointly in an amount of approximately $1.8 billion plus $234 million in accrued interest. The Contractors petitioned a Nigerian federal court for enforcement of the award, and NNPC petitioned the same court to have the award set aside. On May 22, 2012, the court set aside the award. The Contractors appealed that judgment to the Court of Appeal, Abuja Judicial Division. On July 22, 2016, the Court of Appeal upheld the decision of the lower court setting aside the award. On October 21, 2016, the Contractors appealed the decision to the Supreme Court of Nigeria. In June 2013, the Contractors filed a lawsuit against NNPC in the Nigerian federal high court in order to preserve their ability to seek enforcement of the PSC in the courts if necessary. Following dismissal by this court, the Contractors appealed to the Nigerian Court of Appeal in June 2016. In October 2014, the Contractors filed suit in the United States District Court for the Southern District of New York to enforce, if necessary, the arbitration award against NNPC assets residing within that jurisdiction. NNPC has moved to dismiss the lawsuit. At this time, the net impact of this matter on the Corporation's consolidated financial results cannot be reasonably estimated. However, regardless of the outcome of enforcement proceedings, the Corporation does not expect the proceedings to have a material effect upon the Corporation's operations or financial condition.

4. Other Comprehensive Income Information

		Cumulative	Post-
		Foreign	retirement
		Exchange	Benefits
ExxonMobil Share of Accumulated Other		Translation	Reserves
Comprehensive Income		Adjustment	Adjustment	Total
		(millions of dollars)

Balance as of December 31, 2016		(14,501)	(7,738)	(22,239)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	4,925	(300)	4,625
Amounts reclassified from accumulated other
	comprehensive income	140	823	963
Total change in accumulated other comprehensive income		5,065	523	5,588
Balance as of September 30, 2017		(9,436)	(7,215)	(16,651)

Balance as of December 31, 2017		(9,482)	(6,780)	(16,262)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	(2,551)	(406)	(2,957)
Amounts reclassified from accumulated other
	comprehensive income	186	663	849
Total change in accumulated other comprehensive income		(2,365)	257	(2,108)
Balance as of September 30, 2018		(11,847)	(6,523)	(18,370)

Three Months Ended

Nine Months Ended

Amounts Reclassified Out of Accumulated Other

September 30,

Comprehensive Income - Before-tax Income/(Expense)

2018

2017

2018

2017

(millions of dollars)

Foreign exchange translation gain/(loss) included in net income

(Statement of Income line: Other income)

(186)

(234)

Amortization and settlement of postretirement benefits reserves

adjustment included in net periodic benefit costs

(Statement of Income Line: Non-service pension and

postretirement benefit expense)

(287)

(450)

(897)

(1,215)

			Three Months Ended		Nine Months Ended
Income Tax (Expense)/Credit For			September 30,		September 30,
Components of Other Comprehensive Income			2018	2017	2018	2017
		(millions of dollars)

Foreign exchange translation adjustment			8	17	13	(9)
Postretirement benefits reserves adjustment
	(excluding amortization)		-	74	66	154
Amortization and settlement of postretirement benefits reserves
	adjustment included in net periodic benefit costs		(64)	(139)	(208)	(365)
Total			(56)	(48)	(129)	(220)

5. Earnings Per Share

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

Earnings per common share
Net income attributable to ExxonMobil (millions of dollars)		6,240	3,970	14,840	11,330

Weighted average number of common shares
	outstanding (millions of shares)	4,271	4,271	4,271	4,252

Earnings per common share (dollars) (1)		1.46	0.93	3.47	2.66

Dividends paid per common share (dollars)		0.82	0.77	2.41	2.29

(1) The calculation of earnings per common share and earnings per common share – assuming dilution are the same in each period shown.

6. Pension and Other Postretirement Benefits

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

				(millions of dollars)
Components of net benefit cost
	Pension Benefits - U.S.
		Service cost			203	200	616	583
		Interest cost			179	199	540	598
		Expected return on plan assets			(182)	(194)	(545)	(582)
		Amortization of actuarial loss/(gain) and prior
			service cost		93	110	276	332
		Net pension enhancement and
			curtailment/settlement cost		63	187	189	450
		Net benefit cost			356	502	1,076	1,381

	Pension Benefits - Non-U.S.
		Service cost			149	155	461	445
		Interest cost			185	198	571	574
		Expected return on plan assets			(233)	(260)	(722)	(743)
		Amortization of actuarial loss/(gain) and prior
			service cost		113	135	344	388
		Net pension enhancement and
			curtailment/settlement cost		-	-	33	(5)
		Net benefit cost			214	228	687	659

	Other Postretirement Benefits
		Service cost			40	36	111	92
		Interest cost			75	88	226	227
		Expected return on plan assets			(5)	(6)	(17)	(17)
		Amortization of actuarial loss/(gain) and prior
			service cost		19	18	57	45
		Net benefit cost			129	136	377	347

