10-Q 1 psx-2018930_10q.htm 10-Q Document

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X]
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the quarterly period ended
September 30, 2018
 

 
 
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:
001-35349
 
Phillips 66
(Exact name of registrant as specified in its charter)
 
Delaware
 
45-3779385
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)

2331 CityWest Blvd., Houston, Texas 77042
(Address of principal executive offices) (Zip Code)
281-293-6600
(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  [X]    No  [    ]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).     Yes  [X]    No  [    ]
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
 Large accelerated filer  [X]     Accelerated filer  [    ]  Non-accelerated filer  [    ]    
 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  [X]
The registrant had 461,125,321 shares of common stock, $0.01 par value, outstanding as of September 30, 2018.



PHILLIPS 66

TABLE OF CONTENTS
 





PART I. FINANCIAL INFORMATION
Item 1. FINANCIAL STATEMENTS
 
Consolidated Statement of Income
Phillips 66
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues*
$
29,788

25,627

 
82,363

72,608

Equity in earnings of affiliates
779

530

 
1,946

1,357

Net gain on dispositions
1


 
18

15

Other income
24

49

 
47

519

Total Revenues and Other Income
30,592

26,206

 
84,374

74,499

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products
26,385

19,463

 
73,270

55,495

Operating expenses
1,206

1,134

 
3,595

3,541

Selling, general and administrative expenses
440

435

 
1,258

1,258

Depreciation and amortization
346

337

 
1,019

972

Impairments
1

1

 
7

18

Taxes other than income taxes*
109

3,456

 
328

9,968

Accretion on discounted liabilities
5

5

 
17

16

Interest and debt expense
125

112

 
383

324

Foreign currency transaction (gains) losses

7

 
(30
)
6

Total Costs and Expenses
28,617

24,950

 
79,847

71,598

Income before income taxes
1,975

1,256


4,527

2,901

Income tax expense
407

407

 
970

908

Net Income
1,568

849

 
3,557

1,993

Less: net income attributable to noncontrolling interests
76

26

 
202

85

Net Income Attributable to Phillips 66
$
1,492

823

 
3,355

1,908

 
 
 
 
 
 
Net Income Attributable to Phillips 66 Per Share of Common Stock (dollars)
 
 
 
 
 
Basic
$
3.20

1.60

 
7.07

3.68

Diluted
3.18

1.60

 
7.03

3.66

 
 
 
 
 
 
Dividends Paid Per Share of Common Stock (dollars)
$
0.80

0.70

 
2.30

2.03

 
 
 
 
 
 
Weighted-Average Common Shares Outstanding (thousands)
 
 
 
 
 
Basic
466,109

512,923

 
473,760

517,420

Diluted
469,440

515,960

 
477,220

520,516

* Includes excise taxes on sales of petroleum products for periods prior to the adoption of Accounting Standards Update No. 2014-09 on January 1, 2018:
 
$
3,376

 
 
9,664

See Notes to Consolidated Financial Statements.
 
 
 
 
 

1


Consolidated Statement of Comprehensive Income
Phillips 66
 
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

 
 
 
 
 
 
Net Income
$
1,568

849

 
3,557

1,993

Other comprehensive income (loss)
 
 
 
 
 
Defined benefit plans
 
 
 
 
 
Amortization to net income of net actuarial loss, prior service credit and settlements
68

45

 
111

145

Plans sponsored by equity affiliates
4

2

 
13

8

Income taxes on defined benefit plans
(18
)
(17
)
 
(30
)
(56
)
Defined benefit plans, net of tax
54

30

 
94

97

Foreign currency translation adjustments
(15
)
94

 
(125
)
222

Income taxes on foreign currency translation adjustments
1

1

 
2

(8
)
Foreign currency translation adjustments, net of tax
(14
)
95

 
(123
)
214

Cash flow hedges
2


 
10


Income taxes on hedging activities
(1
)

 
(3
)

Hedging activities, net of tax
1


 
7


Other Comprehensive Income (Loss), Net of Tax
41

125

 
(22
)
311

Comprehensive Income
1,609

974

 
3,535

2,304

Less: comprehensive income attributable to noncontrolling interests
76

26

 
202

85

Comprehensive Income Attributable to Phillips 66
$
1,533

948

 
3,333

2,219

See Notes to Consolidated Financial Statements.

2


Consolidated Balance Sheet
Phillips 66
 
 
Millions of Dollars
 
September 30
2018

 
December 31
2017

Assets
 
 
 
Cash and cash equivalents
$
924

 
3,119

Accounts and notes receivable (net of allowances of $22 million in 2018 and $29 million in 2017)
6,840

 
6,424

Accounts and notes receivable—related parties
1,131

 
1,082

Inventories
5,544

 
3,395

Prepaid expenses and other current assets
875

 
370

Total Current Assets
15,314

 
14,390

Investments and long-term receivables
14,311

 
13,941

Net properties, plants and equipment
21,625

 
21,460

Goodwill
3,270

 
3,270

Intangibles
874

 
876

Other assets
490

 
434

Total Assets
$
55,884

 
54,371

 
 
 
 
Liabilities
 
 
 
Accounts payable
$
8,444

 
7,242

Accounts payable—related parties
911

 
785

Short-term debt
316

 
41

Accrued income and other taxes
1,151

 
1,002

Employee benefit obligations
569

 
582

Other accruals
583

 
455

Total Current Liabilities
11,974

 
10,107

Long-term debt
11,021

 
10,069

Asset retirement obligations and accrued environmental costs
637

 
641

Deferred income taxes
5,311

 
5,008

Employee benefit obligations
793

 
884

Other liabilities and deferred credits
353

 
234

Total Liabilities
30,089

 
26,943

 
 
 
 
Equity
 
 
 
Common stock (2,500,000,000 shares authorized at $0.01 par value)
     Issued (2018—645,578,563 shares; 2017—643,835,464 shares)
 
 
 
Par value
6

 
6

Capital in excess of par
19,860

 
19,768

Treasury stock (at cost: 2018—184,453,242 shares; 2017—141,565,145 shares)
(14,526
)
 
(10,378
)
Retained earnings
18,618

 
16,306

Accumulated other comprehensive loss
(639
)
 
(617
)
Total Stockholders’ Equity
23,319

 
25,085

Noncontrolling interests
2,476

 
2,343

Total Equity
25,795

 
27,428

Total Liabilities and Equity
$
55,884

 
54,371

See Notes to Consolidated Financial Statements.