7. Financial Instruments and Derivatives

Financial Instruments. Effective January 1, 2018, ExxonMobil adopted the Financial Accounting Standards Board’s Update, Financial Instruments—Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities. The estimated fair value of financial instruments at September 30, 2018, and the related hierarchy level for the fair value measurement is as follows:

			At September 30, 2018
			(millions of dollars)

			Carrying	Fair Value
			Value	Level 1	Level 2	Level 3	Total
Assets
	Derivative assets (included in the Balance Sheet line: Other
		current assets)	104	104	-	-	104
	Advances to/receivables from equity companies (included in
		the Balance Sheet line: Investments, advances and
		long-term receivables)	8,969	-	1,763	7,072	8,835
	Other long-term financial assets (included in the Balance
		Sheet lines: Investments, advances and long-term receivables
		and Other assets, including intangibles – net)	1,748	764	-	1,041	1,805

Liabilities
	Derivative liabilities (included in the Balance Sheet line:
		Accounts payable and accrued liabilities)	248	248	-	-	248
	Long-term debt (excluding capitalized lease obligations)		19,275	19,020	110	4	19,134
	Long-term obligations to equity companies		4,625	-	-	4,728	4,728
	Other long-term financial liabilities (included in the
		Balance Sheet line: Other long-term obligations)	1,114	-	-	1,121	1,121

Derivative Instruments. The Corporation’s size, strong capital structure, geographic diversity and the complementary nature of the Upstream, Downstream and Chemical businesses reduce the Corporation’s enterprise-wide risk from changes in interest rates, currency rates and commodity prices. In addition, the Corporation uses commodity-based contracts, including derivatives, to manage commodity price risk and for trading purposes. Credit risk associated with the Corporation’s derivative position is mitigated by several factors, including the use of derivative clearing exchanges and the quality of and financial limits placed on derivative counterparties. The Corporation believes that there are no material market or credit risks to the Corporation’s financial position, results of operations or liquidity as a result of the derivatives. The Corporation maintains a system of controls that includes the authorization, reporting and monitoring of derivative activity. Derivative instruments are currently not subject to a master netting agreement, and the Corporation has not offset collateral against the carrying value. The carrying value of derivative instruments, none of which are designated as hedging instruments, is as follows :

			Sept. 30,	Dec. 31,
			2018	2017
			(millions of dollars)
Exchange Traded Futures and Swaps
	Assets		104	25
	Liabilities		(248)	(63)
	Collateral receivable/(payable)		272	94
		Total	128	56

At September 30, 2018, the net notional long/(short) position of derivative instruments was (16) million barrels for crude oil and was (11) million barrels for products.

Realized and unrealized gains/(losses) on derivative instruments that were recognized in the Consolidated Statement of Income are included in the following lines on a before-tax basis:

		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2018	2017	2018	2017
		(millions of dollars)

Sales and other operating revenue		(68)	(11)	(72)	16
Crude oil and product purchases		(107)	(80)	(380)	(37)
	Total	(175)	(91)	(452)	(21)

8. Disclosures about Segments and Related Information

				Three Months Ended		Nine Months Ended
				September 30,		September 30,
				2018	2017	2018	2017
Earnings After Income Tax			(millions of dollars)
	Upstream
		United States		606	(238)	1,474	(439)
		Non-U.S.		3,623	1,805	9,292	5,442
	Downstream
		United States		961	391	1,975	1,030
		Non-U.S.		681	1,141	1,331	3,003
	Chemical
		United States		404	403	1,360	1,413
		Non-U.S.		309	689	1,254	1,835
	Corporate and financing (1)			(344)	(221)	(1,846)	(954)
	Corporate total			6,240	3,970	14,840	11,330

Sales and Other Operating Revenue
	Upstream
		United States		2,728	2,282	7,637	6,955
		Non-U.S.		4,129	3,633	11,344	10,586
	Downstream
		United States		19,963	15,423	56,616	44,533
		Non-U.S.		39,077	30,955	110,855	88,866
	Chemical
		United States		3,152	2,589	9,160	8,118
		Non-U.S.		5,125	4,455	15,429	12,751
	Corporate and financing			13	13	38	41
	Corporate total			74,187	59,350	211,079	171,850

Intersegment Revenue
	Upstream
		United States		2,203	1,365	6,336	3,937
		Non-U.S.		8,536	5,734	22,788	16,356
	Downstream
		United States		5,834	3,134	16,527	10,621
		Non-U.S.		8,275	5,866	22,975	16,048
	Chemical
		United States		2,408	1,675	6,952	5,290
		Non-U.S.		1,841	1,482	5,657	3,776
	Corporate and financing			54	51	153	154

(1) See Note 2 for additional details regarding the change in segmentation of Non-service pension and postretirement benefit expense.