3


Consolidated Statement of Cash Flows
Phillips 66
 
Millions of Dollars
 
Nine Months Ended
September 30
 
2018

 
2017

Cash Flows From Operating Activities
 
 
 
Net income
$
3,557

 
1,993

Adjustments to reconcile net income to net cash provided by operating
activities
 
 
 
Depreciation and amortization
1,019

 
972

Impairments
7

 
18

Accretion on discounted liabilities
17

 
16

Deferred income taxes
229

 
784

Undistributed equity earnings
111

 
(543
)
Net gain on dispositions
(18
)
 
(15
)
Gain on consolidation of business

 
(423
)
Other
118

 
(234
)
Working capital adjustments
 
 
 
Decrease (increase) in accounts and notes receivable
(478
)
 
(33
)
Decrease (increase) in inventories
(2,178
)
 
(1,228
)
Decrease (increase) in prepaid expenses and other current assets
(509
)
 
(106
)
Increase (decrease) in accounts payable
1,280

 
464

Increase (decrease) in taxes and other accruals
279

 
52

Net Cash Provided by Operating Activities
3,434

 
1,717

 
 
 
 
Cash Flows From Investing Activities
 
 
 
Capital expenditures and investments
(1,645
)
 
(1,295
)
Proceeds from asset dispositions*
39

 
65

Collection of advances/loans—related parties

 
325

Restricted cash received from consolidation of business

 
318

Other
66

 
(89
)
Net Cash Used in Investing Activities
(1,540
)
 
(676
)
 
 
 
 
Cash Flows From Financing Activities
 
 
 
Issuance of debt
1,594

 
3,083

Repayment of debt
(374
)
 
(3,161
)
Issuance of common stock
39

 
23

Repurchase of common stock
(4,148
)
 
(1,127
)
Dividends paid on common stock
(1,069
)
 
(1,042
)
Distributions to noncontrolling interests
(146
)
 
(83
)
Net proceeds from issuance of Phillips 66 Partners LP common units
114

 
171

Other
(79
)
 
(66
)
Net Cash Used in Financing Activities
(4,069
)
 
(2,202
)
 
 
 
 
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash
(20
)
 
(3
)
 
 
 
 
Net Change in Cash, Cash Equivalents and Restricted Cash
(2,195
)
 
(1,164
)
Cash, cash equivalents and restricted cash at beginning of period
3,119

 
2,711

Cash, Cash Equivalents and Restricted Cash at End of Period
$
924

 
1,547

* Includes return of investments in equity affiliates.
See Notes to Consolidated Financial Statements.

4


Consolidated Statement of Changes in Equity
Phillips 66
 
 
Millions of Dollars
 
Attributable to Phillips 66
 
 
 
Common Stock
 
 
 
 
 
Par
Value

Capital in Excess of Par

Treasury Stock

Retained
Earnings

Accum. Other
Comprehensive Loss

Noncontrolling
Interests

Total

December 31, 2016
$
6

19,559

(8,788
)
12,608

(995
)
1,335

23,725

Net income



1,908


85

1,993

Other comprehensive income




311


311

Dividends paid on common stock



(1,042
)


(1,042
)
Repurchase of common stock


(1,127
)



(1,127
)
Benefit plan activity

48


(10
)


38

Issuance of Phillips 66 Partners LP common units

45




99

144

Distributions to noncontrolling interests





(83
)
(83
)
September 30, 2017
$
6

19,652

(9,915
)
13,464

(684
)
1,436

23,959

 
 
 
 
 
 
 
 
December 31, 2017
$
6

19,768

(10,378
)
16,306

(617
)
2,343

27,428

Cumulative effect of accounting changes



36


13

49

Net income



3,355


202

3,557

Other comprehensive loss




(22
)

(22
)
Dividends paid on common stock



(1,069
)


(1,069
)
Repurchase of common stock


(4,148
)



(4,148
)
Benefit plan activity

54


(10
)


44

Issuance of Phillips 66 Partners LP common units

38




64

102

Distributions to noncontrolling interests





(146
)
(146
)
September 30, 2018
$
6

19,860

(14,526
)
18,618

(639
)
2,476

25,795

 
 
Shares in Thousands
 
Common Stock Issued

Treasury Stock

December 31, 2016
641,594

122,827

Repurchase of common stock

13,852

Shares issued—share-based compensation
1,826


September 30, 2017
643,420

136,679

 
 
 
December 31, 2017
643,835

141,565

Repurchase of common stock

42,888

Shares issued—share-based compensation
1,744


September 30, 2018
645,579

184,453

See Notes to Consolidated Financial Statements.



5


Notes to Consolidated Financial Statements
Phillips 66
 
Note 1—Interim Financial Information

The interim financial information presented in the financial statements included in this report is unaudited and includes all known accruals and adjustments necessary, in the opinion of management, for a fair presentation of the consolidated financial position of Phillips 66 and its results of operations and cash flows for the periods presented. Unless otherwise specified, all such adjustments are of a normal and recurring nature. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these interim financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2017 Annual Report on Form 10-K. The results of operations for the three and nine months ended September 30, 2018, are not necessarily indicative of the results to be expected for the full year. Certain prior period financial information has been recast to reflect the current year’s presentation.


Note 2—Changes in Accounting Principles

Effective January 1, 2018, we adopted Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2017-05, “Other Income—Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20),” which clarifies the scope and accounting for the sale or transfer of nonfinancial assets and in substance nonfinancial assets to noncustomers, including partial sales.  This ASU eliminated the use of carryover basis for most nonmonetary exchanges, including contributions of assets to equity-method joint ventures, and could result in the entity recognizing a gain or loss on the sale or transfer of nonfinancial assets.  At the time of adoption, there was no impact on our consolidated financial statements from this ASU.

Effective January 1, 2018, we adopted ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” which clarifies the definition of a business with the objective of adding guidance to assist in evaluating whether transactions should be accounted for as acquisitions of assets or businesses. The amendment provides a screen for determining when a transaction involves an acquisition of a business. If substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset, or a group of similar identifiable assets, then the screen is met and the transaction is not considered an acquisition of a business. If the screen is not met, the amendment requires that to be considered a business, the operation must include at a minimum an input and a substantive process that together significantly contribute to the ability to create an output. The guidance may reduce the number of future transactions accounted for as business acquisitions. At the time of adoption, there was no impact on our consolidated financial statements from this ASU.

Effective January 1, 2018, we adopted ASU No. 2016-16, “Income Taxes (Topic 740): Intra-Entity Asset Transfers of Assets Other Than Inventory.”  This ASU requires the income tax consequences of an intra-entity transfer of an asset, other than inventory, to be recognized when the transfer occurs.  At the time of adoption, this ASU did not have a material impact on our consolidated financial statements.

Effective January 1, 2018, we adopted ASU No. 2016-01, “Financial Instruments—Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The majority of this ASU’s provisions amend only the presentation or disclosures of financial instruments; however, one provision could also affect net income. Equity investments carried under the cost method or the lower of cost or fair value method of accounting, in accordance with previous generally accepted accounting principles in the United States (GAAP), will have to be carried at fair value with changes in fair value recorded in net income. For equity investments that do not have readily determinable fair values, a company may elect to carry such investments at cost less impairments, if any, adjusted up or down for price changes in similar financial instruments issued by the investee, when and if observed. At the time of adoption, this ASU did not have a material impact on our consolidated financial statements.





6


Effective January 1, 2018, we adopted ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” using the modified retrospective transition method applied to all contracts. Under the new guidance, recognition of revenue involves a multiple step approach including (i) identifying the contract, (ii) identifying the separate performance obligations, (iii) determining the transaction price, (iv) allocating the price to the performance obligations and (v) recognizing the revenue as the obligations are satisfied. Additional disclosures are required to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

We recorded noncash cumulative effect adjustments to our opening total equity balance as of January 1, 2018, to increase retained earnings by $35 million, net of $11 million of income taxes, and noncontrolling interests by $13 million. These adjustments primarily reflected amounts recorded by our equity-method investees related to contracts that contain tier-pricing and minimum volume commitments with recovery provisions. One of our equity-method investees will adopt this ASU in 2019, and we do not expect its adoption to have a material impact on our consolidated financial statements.

In addition, prospectively from January 1, 2018, our presentation of excise taxes on sales of petroleum products changed to a net basis from a gross basis. As a result, the “Sales and other operating revenues” and “Taxes other than income taxes” lines on our consolidated statement of income for the three and nine months ended September 30, 2018, are not presented on a comparable basis to the three and nine months ended September 30, 2017. See Note 3—Sales and Other Operating Revenues, for more information on our presentation of excise taxes on sales of petroleum products.


Note 3—Sales and Other Operating Revenues

Our revenues are primarily associated with sales of refined petroleum products, crude oil and natural gas liquids (NGL). Each gallon, or other unit of measure of product, is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. The transaction prices of our contracts with customers are either fixed or variable, with variable pricing based upon various market indices. For our contracts that include variable consideration, we utilize the variable consideration allocation exception, whereby the variable consideration is only allocated to the performance obligations that are satisfied during the period. The related revenue is recognized at a point in time when control passes to the customer, which is when title and the risk of ownership passes to the customer and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry.

Effective for reporting periods ending after our adoption of ASU No. 2014-09 on January 1, 2018, excise taxes on sales of petroleum products charged to our customers are presented net of excise taxes on sales of petroleum products owed to governmental authorities in the “Taxes other than income taxes” line on our consolidated statement of income. For reporting periods ending prior to January 1, 2018, excise taxes on sales of petroleum products charged to our customers are presented in the “Sales and other operating revenues” line on our consolidated statement of income, and excise taxes on sales of petroleum products owed to governmental authorities are presented in the “Taxes other than income taxes” line on our consolidated statement of income. See Note 2—Changes in Accounting Principles, for more information regarding our adoption of this ASU.

Revenues associated with pipeline transportation services are recognized at a point in time when the volumes are delivered based on contractual rates. Revenues associated with terminaling and storage services are recognized over time as the services are performed based on throughput volume or capacity utilization at contractual rates.

Our products and services are billed and payments are received typically on a monthly basis, which may vary based upon the product or service offered.

7


Disaggregated Revenues
The following tables present our disaggregated sales and other operating revenues:

 
Millions of Dollars
 
Three Months Ended
September 30

 
Nine Months Ended
September 30

 
2018

 
2018

Product Line and Services
 
 
 
Refined petroleum products
$
23,184

 
64,975

Crude oil resales
4,747

 
12,316

NGL
1,782

 
4,751

Services and other
75

 
321

Consolidated sales and other operating revenues
$
29,788


82,363

 
 
 
 
Geographic Location
 
 
 
United States
$
23,068

 
64,481

United Kingdom
3,085

 
7,623

Germany
1,135

 
3,174

Other foreign countries
2,500

 
7,085

Consolidated sales and other operating revenues
$
29,788


82,363



Contract-Related Assets and Liabilities
At September 30, 2018, and January 1, 2018, receivables from contracts with customers were $6.5 billion and $6.2 billion, respectively. Significant non-customer balances, such as buy/sell receivables and excise tax receivables, were excluded from these amounts.

Our contract-related assets also include payments we make to our marketing customers related to incentive programs. An incentive payment is initially recognized as an asset and subsequently amortized as a reduction to revenue over the contract term, which generally ranges from 5 to 15 years. At September 30, 2018, and January 1, 2018, our asset balances related to such payments were $237 million and $208 million, respectively.

Our contract liabilities represent advances from our customers prior to product or service delivery. At September 30, 2018, and January 1, 2018, contract liabilities were not material.

Remaining Performance Obligations
Most of our contracts with customers are spot contracts or term contracts with only variable consideration. We do not disclose remaining performance obligations for these contracts as the expected duration is one year or less or because the variable consideration has been allocated entirely to an unsatisfied performance obligation. We also have certain contracts in our Midstream segment that include minimum volume commitments with fixed pricing, most of which expire by 2021. The remaining performance obligations related to these minimum volume commitment contracts were immaterial at September 30, 2018.


8


Note 4—Inventories

Inventories consisted of the following:

 
Millions of Dollars
 
September 30
2018

 
December 31
2017

 
 
 
 
Crude oil and petroleum products
$
5,245

 
3,106

Materials and supplies
299

 
289

 
$
5,544

 
3,395



Inventories valued on the last-in, first-out (LIFO) basis totaled $5,153 million and $2,980 million at September 30, 2018, and December 31, 2017, respectively. The estimated excess of current replacement cost over LIFO cost of inventories amounted to approximately $6.6 billion and $4.3 billion at September 30, 2018, and December 31, 2017, respectively.


Note 5—Business Combinations

Merey Sweeny, L.P. (MSLP) is a limited partnership that owns a delayed coker and related facilities at the Sweeny Refinery. In February 2017, we began accounting for MSLP as a consolidated subsidiary because the exercise of a call right triggered by certain defaults by the co-venturer, Petróleos de Venezuela S.A. (PDVSA), with respect to supply of crude oil to the Sweeny Refinery ceased to be subject to legal challenge. The purchase price for PDVSA’s 50 percent ownership interest was determined by a contractual formula. Because the distributions PDVSA received from MSLP exceeded the amounts it contributed to MSLP, the contractual formula required no cash consideration for the acquisition. 

Based on a third-party appraisal of the fair value of MSLP’s net assets, utilizing discounted cash flows and replacement costs, the acquisition of PDVSA’s 50 percent interest resulted in the recognition of a pre-tax gain of $423 million during the three months ended March 31, 2017.  This gain was included in the “Other income” line on our consolidated statement of income. The fair value of our original equity interest in MSLP immediately prior to the deemed acquisition was $145 million. We also recorded $318 million of restricted cash, $250 million of properties, plants and equipment (PP&E) and $238 million of debt, as well as a net $93 million for the elimination of our equity investment in MSLP and net intercompany payables related to this transaction. Our acquisition accounting was finalized in the first quarter of 2017.

The results of MSLP were included in our Refining segment until October 2017, when we contributed our 100 percent interest in MSLP to Phillips 66 Partners LP (Phillips 66 Partners), which is a consolidated subsidiary in our Midstream segment.


9


Note 6—Investments, Loans and Long-Term Receivables

Equity Investments

Chevron Phillips Chemical Company LLC
Summarized 100 percent financial information for Chevron Phillips Chemical Company LLC (CPChem) was as follows:
 
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

 
 
 
 
 
 
Revenues and other income
$
3,393

2,287

 
9,329

7,196

Income before income taxes
552

345

 
1,819

1,469

Net income
531

331

 
1,766

1,424



Gray Oak Pipeline, LLC
Phillips 66 Partners has a 75 percent ownership interest in Gray Oak Pipeline, LLC (Gray Oak), an entity formed to develop and construct the Gray Oak Pipeline system which, upon completion, will provide crude oil transportation from the Permian Basin and Eagle Ford to destinations in the Corpus Christi and Freeport markets on the Texas Gulf Coast. The pipeline is expected to be placed in service by the end of 2019.

Gray Oak is considered a variable interest entity (VIE) because it does not have sufficient equity at risk to fully fund the construction of all assets required for principal operations. Phillips 66 Partners has determined it is not the primary beneficiary because it and its co-venturer jointly direct the activities of Gray Oak that most significantly impact economic performance. At September 30, 2018, Phillips 66 Partners’ maximum exposure to loss was $72 million, which represented the aggregate book value of its equity investment in Gray Oak.

Rockies Express Pipeline LLC
In July 2018, Rockies Express Pipeline LLC (REX) repaid $550 million of its debt, reducing its total debt to approximately $2.1 billion.  REX funded the repayment through member cash contributions.  Our 25 percent share was approximately $138 million and was contributed to REX in July 2018.

Related Party Loans and Advances
During the three months ended March 31, 2017, we received payment of the $250 million outstanding sponsor loans to the Dakota Access, LLC and Energy Transfer Crude Oil Company, LLC joint ventures. We also received payment of the $75 million outstanding principal balance of the partner loan we made to WRB Refining LP (WRB) in 2016. These cash inflows, totaling $325 million, are included in the “Collection of advances/loans—related parties” line on our consolidated statement of cash flows.