Geographic
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
Sales and Other Operating Revenue		2018	2017	2018	2017
		(millions of dollars)

United States		25,843	20,294	73,413	59,606
Non-U.S.		48,344	39,056	137,666	112,244
	Total	74,187	59,350	211,079	171,850

Significant Non-U.S. revenue sources include: (1)
	Canada	6,214	5,260	17,752	14,492
	United Kingdom	4,797	4,057	14,240	12,309
	Belgium	3,996	3,247	12,063	9,833
	France	3,588	2,984	10,405	8,290
	Singapore	3,502	2,888	10,387	8,264
	Italy	3,316	2,913	9,684	8,317
	Germany	2,518	2,210	7,184	6,283

(1) Revenue is determined by primary country of operations. Excludes certain sales and other operating revenues in Non‑U.S. operations where attribution to a specific country is not practicable.

9. Additional Information on Revenue Recognition

Accounting Policy for Revenue Recognition

The Corporation generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments to reflect market conditions. Revenue is recognized at the amount the Corporation expects to receive when the customer has taken control, which is typically when title transfers and the customer has assumed the risks and rewards of ownership. The prices of certain sales are based on price indexes that are sometimes not available until the next period. In such cases, estimated realizations are accrued when the sale is recognized, and are finalized when the price is available. Such adjustments to revenue from performance obligations satisfied in previous periods are not significant. Payment for revenue transactions is typically due within 30 days. Future volume delivery obligations that are unsatisfied at the end of the period are expected to be fulfilled through ordinary production or purchases. These performance obligations are based on market prices at the time of the transaction and are fully constrained due to market price volatility.

“Sales and other operating revenue” and “Notes and accounts receivable” primarily arise from contracts with customers. Long-term receivables are primarily from non-customers. Contract assets are mainly from marketing assistance programs and are not significant. Contract liabilities are mainly customer prepayments and accruals of expected volume discounts and are not significant.

EXXON MOBIL CORPORATION

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

FUNCTIONAL EARNINGS SUMMARY

			Third Quarter		First Nine Months
Earnings (U.S. GAAP)			2018	2017	2018	2017
		(millions of dollars)
Upstream
	United States		606	(238)	1,474	(439)
	Non-U.S.		3,623	1,805	9,292	5,442
Downstream
	United States		961	391	1,975	1,030
	Non-U.S.		681	1,141	1,331	3,003
Chemical
	United States		404	403	1,360	1,413
	Non-U.S.		309	689	1,254	1,835
Corporate and financing (1)			(344)	(221)	(1,846)	(954)
	Net income attributable to ExxonMobil (U.S. GAAP)		6,240	3,970	14,840	11,330

Earnings per common share (dollars)			1.46	0.93	3.47	2.66

Earnings per common share - assuming dilution (dollars)			1.46	0.93	3.47	2.66

(1) See Note 2 to the financial statements for additional details regarding the change in segmentation of Non-service pension and postretirement benefit expense.

References in this discussion to Corporate earnings mean net income attributable to ExxonMobil (U.S. GAAP) from the consolidated income statement. Unless otherwise indicated, references to earnings, Upstream, Downstream, Chemical and Corporate and financing segment earnings, and earnings per share are ExxonMobil's share after excluding amounts attributable to noncontrolling interests.

REVIEW OF THIRD QUARTER 2018 RESULTS

ExxonMobil’s third quarter 2018 earnings were $6.2 billion, or $1.46 per diluted share, compared with $4 billion a year earlier, as liquids realizations increased.

Earnings of $14.8 billion for the first nine months of 2018 increased 31 percent from $11.3 billion in 2017.

Earnings per share assuming dilution were $3.47.

Capital and exploration expenditures were $18.1 billion, up 28 percent from 2017.

Oil‑equivalent production was 3.8 million barrels per day, down 5 percent from the prior year. Excluding entitlement effects and divestments, oil‑equivalent production was down 2 percent from the prior year.

The Corporation distributed $10.3 billion in dividends to shareholders.

				Third Quarter		First Nine Months
				2018	2017	2018	2017
			(millions of dollars)
Upstream earnings
	United States			606	(238)	1,474	(439)
	Non-U.S.			3,623	1,805	9,292	5,442
		Total		4,229	1,567	10,766	5,003

Upstream earnings were $4,229 million in the third quarter of 2018, up $2,662 million from the third quarter of 2017.

· Realizations increased earnings by $2,580 million due to higher liquids and gas realizations.

· Higher volume and mix effects increased earnings by $50 million.

· All other items increased earnings by $30 million including favorable one-time tax impacts, partly offset by higher production expenses.

· U.S. Upstream earnings were $606 million, up $844 million from the prior year quarter.

· Non‑U.S. Upstream earnings were $3,623 million, up $1,818 million from the prior year quarter.

· On an oil‑equivalent basis, production decreased 2 percent from the third quarter of 2017.