10


Note 7—Properties, Plants and Equipment

Our gross investment in PP&E and the associated accumulated depreciation and amortization (Accum. D&A) balances were as follows:

 
Millions of Dollars
 
September 30, 2018
 
December 31, 2017
 
Gross
PP&E

 
Accum.
D&A

 
Net
PP&E

 
Gross
PP&E

 
Accum.
D&A

 
Net
PP&E

 
 
 
 
 
 
 
 
 
 
 
 
Midstream
$
9,393

 
2,076

 
7,317

 
8,849

 
1,853

 
6,996

Chemicals

 

 

 

 

 

Refining
22,584

 
9,549

 
13,035

 
22,144

 
8,987

 
13,157

Marketing and Specialties
1,641

 
929

 
712

 
1,658

 
909

 
749

Corporate and Other
1,163

 
602

 
561

 
1,091

 
533

 
558

 
$
34,781

 
13,156

 
21,625

 
33,742

 
12,282

 
21,460



Note 8—Earnings Per Share

The numerator of basic earnings per share (EPS) is net income attributable to Phillips 66, reduced by noncancelable dividends paid on unvested share-based employee awards during the vesting period (participating securities). The denominator of basic EPS is the sum of the daily weighted-average number of common shares outstanding during the periods presented and fully vested stock and unit awards that have not yet been issued as common stock. The numerator of diluted EPS is also based on net income attributable to Phillips 66, which is reduced only by dividend equivalents paid on participating securities for which the dividends are more dilutive than the participation of the awards in the earnings of the periods presented. To the extent unvested stock, unit or option awards and vested unexercised stock options are dilutive, they are included with the weighted-average common shares outstanding in the denominator. Treasury stock is excluded from the denominator in both basic and diluted EPS.
  
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018
 
2017
 
2018
 
2017
 
Basic

Diluted

 
Basic

Diluted

 
Basic

Diluted

 
Basic

Diluted

Amounts attributed to Phillips 66 Common
Stockholders (millions):
 
 
 
 
 
 
 
 
 
 
 
Net income attributable to Phillips 66
$
1,492

1,492

 
823

823

 
3,355

3,355

 
1,908

1,908

Income allocated to participating securities
(1
)

 
(1
)

 
(4
)

 
(4
)
(1
)
Net income available to common stockholders
$
1,491

1,492


822

823

 
3,351

3,355


1,904

1,907

 
 
 
 
 
 
 
 
 
 
 
 
Weighted-average common shares outstanding (thousands):
463,002

466,109

 
509,147

512,923

 
470,471

473,760

 
513,583

517,420

Effect of share-based compensation
3,107

3,331

 
3,776

3,037

 
3,289

3,460

 
3,837

3,096

Weighted-average common shares outstanding—EPS
466,109

469,440

 
512,923

515,960

 
473,760

477,220

 
517,420

520,516

 
 
 
 
 
 
 
 
 
 
 
 
Earnings Per Share of Common Stock (dollars)
$
3.20

3.18

 
1.60

1.60

 
7.07

7.03

 
3.68

3.66




11


Note 9—Debt

Debt Issuances
In March 2018, Phillips 66 closed on a public offering of $1,500 million aggregate principal amount of unsecured notes consisting of:

$500 million of floating-rate Senior Notes due 2021. Interest on these notes is equal to the three-month London Interbank Offered Rate (LIBOR) plus 0.60% per annum and is payable quarterly in arrears on February 26, May 26, August 26 and November 26, beginning on May 29, 2018.

$800 million of 3.900% Senior Notes due 2028. Interest on these notes is payable semiannually on March 15 and September 15 of each year, beginning on September 15, 2018.

An additional $200 million of our 4.875% Senior Notes due 2044. Interest on these notes is payable semiannually on May 15 and November 15 of each year, beginning on May 15, 2018.
 
These notes are guaranteed by Phillips 66 Company, a wholly owned subsidiary. Phillips 66 used the net proceeds from the issuance of these notes and cash on hand to repay commercial paper borrowings during the three months ended March 31, 2018, and for general corporate purposes. The commercial paper borrowings during the three months ended March 31, 2018, were primarily used to repurchase shares of our common stock; see Note 16—Treasury Stock for additional information.

Debt Repayments
In June 2018, Phillips 66 repaid $250 million of the $450 million outstanding under its three-year term loan facility due 2020.

Debt Reclassifications
In April 2018, Phillips 66’s $300 million of floating-rate notes due 2019 were reclassified from long-term to short-term debt.


Note 10—Guarantees

At September 30, 2018, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability either because the guarantees were issued prior to December 31, 2002, or because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently performing with any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence.

Guarantees of Joint Venture Debt
In December 2016, as part of the restructuring within DCP Midstream, LLC (DCP Midstream), we issued a guarantee, effective January 1, 2017, to support the debt DCP Midstream issued during the three months ended March 31, 2017. Payment would be required if DCP Midstream defaults on this debt obligation, which matures in December 2019. At September 30, 2018, the maximum potential amount of future payments to third parties under the guarantee is estimated to be $105 million

At September 30, 2018, we had other guarantees outstanding for our portion of certain joint venture debt obligations, which have remaining terms of up to seven years. Payment would be required if a joint venture defaults on its debt obligations. The maximum potential amount of future payments to third parties under these guarantees was approximately $134 million.






12


Other Guarantees
Under the operating lease agreement on our headquarters facility in Houston, Texas, we have a residual value guarantee with a maximum future exposure of $554 million. The operating lease term ends in June 2021 and provides us the option, at the end of the lease term, to request to renew the lease, purchase the facility or assist the lessor in marketing it for resale.

We also have residual value guarantees associated with railcar and airplane leases with maximum future exposures totaling $319 million, which have remaining terms of up to five years. For one of our railcar leases, we estimated a total residual value deficiency of $56 million based on a third-party appraisal of the railcars’ expected fair value at the end of the lease term in May 2019. The total residual value deficiency is our estimate of the amount we will owe to the lessor at the end of the lease term and is recognized as expense over the remaining lease term. During the nine months ended September 30, 2018, we recognized $19 million of expense related to the residual value deficiency.  At September 30, 2018, the remaining unrecognized residual value deficiency was $17 million

Indemnifications
Over the years, we have entered into various agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to indemnification. Agreements associated with these sales include indemnifications for taxes, litigation, environmental liabilities, permits and licenses and employee claims, as well as real estate indemnity against tenant defaults. The provisions of these indemnifications vary greatly. The majority of these indemnifications are related to environmental issues, which generally have indefinite terms and potentially unlimited exposure. At September 30, 2018, the carrying amount recorded for indemnifications was $178 million.

We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have information to support that the liability was essentially relieved or amortize the liability over an appropriate time period as the fair value of our indemnification exposure declines. Although it is reasonably possible future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments. At September 30, 2018, environmental accruals for known contaminations of $107 million were included in the recorded carrying amount for indemnifications. These accruals were primarily included in the “Asset retirement obligations and accrued environmental costs” line on our consolidated balance sheet. For additional information about environmental liabilities, see Note 11—Contingencies and Commitments.

Indemnification and Release Agreement
In 2012, in connection with our separation from ConocoPhillips (the Separation), we entered into the Indemnification and Release Agreement. This agreement governs the treatment between ConocoPhillips and us of matters relating to indemnification, insurance, litigation responsibility and management, and litigation document sharing and cooperation arising in connection with the Separation. Generally, the agreement provides for cross-indemnities principally designed to place financial responsibility for the obligations and liabilities of our business with us and financial responsibility for the obligations and liabilities of ConocoPhillips’ business with ConocoPhillips. The agreement also establishes procedures for handling claims subject to indemnification and related matters.


Note 11—Contingencies and Commitments

A number of lawsuits involving a variety of claims that arose in the ordinary course of business have been filed against us or are subject to indemnifications provided by us. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for financial recognition or disclosure of these contingencies. In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. 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. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. In the case of income-tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain.


13


Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other potentially responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.

Environmental
We are subject to international, federal, state and local environmental laws and regulations. When we prepare our consolidated financial statements, we record accruals for environmental liabilities based on management’s best estimates, using all information available at the time. We measure estimates and base contingent liabilities on currently available facts, existing technology and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring contingent environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the U.S. Environmental Protection Agency (EPA) or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable.

Although liability for environmental remediation costs is generally joint and several for federal sites and frequently so for state sites, we are usually only one of many companies alleged to have liability at a particular site. Due to such joint and several liabilities, we could be responsible for all cleanup costs related to any site at which we have been designated as a potentially responsible party. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites at which we are potentially responsible are still under investigation by the EPA or the state agencies concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential liability, and we adjust our accruals accordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit, although some of the indemnifications are subject to dollar and time limits.

We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except those pertaining to sites acquired in a business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. At September 30, 2018, our total environmental accrual was $456 million, compared with $458 million at December 31, 2017. We expect to incur a substantial amount of these expenditures within the next 30 years. We have not reduced these accruals for possible insurance recoveries. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

Legal Proceedings
Our legal organization applies its knowledge, experience and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. Our process facilitates the early evaluation and quantification of potential exposures in individual cases and enables the tracking of those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required.


14


Other Contingencies
We have contingent liabilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized.

At September 30, 2018, we had performance obligations secured by letters of credit and bank guarantees of $628 million related to various purchase and other commitments incident to the ordinary conduct of business.


Note 12—Derivatives and Financial Instruments

Derivative Instruments
We use financial and commodity-based derivative contracts to manage exposures to fluctuations in commodity prices, interest rates and foreign currency exchange rates, or to capture market opportunities. Because we do not apply hedge accounting for commodity derivative contracts, all realized and unrealized gains and losses from commodity derivative contracts are recognized in our consolidated statement of income. Gains and losses from derivative contracts held for trading not directly related to our physical business are reported net in the “Other income” line on our consolidated statement of income. Cash flows from all our derivative activity for the periods presented appear in the operating section on our consolidated statement of cash flows.

Purchase and sales contracts with firm minimum notional volumes for commodities that are readily convertible to cash are recorded on our consolidated balance sheet as derivatives unless the contracts are eligible for, and we elect, the normal purchases and normal sales exception, whereby the contracts are recorded on an accrual basis. We generally apply the normal purchases and normal sales exception to eligible crude oil, refined petroleum products, NGL, natural gas and power commodity contracts to purchase or sell quantities we expect to use or sell in the normal course of business. All other derivative instruments are recorded at fair value on our consolidated balance sheet. For further information on the fair value of derivatives, see Note 13—Fair Value Measurements.

Commodity Derivative Contracts—We sell into or receive supply from the worldwide crude oil, refined petroleum products, NGL, natural gas and electric power markets, exposing our revenues, purchases, cost of operating activities and cash flows to fluctuations in the prices for these commodities. Generally, our policy is to remain exposed to the market prices of commodities; however, we use futures, forwards, swaps and options in various markets to balance physical systems, meet customer needs, manage price exposures on specific transactions, and do a limited, immaterial amount of trading not directly related to our physical business, all of which may reduce our exposure to fluctuations in market prices. We also use the market knowledge gained from these activities to capture market opportunities such as moving physical commodities to more profitable locations, storing commodities to capture seasonal or time premiums, and blending commodities to capture quality upgrades.

15


The following table indicates the consolidated balance sheet line items that include the fair values of commodity derivative assets and liabilities. The balances in the following table are presented on a gross basis, before the effects of counterparty and collateral netting. However, we have elected to present our commodity derivative assets and liabilities with the same counterparty on a net basis on our consolidated balance sheet when the right of setoff exists.

 
Millions of Dollars
 
September 30, 2018
 
December 31, 2017
 
Commodity Derivatives
Effect of Collateral Netting

Net Carrying Value Presented on the Balance Sheet

 
Commodity Derivatives
Effect of Collateral Netting

Net Carrying Value Presented on the Balance Sheet

 
Assets

Liabilities

 
Assets

Liabilities

 
 
 
 
 
 
 
 
 
 
Assets
 
 
 
 
 
 
 
 
 
Prepaid expenses and other current assets
$
58

(30
)
(4
)
24

 
43

(19
)

24

Other assets
11

(3
)

8

 
7

(3
)

4

Liabilities
 
 
 
 
 
 
 
 
 
Other accruals
1,078

(1,274
)
155

(41
)
 
699

(746
)
21

(26
)
Other liabilities and deferred credits
25

(26
)

(1
)
 

(1
)

(1
)
Total
$
1,172

(1,333
)
151

(10
)
 
749

(769
)
21

1

 

At September 30, 2018, and December 31, 2017, there was no material cash collateral received or paid that was not offset on our consolidated balance sheet.

The realized and unrealized gains (losses) incurred from commodity derivatives, and the line items where they appear on our consolidated statement of income, were:
 
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

 
 
 
 
 
 
Sales and other operating revenues
$
(98
)
(256
)
 
(227
)
(101
)
Other income
3

33

 
(17
)
46

Purchased crude oil and products
(138
)
(111
)
 
(311
)
16

Net loss from commodity derivative activity
$
(233
)
(334
)
 
(555
)
(39
)

16


The following table summarizes our material net exposures resulting from outstanding commodity derivative contracts. These financial and physical derivative contracts are primarily used to manage price exposure on our underlying operations. The underlying exposures may be from non-derivative positions such as inventory volumes. Financial derivative contracts may also offset physical derivative contracts, such as forward sales contracts. The percentage of our derivative contract volumes expiring within the next 12 months was at least 98 percent at September 30, 2018, and December 31, 2017.

 
Open Position
Long / (Short)
 
September 30
2018

 
December 31
2017

Commodity
 
 
 
Crude oil, refined petroleum products and NGL (millions of barrels)
(45
)
 
(11
)


Interest Rate Derivative Contracts—In 2016, we entered into interest rate swaps to hedge the variability of lease payments on our new headquarters. These monthly lease payments vary based on monthly changes in the one-month LIBOR and changes, if any, in our credit rating over the five-year term of the lease. The pay-fixed, receive-floating interest rate swaps have an aggregate notional value of $650 million and end in April 2021. We have designated these swaps as cash-flow hedges.

The aggregate net fair value of these swaps, which is included in the “Prepaid expenses and other current assets” and “Other assets” lines on our consolidated balance sheet, totaled $24 million and $14 million at September 30, 2018, and December 31, 2017, respectively.

We report the mark-to-market gains or losses on our interest rate swaps designated as highly effective cash-flow hedges as a component of other comprehensive income (loss), and reclassify such gains and losses into earnings in the same period during which the hedged transaction affects earnings. Net realized gains and losses from settlements of the swaps were immaterial for the three and nine months ended September 30, 2018 and 2017.