· Liquids production totaled 2.3 million barrels per day, up 6,000 barrels per day as growth more than offset lower volumes from entitlements, divestments, decline, and downtime.

· Natural gas production was 9 billion cubic feet per day, down 584 million cubic feet per day driven by decline largely in the U.S. aligned with value focus, lower volumes from divestments and lower demand.

Upstream earnings were $10,766 million in the first nine months of 2018, up $5,763 million from the first nine months of 2017.

· Realizations increased earnings by $6,400 million mainly due to higher liquids realizations.

· Lower volume and mix effects decreased earnings by $430 million.

· All other items decreased earnings by $210 million, mainly due to higher production expenses and unfavorable tax impacts, partly offset by favorable one-time tax items and higher divestment gains.

· U.S. Upstream earnings were $1,474 million, up $1,913 million from the first nine months of prior year.

· Non-U.S. Upstream earnings were $9,292 million, up $3,850 million from the first nine months of prior year.

· On an oil-equivalent basis, production decreased 5 percent from the first nine months of 2017.

· Liquids production totaled 2.2 million barrels per day, down 56,000 barrels per day as growth in North America was more than offset by lower volumes from decline, entitlements, and divestments.

· Natural gas production was 9.2 billion cubic feet per day, down 920 million cubic feet per day driven by decline in the U.S. aligned with value focus, higher downtime and lower volumes from entitlements and divestments.

		Third Quarter		First Nine Months
Upstream additional information			(thousands of barrels daily)
Volumes reconciliation (Oil-equivalent production)(1)
2017			3,878		3,983
	Entitlements - Net Interest		(3)		(3)
	Entitlements - Price / Spend / Other		(84)		(68)
	Quotas		-		-
	Divestments		(69)		(64)
	Growth / Other		64		(74)
2018			3,786		3,774

(1) Gas converted to oil-equivalent at 6 million cubic feet = 1 thousand barrels.

Listed below are descriptions of ExxonMobil’s volumes reconciliation factors which are provided to facilitate understanding of the terms.

Entitlements - Net Interest are changes to ExxonMobil’s share of production volumes caused by non-operational changes to volume-determining factors. These factors consist of net interest changes specified in Production Sharing Contracts (PSCs) which typically occur when cumulative investment returns or production volumes achieve defined thresholds, changes in equity upon achieving pay-out in partner investment carry situations, equity redeterminations as specified in venture agreements, or as a result of the termination or expiry of a concession. Once a net interest change has occurred, it typically will not be reversed by subsequent events, such as lower crude oil prices.

Entitlements - Price, Spend and Other are changes to ExxonMobil’s share of production volumes resulting from temporary changes to non-operational volume-determining factors. These factors include changes in oil and gas prices or spending levels from one period to another. According to the terms of contractual arrangements or government royalty regimes, price or spending variability can increase or decrease royalty burdens and/or volumes attributable to ExxonMobil. For example, at higher prices, fewer barrels are required for ExxonMobil to recover its costs. These effects generally vary from period to period with field spending patterns or market prices for oil and natural gas. Such factors can also include other temporary changes in net interest as dictated by specific provisions in production agreements.

Quotas are changes in ExxonMobil’s allowable production arising from production constraints imposed by countries which are members of the Organization of the Petroleum Exporting Countries (OPEC). Volumes reported in this category would have been readily producible in the absence of the quota.

Divestments are reductions in ExxonMobil’s production arising from commercial arrangements to fully or partially reduce equity in a field or asset in exchange for financial or other economic consideration.

Growth and Other factors comprise all other operational and non-operational factors not covered by the above definitions that may affect volumes attributable to ExxonMobil. Such factors include, but are not limited to, production enhancements from project and work program activities, acquisitions including additions from asset exchanges, downtime, market demand, natural field decline, and any fiscal or commercial terms that do not affect entitlements.

				Third Quarter		First Nine Months
				2018	2017	2018	2017
			(millions of dollars)
Downstream earnings
	United States			961	391	1,975	1,030
	Non-U.S.			681	1,141	1,331	3,003
		Total		1,642	1,532	3,306	4,033

Downstream earnings were $1,642 million in the third quarter of 2018, up $110 million from the third quarter of 2017.

· Margins decreased earnings by $110 million, as lower Non-U.S. margins were partially offset by higher U.S. margins.

· Higher volume and mix effects increased earnings by $210 million, primarily due to improved refinery operations.

· All other items increased earnings by $10 million, mainly due to favorable tax impacts and divestment gains, partly offset by higher maintenance expenses.

· U.S. Downstream earnings were $961 million, up $570 million from the prior year quarter.

· Non‑U.S. Downstream earnings were $681 million, down $460 million from the prior year quarter.

· Petroleum product sales of 5.6 million barrels per day were 74,000 barrels per day higher than the prior year quarter.

Downstream earnings were $3,306 million in the first nine months of 2018, down $727 million from the first nine months of 2017.