We currently estimate that pre-tax gains of $8 million will be reclassified from accumulated other comprehensive loss into general and administrative expenses during the next twelve months as the hedged transactions settle; however, the actual amounts that will be reclassified will vary based on changes in interest rates.

Credit Risk
Financial instruments potentially exposed to concentrations of credit risk consist primarily of over-the-counter (OTC) derivative contracts and trade receivables.

The credit risk from our OTC derivative contracts, such as forwards and swaps, derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significant nonperformance. We also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements until settled. However, we are exposed to the credit risk of those exchange brokers for receivables arising from daily margin cash calls, as well as for cash deposited to meet initial margin requirements.

Our trade receivables result primarily from the sale of products from, or related to, our refinery operations and reflect a broad national and international customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less. We continually monitor this exposure and the creditworthiness of the counterparties and recognize bad debt expense based on historical write-off experience or specific counterparty collectability. Generally, we do not require collateral to limit the exposure to loss; however, we will sometimes use letters of credit, prepayments or master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as these agreements permit the amounts owed by us or owed to others to be offset against amounts due to us.


17


Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if our credit ratings fall below investment grade. Cash is the primary collateral in all contracts; however, many contracts also permit us to post letters of credit as collateral.

The aggregate fair values of all derivative instruments with such credit-risk-related contingent features that were in a liability position were immaterial at September 30, 2018, and December 31, 2017.


Note 13—Fair Value Measurements

Recurring Fair Value Measurements
We carry certain assets and liabilities at fair value, which we measure at the reporting date using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability), and disclose the quality of these fair values based on the valuation inputs used in these measurements under the following hierarchy:

Level 1: Fair value measured with unadjusted quoted prices from an active market for identical assets or liabilities.
Level 2: Fair value measured either with: (1) adjusted quoted prices from an active market for similar assets or liabilities; or (2) other valuation inputs that are directly or indirectly observable.
Level 3: Fair value measured with unobservable inputs that are significant to the measurement.

We classify the fair value of an asset or liability based on the significance of its observable or unobservable inputs to the measurement. However, the fair value of an asset or liability initially reported as Level 3 will be subsequently reported as Level 2 if the unobservable inputs become inconsequential to its measurement or corroborating market data becomes available. Conversely, an asset or liability initially reported as Level 2 will be subsequently reported as Level 3 if corroborating market data becomes unavailable. For the nine months ended September 30, 2018, derivative assets with an aggregate value of $244 million and derivative liabilities with an aggregate value of $244 million were transferred to Level 1 from Level 2, as measured from the beginning of the reporting period. The measurements were reclassified within the fair value hierarchy due to the availability of unadjusted quoted prices from an active market.

We used the following methods and assumptions to estimate the fair value of financial instruments:

Cash and cash equivalents—The carrying amount reported on our consolidated balance sheet approximates fair value.
Accounts and notes receivable—The carrying amount reported on our consolidated balance sheet approximates fair value.
Derivative instruments—We fair value our exchange-traded contracts based on quoted market prices obtained from the New York Mercantile Exchange, the Intercontinental Exchange or other exchanges, and classify them as Level 1 in the fair value hierarchy. When exchange-cleared contracts lack sufficient liquidity, or are valued using either adjusted exchange-provided prices or non-exchange quotes, we classify those contracts as Level 2.
Physical commodity forward purchase and sales contracts are generally valued using forward quotes provided by brokers and price index developers, such as Platts and Oil Price Information Service. We corroborate these quotes with market data and classify the resulting fair values as Level 2. When forward market prices are not available, we estimate fair value using the forward price of a similar commodity, adjusted for the difference in quality or location. In certain less liquid markets or for longer-term contracts, forward prices are not as readily available. In these circumstances, physical commodity purchase and sales contracts are valued using internally developed methodologies that consider historical relationships among various commodities that result in management’s best estimate of fair value. We classify these contracts as Level 3. Physical commodity options are valued using industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets

18


determines whether the options are classified as Level 2 or 3. We use a mid-market pricing convention (the mid-point between bid and ask prices). When appropriate, valuations are adjusted to reflect credit considerations, generally based on available market evidence.
We determine the fair value of our interest rate swaps based on observed market valuations for interest rate swaps that have notional values, terms and pay and reset frequencies similar to ours.
Rabbi trust assets—These deferred compensation investments are measured at fair value using unadjusted quoted prices available from national securities exchanges and are therefore categorized as Level 1 in the fair value hierarchy.
Debt—The carrying amount of our floating-rate debt approximates fair value. The fair value of our fixed-rate debt is estimated based on observable market prices.

The following tables display the fair value hierarchy for our material financial assets and liabilities either accounted for or disclosed at fair value on a recurring basis. These values are determined by treating each contract as the fundamental unit of account; therefore, derivative assets and liabilities with the same counterparty are shown on a gross basis in the hierarchy sections of these tables, before the effects of counterparty and collateral netting. These tables also show that our Level 3 activity was immaterial.

We have master netting agreements for all of our exchange-cleared derivative instruments and certain of our physical commodity forward contracts (primarily pipeline crude oil deliveries). The following tables show the impact of these agreements in the column “Effect of Counterparty Netting.”

The carrying values and fair values by hierarchy of our material financial instruments and commodity forward contracts, either carried or disclosed at fair value, including any effects of netting derivative assets with liabilities and netting collateral due to right of setoff or master netting agreements, were:

 
Millions of Dollars
 
September 30, 2018
 
Fair Value Hierarchy
 
Total Fair Value of Gross Assets & Liabilities

Effect of Counterparty Netting

Effect of Collateral Netting

Difference in Carrying Value and Fair Value

Net Carrying Value Presented on the Balance Sheet

 
Level 1

 
Level 2

 
Level 3

Commodity Derivative Assets
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
672

 
480

 

 
1,152

(1,136
)
(4
)

12

Physical forward contracts

 
19

 
1

 
20




20

Interest rate derivatives

 
24

 

 
24




24

Rabbi trust assets
121

 

 

 
121

N/A

N/A


121

 
$
793

 
523

 
1

 
1,317

(1,136
)
(4
)

177

 
 
 
 
 
 
 
 
 
 
 
 
Commodity Derivative Liabilities
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
790

 
501

 

 
1,291

(1,136
)
(155
)


Physical forward contracts

 
38

 
4

 
42




42

Floating-rate debt

 
1,375

 

 
1,375

N/A

N/A


1,375

Fixed-rate debt, excluding capital leases

 
10,132

 

 
10,132

N/A

N/A

(359
)
9,773

 
$
790

 
12,046

 
4

 
12,840

(1,136
)
(155
)
(359
)
11,190





19


 
Millions of Dollars
 
December 31, 2017
 
Fair Value Hierarchy
 
Total Fair Value of Gross Assets & Liabilities

Effect of Counterparty Netting

Effect of Collateral Netting

Difference in Carrying Value and Fair Value

Net Carrying Value Presented on the Balance Sheet

 
Level 1

 
Level 2

 
Level 3

 
Commodity Derivative Assets
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
333

 
395

 

 
728

(721
)


7

Physical forward contracts

 
20

 
1

 
21




21

Interest rate derivatives

 
14

 

 
14




14

Rabbi trust assets
112

 

 

 
112

N/A

N/A


112

 
$
445

 
429

 
1

 
875

(721
)


154

 
 
 
 
 
 
 
 
 
 
 
 
Commodity Derivative Liabilities
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
369

 
373

 

 
742

(721
)
(21
)


Physical forward contracts

 
23

 
4

 
27




27

Floating-rate debt

 
1,150

 

 
1,150

N/A

N/A


1,150

Fixed-rate debt, excluding capital leases

 
9,746

 

 
9,746

N/A

N/A

(978
)
8,768

 
$
369

 
11,292

 
4

 
11,665

(721
)
(21
)
(978
)
9,945



The rabbi trust assets are recorded in the “Investments and long-term receivables” line and the floating-rate and fixed-rate debt are recorded in the “Short-term debt” and “Long-term debt” lines on our consolidated balance sheet. For information regarding the location of our commodity derivative assets and liabilities on our consolidated balance sheet, see the first table in Note 12—Derivatives and Financial Instruments.

Nonrecurring Fair Value Measurements
See Note 5—Business Combinations, for information on the remeasurement of our investment in MSLP to fair value in 2017. During the nine months ended September 30, 2018 and 2017, there were no other material nonrecurring fair value remeasurements of assets subsequent to their initial recognition.



20


Note 14—Pension and Postretirement Plans

The components of net periodic benefit cost for the three and nine months ended September 30, 2018 and 2017, were as follows:
 
Millions of Dollars
 
Pension Benefits
 
Other Benefits
 
2018
 
2017
 
2018

 
2017

 
U.S.

 
Int’l.

 
U.S.

 
Int’l.

 
 
 
 
Components of Net Periodic Benefit Cost
 
 
 
 
 
 
 
 
 
 
 
Three Months Ended September 30
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
34

 
5

 
33

 
8

 
2

 
1

Interest cost
26

 
6

 
27

 
7

 
1

 
2

Expected return on plan assets
(42
)
 
(11
)
 
(37
)
 
(11
)
 

 

Amortization of prior service cost

 

 
1

 

 

 

Recognized net actuarial loss
14

 
5

 
17

 
6

 

 

Settlements
49

 

 
21

 

 

 

Net periodic benefit cost*
$
81


5


62


10


3


3

 
 
 
 
 
 
 
 
 
 
 
 
Nine Months Ended September 30
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
102

 
22

 
99

 
25

 
5

 
4

Interest cost
78

 
21

 
81

 
20

 
5

 
6

Expected return on plan assets
(127
)
 
(35
)
 
(110
)
 
(30
)
 

 

Amortization of prior service cost (credit)

 
(1
)
 
2

 
(1
)
 
(1
)
 
(1
)
Recognized net actuarial loss
44

 
15

 
52

 
18

 

 

Settlements
54

 

 
76

 

 

 

Net periodic benefit cost*
$
151

 
22

 
200

 
32

 
9

 
9

* Included in the “Operating expenses” and “Selling, general and administrative expenses” lines on our consolidated statement of income.


During the nine months ended September 30, 2018, we contributed $133 million to our U.S. employee benefit plans and $26 million to our international employee benefit plans. We currently expect to make additional contributions of approximately $20 million to our U.S. employee benefit plans and $10 million to our international employee benefit plans during the remainder of 2018.

During 2018 and 2017, lump-sum benefit payments exceeded the sum of service and interest costs for our U.S. pension plans. As a result, we recognized a proportionate share of prior actuarial losses, or pension settlement expense, totaling $54 million and $76 million for the nine months ended September 30, 2018 and 2017, respectively.

21


Note 15—Accumulated Other Comprehensive Loss

Changes in the balances of each component of accumulated other comprehensive loss were as follows:
 
Millions of Dollars
 
Defined Benefit Plans

 
Foreign Currency Translation

 
Hedging

 
Accumulated Other Comprehensive Loss

 
 
 
 
 
 
 
 
December 31, 2016
$
(713
)
 
(285
)
 
3

 
(995
)
Other comprehensive income before reclassifications
5

 
214

 

 
219

Amounts reclassified from accumulated other comprehensive loss*
 
 
 
 
 
 
 
Amortization of defined benefit plan items**
 
 
 
 
 
 
 
Net actuarial loss, prior service credit and settlements
92

 

 

 
92

Net current period other comprehensive income
97

 
214

 

 
311

September 30, 2017
$
(616
)
 
(71
)
 
3

 
(684
)
 
 
 
 
 
 
 
 
December 31, 2017
$
(598
)
 
(26
)
 
7

 
(617
)
Other comprehensive income (loss) before reclassifications
10

 
(113
)
 
9

 
(94
)
Amounts reclassified from accumulated other comprehensive loss
 
 
 
 
 
 


Amortization of defined benefit plan items**
 
 
 
 
 
 
 
Net actuarial loss, prior service credit and settlements
84

 

 

 
84

Foreign currency translation

 
(10
)
 

 
(10
)
Hedging

 

 
(2
)
 
(2
)
Net current period other comprehensive income (loss)
94

 
(123
)
 
7

 
(22
)
September 30, 2018
$
(504
)
 
(149
)
 
14

 
(639
)
* There were no significant reclassifications related to hedging or foreign currency translation in the prior year period.
** Included in the computation of net periodic benefit cost. See Note 14—Pension and Postretirement Plans, for additional information.



Note 16—Treasury Stock

In February 2018, we entered into a Stock Purchase and Sale Agreement (Purchase Agreement) with Berkshire Hathaway Inc. and National Indemnity Company, a wholly owned subsidiary of Berkshire Hathaway, to repurchase 35 million shares of Phillips 66 common stock for an aggregate purchase price of $3,280 million. Pursuant to the Purchase Agreement, the purchase price per share of $93.725 was based on the volume-weighted-average price of our common stock on the New York Stock Exchange on February 13, 2018. The transaction closed in February 2018. We funded the repurchase with cash of $1,880 million and borrowings of $1,400 million under our commercial paper program. These borrowings were subsequently refinanced through a public offering of senior notes in March 2018. This specific share repurchase transaction was separately authorized by our Board of Directors and therefore does not impact previously announced authorizations to repurchase shares of Phillips 66 common stock under our share repurchase program, which total up to $12.0 billion. See Note 9—Debt, for additional information regarding our borrowing activity during the nine months ended September 30, 2018.


Note 17—Restricted Cash

At September 30, 2018, and December 31, 2017, the company did not have any restricted cash. The restrictions on the cash acquired in February 2017, as a result of the consolidation of MSLP, were fully removed in May 2017 when MSLP’s outstanding debt that contained lender restrictions on the use of cash was paid in full. See Note 5—Business Combinations, for additional information regarding our consolidation of MSLP.


22


Note 18—Related Party Transactions

Significant transactions with related parties were:

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

 
 
 
 
 
 
Operating revenues and other income (a)
$
955

638

 
2,717

1,778

Purchases (b)
3,667

2,557

 
9,534

6,932

Operating expenses and selling, general and administrative expenses (c)
12

13

 
44

52


(a)
We sold NGL and other petrochemical feedstocks, along with solvents, to CPChem, gas oil and hydrogen feedstocks to Excel Paralubes (Excel), and refined petroleum products to OnCue Holdings, LLC. We also sold certain feedstocks and intermediate products to WRB and acted as agent for WRB in supplying crude oil and other feedstocks for a fee. In addition, we charged several of our affiliates, including CPChem, for the use of common facilities, such as steam generators, waste and water treaters and warehouse facilities.

(b)
We purchased crude oil and refined petroleum products from WRB and also acted as agent for WRB in distributing solvents. We also purchased natural gas and NGL from DCP Midstream and CPChem, as well as other feedstocks from various affiliates, for use in our refinery and fractionation processes. In addition, we purchased base oils and fuel products from Excel for use in our specialty and refining businesses. We paid NGL fractionation fees to CPChem. We also paid fees to various pipeline affiliates for transporting crude oil, refined petroleum products and NGL.
 