· Margins increased earnings by $110 million, as higher U.S. margins were partially offset by lower Non-U.S. margins.

· Lower volume and mix effects decreased earnings by $40 million, primarily due to downtime and maintenance partly offset by improved refinery mix/ yield and higher sales.

· All other items decreased earnings by $800 million, mainly due to unfavorable foreign exchange impacts of $250 million, lower divestment gains of $180 million, and other unfavorable impacts of $370 million including higher expenses from downtime / maintenance.

· U.S. Downstream earnings were $1,975 million, up $945 million from the first nine months of prior year.

· Non-U.S. Downstream earnings were $1,331 million, down $1,672 million from the first nine months of prior year.

· Petroleum product sales of 5.5 million barrels per day were 18,000 barrels per day higher than the first nine months of prior year.

				Third Quarter		First Nine Months
				2018	2017	2018	2017
			(millions of dollars)
Chemical earnings
	United States			404	403	1,360	1,413
	Non-U.S.			309	689	1,254	1,835
		Total		713	1,092	2,614	3,248

Chemical earnings of $713 million in the third quarter of 2018, were $379 million lower than the third quarter of 2017.

· Weaker margins decreased earnings by $140 million.

· Volume and mix effects increased earnings by $20 million.

· All other items decreased earnings by $260 million, mainly due to higher expenses.

· U.S. Chemical earnings were $404 million, up $1 million from the prior year quarter.

· Non‑U.S. Chemical earnings were $309 million, down $380 million from the prior year quarter.

· Third quarter prime product sales of 6.7 million metric tons were 231,000 metric tons higher than the prior year quarter due to project growth and acquisitions.

Chemical earnings were $2,614 million in the first nine months of 2018, down $634 million from the first nine months of 2017.

· Weaker margins decreased earnings by $640 million.

· Volume and mix effects increased earnings by $250 million.

· All other items decreased earnings by $240 million, as higher expenses were partially offset by favorable foreign exchange and tax impacts.

· U.S. Chemical earnings were $1,360 million, down $53 million from the first nine months of prior year.

· Non-U.S. Chemical earnings were $1,254 million, down $581 million from the first nine months of prior year.

· Prime product sales of 20.2 million metric tons in the first nine months were 1.6 million metric tons higher than the first nine months of prior year due to project growth and acquisitions.

Third Quarter

First Nine Months

2018

2017

2018

2017

(millions of dollars)

Corporate and financing earnings

(344)

(221)

(1,846)

(954)

Corporate and financing expenses were $344 million for the third quarter of 2018, up $123 million from the third quarter of 2017, mainly due to the impact of a lower U.S. tax rate.

Corporate and financing expenses were $1,846 million in the first nine months of 2018, up $892 million from the first nine months of 2017, mainly due to lower net favorable tax items, the impact of a lower U.S. tax rate, and higher pension and financing related costs.

LIQUIDITY AND CAPITAL RESOURCES

				Third Quarter		First Nine Months
				2018	2017	2018	2017
			(millions of dollars)
Net cash provided by/(used in)
	Operating activities					27,407	22,655
	Investing activities					(10,862)	(9,194)
	Financing activities					(13,945)	(13,293)
Effect of exchange rate changes						(108)	441
Increase/(decrease) in cash and cash equivalents						2,492	609

Cash and cash equivalents (at end of period)						5,669	4,266

Cash flow from operations and asset sales
	Net cash provided by operating activities (U.S. GAAP)			11,108	7,535	27,407	22,655
	Proceeds associated with sales of subsidiaries, property,
		plant & equipment, and sales and returns of investments		1,491	854	3,239	1,695
	Cash flow from operations and asset sales			12,599	8,389	30,646	24,350

Because of the ongoing nature of our asset management and divestment program, we believe it is useful for investors to consider proceeds associated with asset sales together with cash provided by operating activities when evaluating cash available for investment in the business and financing activities, including shareholder distributions.

Cash flow from operations and asset sales in the third quarter of 2018 was $12.6 billion, including asset sales of $1.5 billion, an increase of $4.2 billion from the comparable 2017 period primarily reflecting higher earnings and favorable working capital effects.

Cash provided by operating activities totaled $27.4 billion for the first nine months of 2018, $4.8 billion higher than 2017. The major source of funds was net income including noncontrolling interests of $15.2 billion, an increase of $3.8 billion from the prior year period. The adjustment for the noncash provision of $13.7 billion for depreciation and depletion was down $0.3 billion from 2017. Changes in operational working capital were essentially flat, compared to a decrease of $0.5 billion in the prior year period. All other items net decreased cash flows by $1.5 billion in 2018 versus a reduction of $2.3 billion in 2017. See the Condensed Consolidated Statement of Cash Flows for additional details.

Investing activities for the first nine months of 2018 used net cash of $10.9 billion, an increase of $1.7 billion compared to the prior year. Spending for additions to property, plant and equipment of $13.5 billion was $2.6 billion higher than 2017. Proceeds from asset sales of $3.2 billion increased $1.5 billion. Investments and advances decreased $0.8 billion, principally reflecting the absence of the deposit into escrow of the maximum potential contingent consideration payable as a result of the acquisition of InterOil Corporation in 2017. This was partly offset by cash outflows in 2018 related to the acquisition of a Downstream business in Indonesia.

Cash flow from operations and asset sales in the first nine months of 2018 was $30.6 billion, including asset sales of $3.2 billion, an increase of $6.3 billion from the comparable 2017 period primarily reflecting higher earnings and increased asset sale proceeds.

Net cash used by financing activities was $13.9 billion in the first nine months of 2018, an increase of $0.7 billion from 2017. The net reduction in short and long term debt was $2.7 billion compared to $2.8 billion in 2017.

During the first nine months of 2018, Exxon Mobil Corporation purchased 5 million shares of its common stock for the treasury at a gross cost of $0.4 billion. These purchases were made to offset shares or units settled in shares issued in conjunction with the company’s benefit plans and programs. Shares outstanding decreased from 4,239 million at year-end to 4,234 million at the end of the third quarter of 2018. Purchases may be made both in the open market and through negotiated transactions, and may be increased, decreased or discontinued at any time without prior notice.

The Corporation distributed a total of $10.3 billion to shareholders in the first nine months of 2018 through dividends.

Total cash and cash equivalents of $5.7 billion at the end of the third quarter of 2018 compared to $3.2 billion at year-end 2017.

Total debt at the end of the third quarter of 2018 was $40 billion compared to $42.3 billion at year-end 2017. The Corporation's debt to total capital ratio was 16.9 percent at the end of the third quarter of 2018 compared to 17.9 percent at year-end 2017.

The Corporation has access to significant capacity of long-term and short-term liquidity. Internally generated funds are generally expected to cover financial requirements, supplemented by short-term and long-term debt as required.

The Corporation, as part of its ongoing asset management program, continues to evaluate its mix of assets for potential upgrade. Because of the ongoing nature of this program, dispositions will continue to be made from time to time which will result in either gains or losses. Additionally, the Corporation continues to evaluate opportunities to enhance its business portfolio through acquisitions of assets or companies, and enters into such transactions from time to time. Key criteria for evaluating acquisitions include potential for future growth and attractive current valuations. Acquisitions may be made with cash, shares of the Corporation’s common stock, or both.

Litigation and other contingencies are discussed in Note 3 to the unaudited condensed consolidated financial statements.

TAXES

				Third Quarter				First Nine Months
				2018		2017		2018		2017
			(millions of dollars)

Income taxes				2,634		1,498		7,617		4,218
	Effective income tax rate			34	%	33	%	39	%	34	%
Total other taxes and duties (1)				8,939		8,287		26,757		23,876
		Total		11,573		9,785		34,374		28,094

(1) Includes “Other taxes and duties” plus taxes that are included in “Production and manufacturing expenses” and “Selling, general and administrative expenses.”

Total taxes were $11.6 billion for the third quarter of 2018, an increase of $1.8 billion from 2017. Income tax expense increased by $1.1 billion to $2.6 billion reflecting higher pre-tax income. The effective income tax rate was 34 percent compared to 33 percent in the prior year period. This increase mainly reflects a higher share of earnings in higher tax jurisdictions, partly offset by the impact of favorable one-time tax items. Total other taxes and duties increased by $0.7 billion to $8.9 billion.

Total taxes were $34.4 billion for the first nine months of 2018, an increase of $6.3 billion from 2017. Income tax expense increased by $3.4 billion to $7.6 billion reflecting higher pre-tax income. The effective income tax rate was 39 percent compared to 34 percent in the prior year period due to a higher share of earnings in higher tax jurisdictions. Total other taxes and duties increased by $2.9 billion to $26.8 billion.

Non-U.S. Upstream earnings included a $270 million tax credit resulting from an updated estimate of the impact of U.S. tax reform and from clarifications provided in proposed transition tax regulations issued by the Treasury in the third quarter of 2018. The adjustment restores a portion of the U.S. tax reform deferred income tax expense reported in the non-U.S. Upstream segment in the fourth quarter of 2017. There were no other significant changes during the first nine months of 2018 to the Corporation’s reasonable estimates of the income tax effects reflected in 2017 for the changes in tax law and tax rate from U.S. tax reform and following guidance outlined in the SEC Staff Accounting Bulletin No. 118. The impact of tax law changes on the Corporation’s financial statements could differ from its estimates due to further analysis of the new law, regulatory guidance, technical corrections legislation, guidance under U.S. GAAP, or other considerations. If significant changes occur, the Corporation will provide updated information in connection with its Form 10-K for 2018.