(c)
We paid utility and processing fees to various affiliates.


23


Note 19—Segment Disclosures and Related Information

Our operating segments are:

1)
Midstream—Provides crude oil and refined petroleum products transportation, terminaling and processing services, as well as natural gas, NGL and liquefied petroleum gas (LPG) transportation, storage, processing and marketing services, mainly in the United States. The Midstream segment includes our master limited partnership, Phillips 66 Partners, as well as our 50 percent equity investment in DCP Midstream.

2)
Chemicals—Consists of our 50 percent equity investment in CPChem, which manufactures and markets petrochemicals and plastics on a worldwide basis.

3)
Refining—Refines crude oil and other feedstocks into petroleum products (such as gasoline, distillates and aviation fuels) at 13 refineries in the United States and Europe.

4)
Marketing and Specialties—Purchases for resale and markets refined petroleum products, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products, as well as power generation operations.

Corporate and Other includes general corporate overhead, interest expense, our investments in new technologies and various other corporate activities. Corporate assets include all cash and cash equivalents.

During the fourth quarter of 2017, the segment performance measure used by our chief executive officer to assess performance and allocate resources was changed from “net income attributable to Phillips 66” to “net income.”  This change reflects the recognition that management does not differentiate between those earnings attributable to Phillips 66 and those attributable to noncontrolling interests when making operating and resource allocation decisions impacting segment performance.  Prior period segment information has been recast to conform to the current presentation. Intersegment sales are at prices that we believe approximate market.

24


Analysis of Results by Operating Segment

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2018

2017

 
2018

2017

Sales and Other Operating Revenues
 
 
 
 
 
Midstream
 
 
 
 
 
Total sales
$
2,287

1,433

 
6,234

4,467

Intersegment eliminations
(524
)
(433
)
 
(1,555
)
(1,260
)
Total Midstream
1,763

1,000

 
4,679

3,207

Chemicals
1

2

 
4

4

Refining
 
 
 
 
 
Total sales
21,949

16,499

 
61,707

46,014

Intersegment eliminations
(12,807
)
(10,461
)
 
(37,027
)
(28,641
)
Total Refining
9,142

6,038

 
24,680

17,373

Marketing and Specialties
 
 
 
 
 
Total sales
19,332

18,887

 
54,471

52,903

Intersegment eliminations
(457
)
(306
)
 
(1,492
)
(900
)
Total Marketing and Specialties
18,875

18,581

 
52,979

52,003

Corporate and Other
7

6

 
21

21

Consolidated sales and other operating revenues
$
29,788

25,627

 
82,363

72,608

 
 
 
 
 
 
Net Income (Loss)
 
 
 
 
 
Midstream
$
240

117

 
675

325

Chemicals
210

121

 
704

498

Refining
936

550

 
1,937

1,033

Marketing and Specialties
318

208

 
739

563

Corporate and Other
(136
)
(147
)
 
(498
)
(426
)
Consolidated net income
$
1,568

849

 
3,557

1,993


 
Millions of Dollars
 
September 30
2018

 
December 31
2017

Total Assets
 
 
 
Midstream
$
14,123

 
13,231

Chemicals
6,378

 
6,226

Refining
25,959

 
23,820

Marketing and Specialties
7,581

 
7,103

Corporate and Other
1,843

 
3,991

Consolidated total assets
$
55,884

 
54,371




25


Note 20—Income Taxes

Our effective income tax rate for the three and nine months ended September 30, 2018, was 21 percent, compared with 32 percent and 31 percent for the corresponding periods of 2017. The decrease was primarily attributable to the enactment of the U.S. Tax Cuts and Jobs Act (the Tax Act) in December 2017, which reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent beginning January 1, 2018. The effective income tax rates in the 2018 periods did not vary from the U.S. federal statutory income tax rate of 21 percent as the effect of state income tax expense was primarily offset by adjustments to the provisional income tax benefit related to the Tax Act, and the tax benefits associated with our foreign operations and income attributable to noncontrolling interests.

During the three and nine months ended September 30, 2018, we recorded income tax benefits of $49 million and $20 million, respectively, to adjust the provisional income tax benefit recorded in December 2017 upon enactment of the Tax Act. The adjustments to date were primarily due to the revision of our estimated deferred income tax balances in conjunction with the filing of our 2017 income tax return and the issuance of additional guidance by the U.S. Internal Revenue Service related to the calculation of the one-time deemed repatriation tax. We have not yet completed our accounting for the income tax effects of the Tax Act; however, we have made reasonable estimates of the effects on our existing deferred income tax balances and the one-time deemed repatriation tax. The final financial statement impact of the Tax Act may differ from our previously recorded estimates, possibly materially, due to, among other things, changes in interpretations of the Tax Act, any legislative action to address questions that arise because of the Tax Act, and changes in accounting standards for income taxes or related interpretations in response to the Tax Act, or any updates or changes to estimates the company has utilized to calculate the provisional impacts. The U.S. Securities and Exchange Commission has issued rules that allow for a measurement period of up to one year after the enactment date of the Tax Act to finalize the recording of the related income tax impacts.


Note 21—Phillips 66 Partners LP

In 2013, we formed Phillips 66 Partners, a publicly traded master limited partnership, to own, operate, develop and acquire primarily fee-based crude oil, refined petroleum products and NGL pipelines, terminals and other midstream assets. Headquartered in Houston, Texas, Phillips 66 Partners’ operations currently consist of crude oil, refined petroleum products and NGL transportation, processing, terminaling and storage assets.
 
We consolidate Phillips 66 Partners because we determined it is a VIE of which we are the primary beneficiary. As general partner of Phillips 66 Partners, we have the ability to control its financial interests, as well as the ability to direct the activities that most significantly impact its economic performance. As a result of this consolidation, the public common and perpetual convertible preferred unitholders’ ownership interests in Phillips 66 Partners are reflected as noncontrolling interests in our financial statements. At September 30, 2018, we owned a 54 percent limited partner interest and a 2 percent general partner interest in Phillips 66 Partners, while the public owned a 44 percent limited partner interest and 13.8 million perpetual convertible preferred units.

The most significant assets of Phillips 66 Partners that are available to settle only its obligations, along with its most significant liabilities for which its creditors do not have recourse to Phillips 66’s general credit, were:

 
Millions of Dollars
 
September 30
2018

 
December 31
2017

 
 
 
 
Cash and cash equivalents
$
100

 
185

Equity investments*
2,215

 
1,932

Net properties, plants and equipment
2,999

 
2,918

Long-term debt
2,922

 
2,920

* Included in “Investments and long-term receivables” line on the Phillips 66 consolidated balance sheet.

26


Financing Activities
Phillips 66 Partners’ initial $250 million continuous offering of common units, or at-the-market (ATM) program, was completed in June 2018.  At that time, Phillips 66 Partners commenced issuing common units under its second $250 million ATM program. For the nine months ended September 30, 2018 and 2017, on a settlement-date basis, Phillips 66 Partners generated net proceeds of $114 million and $171 million, respectively, from common units issued under the ATM programs. Since inception through September 30, 2018, the ATM programs generated net proceeds of $306 million.


Note 22—New Accounting Standards

In February 2018, the FASB issued ASU No. 2018-02, “Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” This ASU allows for the deferred income tax effects stranded in accumulated other comprehensive income (AOCI) resulting from the Tax Act enacted in December 2017 to be reclassed from AOCI to retained earnings. This ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018, with early adoption permitted. We are currently evaluating the impact of this ASU on our consolidated financial statements.