In the United States, the Corporation has various ongoing U.S. federal income tax positions at issue with the Internal Revenue Service (IRS) for tax years beginning in 2006. The IRS has asserted penalties associated with several of those positions. The Corporation has not recognized the penalties as an expense because the Corporation does not expect the penalties to be sustained under applicable law. The Corporation has filed a refund suit for tax years 2006-2009 in a U.S. federal district court with respect to the positions at issue for those years. Unfavorable resolution of all positions at issue with the IRS would not have a materially adverse effect on the Corporation’s net income or liquidity.

CAPITAL AND EXPLORATION EXPENDITURES

			Third Quarter		First Nine Months
			2018	2017	2018	2017
		(millions of dollars)

Upstream (including exploration expenses)			5,330	3,175	13,944	9,080
Downstream			719	611	2,563	1,742
Chemical			526	2,183	1,524	3,215
Other			11	18	49	44
	Total		6,586	5,987	18,080	14,081

Capital and exploration expenditures in the third quarter of 2018 were $6.6 billion, up 10 percent from the third quarter of 2017.

Capital and exploration expenditures in the first nine months of 2018 were $18.1 billion, up 28 percent from the first nine months of 2017 due primarily to increased U.S. drilling activity and acreage acquisitions in Brazil. The Corporation anticipates an investment level of approximately $25 billion in 2018. Actual spending could vary depending on the progress of individual projects and property acquisitions.

In 2013 and 2014, the Corporation and Rosneft established various entities to conduct exploration and research activities. In 2014, the European Union and United States imposed sanctions relating to the Russian energy sector. ExxonMobil continues to comply with all sanctions and regulatory licenses applicable to its affiliates’ investments in the Russian Federation. See Part II. Other Information, Item 1. Legal Proceedings in this report for information concerning a civil penalty assessment related to this matter which the Corporation is contesting. The Corporation withdrew from the aforementioned joint ventures with Rosneft, effective April 30, 2018.

The Groningen field is operated by Nederlandse Aardolie Maatschappij (NAM), a Netherlands company owned 50 percent by affiliates of the Corporation. NAM has a 60 percent interest in the Groningen field. On March 29, 2018, the Dutch Cabinet notified Parliament of its intention to further reduce previously legislated Groningen gas extraction in response to seismic events over the last several years. Affiliates of the Corporation and their partners have actively been in discussions with the government on the associated implementation measures which resulted in a signed Heads of Agreement (HoA – agreement on principles) on June 25, 2018 and the execution of additional implementation agreements in September. In anticipation of a lower production outlook, the Corporation has reduced its estimate of proved reserves by 0.8 billion oil-equivalent barrels. In addition, the seismic activity has yielded various claims. Where losses are probable and reasonably estimable, liabilities have been recorded. The Corporation does not expect these matters to have a material effect on the Corporation’s operations or financial condition. While the future production profile and other considerations related to the Groningen field could vary depending on a wide variety of factors, reduced gas extraction in the future is expected to result in lower reported production, earnings and cash flows than in recent years for the Corporation’s share of NAM.

RECENTLY ISSUED ACCOUNTING STANDARDS

FORWARD-LOOKING STATEMENTS

Statements relating to future plans and objectives, projections, events or conditions are forward-looking statements. Future results, including new projects, growth strategies, costs, timing, and capacities; business growth; integration benefits; resource recoveries; and the impact of new technologies, could differ materially due to a number of factors. These include changes in supply and demand for oil, gas or petrochemicals or other market conditions affecting the oil, gas and petrochemical industries; reservoir performance; timely completion of new projects; the impact of fiscal and commercial terms and the outcome of commercial negotiations; changes in law, taxes, or government regulation and timely granting of governmental permits; war and other political or security disturbances; the actions of competitors; unforeseen technical or operating difficulties; unexpected technological developments; general economic conditions including the occurrence and duration of economic recessions; commodity cycles within the general economy; the results of research programs; and other factors discussed under the heading Factors Affecting Future Results on the Investors page of our website at www.exxonmobil.com and in Item 1A of ExxonMobil's 2017 Form 10-K. We assume no duty to update these statements as of any future date.

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.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Information about market risks for the nine months ended September 30, 2018, does not differ materially from that discussed under Item 7A of the registrant's Annual Report on Form 10-K for 2017.

Item 4. Controls and Procedures

As indicated in the certifications in Exhibit 31 of this report, the Corporation’s Chief Executive Officer, Principal Financial Officer and Principal Accounting Officer have evaluated the Corporation’s disclosure controls and procedures as of September 30, 2018. Based on that evaluation, these officers have concluded that the Corporation’s disclosure controls and procedures are effective in ensuring that information required to be disclosed by the Corporation 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 were no changes during the Corporation’s last fiscal quarter that materially affected, or are reasonably likely to materially affect, the Corporation’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

As last reported in the Corporation’s Form 10-K for 2017, in April 2017, the State of North Dakota Department of Health (NDDOH) and the North Dakota State Office of the Attorney General notified XTO Energy Inc. (XTO) of their interest in settling alleged violations of the North Dakota Century Code and implementing regulations regarding the alleged failure of vapor control systems to properly route tank vapors to control devices at well pads and tank farms outside the Fort Berthold Indian Reservation. On February 1, 2018, the South Central Judicial District Court in Bismarck, North Dakota, approved a Consent Decree between XTO and NDDOH concerning those alleged violations. Under the Consent Decree, XTO paid a civil penalty of $575,000 on September 21, 2018.

As last reported in the Corporation’s Form 10-Q for the third quarter of 2017, in a matter related to the discharge of crude oil from the Pegasus Pipeline in Mayflower, Faulkner County, Arkansas, the Pipeline and Hazardous Materials Safety Administration (PHMSA) on October 1, 2015, issued a Final Order arising from a November 2013 Notice of Probable Violation alleging that ExxonMobil Pipeline Company (EMPCo) violated multiple federal Pipeline Safety Regulations. The Final Order imposed a penalty of $2,630,400, which EMPCo paid on April 21, 2016. On June 27, 2016, EMPCo filed an appeal with the U.S. Court of Appeals for the Fifth Circuit, contesting six of the nine regulatory violations found by PHMSA and seeking a refund of the penalty paid associated with the six contested violations ($2,417,400 of the total penalty paid in April 2016). On August 14, 2017, the Fifth Circuit dismissed five of the six violations EMPCo challenged from PHMSA’s final administrative order, and vacated $1,634,100 in associated penalties. The Fifth Circuit also remanded the remaining violation back to PHMSA for re-calculation of the civil penalty previously imposed. On August 7, 2018, PHMSA issued the Order on Remand, assessing a reduced civil penalty of $61,900 for the remanded sixth violation (down from $783,300). As a result, in September 2018, EMPCo received a refund of $2,355,500 for penalties that had been paid.

As last reported in the Corporation’s Form 10-Q for the second quarter of 2018, on July 20, 2017, the United States Department of Treasury, Office of Foreign Assets Control (OFAC) assessed a civil penalty against Exxon Mobil Corporation, ExxonMobil Development Company and ExxonMobil Oil Corporation for violating the Ukraine-Related Sanctions Regulations, 31 C.F.R. part 589. The assessed civil penalty is in the amount of $2,000,000. ExxonMobil and its affiliates have been and continue to be in compliance with all sanctions and disagree that any violation has occurred. ExxonMobil and its affiliates filed a complaint on July 20, 2017, in the United States Federal District Court, Northern District of Texas seeking judicial review of, and to enjoin, the civil penalty under the Administrative Procedures Act and the United States Constitution, including on the basis that it represents an arbitrary and capricious action by OFAC and a violation of the Company’s due process rights.

Refer to the relevant portions of Note 3 of this Quarterly Report on Form 10-Q for further information on legal proceedings.

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

Issuer Purchase of Equity Securities for Quarter Ended September 30, 2018

				Total Number of	Maximum Number
				Shares Purchased	of Shares that May
		Total Number	Average	as Part of Publicly	Yet Be Purchased
		of Shares	Price Paid	Announced Plans	Under the Plans or
Period		Purchased	per Share	or Programs	Programs

July 2018		-		-
August 2018		-		-
September 2018		-		-
	Total	-		-	(See Note 1)

Note 1 - On August 1, 2000, the Corporation announced its intention to resume purchases of shares of its common stock for the treasury both to offset shares issued in conjunction with company benefit plans and programs and to gradually reduce the number of shares outstanding. The announcement did not specify an amount or expiration date. The Corporation has continued to purchase shares since this announcement and to report purchased volumes in its quarterly earnings releases. In its earnings release dated February 2, 2016, the Corporation stated it will continue to acquire shares to offset dilution in conjunction with benefit plans and programs, but had suspended making purchases to reduce shares outstanding effective beginning the first quarter of 2016.

Item 6. Exhibits

See Index to Exhibits of this report.

INDEX TO EXHIBITS

Exhibit		Description

31.1		Certification (pursuant to Securities Exchange Act Rule 13a-14(a)) by Chief Executive Officer.
31.2		Certification (pursuant to Securities Exchange Act Rule 13a-14(a)) by Principal Financial Officer.
31.3		Certification (pursuant to Securities Exchange Act Rule 13a-14(a)) by Principal Accounting Officer.
32.1		Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906) by Chief Executive Officer.
32.2		Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906) by Principal Financial Officer.
32.3		Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906) by Principal Accounting Officer.
101		Interactive Data Files.

EXXON MOBIL CORPORATION

SIGNATURE

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.

	EXXON MOBIL CORPORATION
Date: November 7, 2018	By:	/s/ DAVID S. ROSENTHAL
		David S. Rosenthal
		Vice President, Controller and
		Principal Accounting Officer