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Phillips 66 - Quarter Report: 2014 September (Form 10-Q)

Table of Contents

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, 2014
 

 
 
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.)

3010 Briarpark Drive, 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, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer   [X]        Accelerated filer  [    ]        Non-accelerated filer   [    ]        Smaller reporting company  [    ]
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 553,513,402 shares of common stock, $.01 par value, outstanding as of September 30, 2014.


Table of Contents

PHILLIPS 66

TABLE OF CONTENTS
 
 
Page
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 




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
 
2014

2013

 
2014

2013

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues*
$
40,417

44,146

 
126,249

128,547

Equity in earnings of affiliates
511

647

 
2,053

2,304

Net gain on dispositions
109

8

 
125

50

Other income (loss)
11

(7
)
 
59

65

Total Revenues and Other Income
41,048

44,794

 
128,486

130,966

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products
33,602

38,717

 
107,299

111,217

Operating expenses
1,104

992

 
3,271

3,002

Selling, general and administrative expenses
401

349

 
1,215

1,044

Depreciation and amortization
249

233

 
722

704

Impairments
12

1

 
16

26

Taxes other than income taxes*
3,874

3,624

 
11,344

10,449

Accretion on discounted liabilities
6

6

 
18

18

Interest and debt expense
60

68

 
194

207

Foreign currency transaction losses (gains)
13


 
23

(16
)
Total Costs and Expenses
39,321

43,990

 
124,102

126,651

Income from continuing operations before income taxes
1,727

804

 
4,384

4,315

Provision for income taxes
538

278

 
1,451

1,448

Income From Continuing Operations
1,189

526

 
2,933

2,867

Income from discontinued operations**

14

 
706

43

Net Income
1,189

540

 
3,639

2,910

Less: net income attributable to noncontrolling interests
9

5

 
24

10

Net Income Attributable to Phillips 66
$
1,180

535

 
3,615

2,900

 
 
 
 
 
 
Amounts Attributable to Phillips 66 Common Stockholders:
 
 
 
 
 
Income from continuing operations
$
1,180

521

 
2,909

2,857

Income from discontinued operations

14

 
706

43

Net Income Attributable to Phillips 66
$
1,180

535

 
3,615

2,900

 
 
 
 
 
 
Net Income Attributable to Phillips 66 Per Share of Common Stock (dollars)
 
 
 
 
 
Basic
 
 
 
 
 
Continuing operations
$
2.11

0.86

 
5.10

4.62

Discontinued operations

0.02

 
1.24

0.07

Net Income Attributable to Phillips 66 Per Share of Common Stock
$
2.11

0.88

 
6.34

4.69

Diluted
 
 
 
 
 
Continuing operations
$
2.09

0.85

 
5.05

4.58

Discontinued operations

0.02

 
1.23

0.07

Net Income Attributable to Phillips 66 Per Share of Common Stock
$
2.09

0.87

 
6.28

4.65

 
 
 
 
 
 
Dividends Paid Per Share of Common Stock (dollars)
$
0.5000

0.3125

 
1.3900

0.9375

 
 
 
 
 
 
Average Common Shares Outstanding (in thousands)
 
 
 
 
 
Basic
559,492

608,934

 
569,692

617,654

Diluted
564,958

614,519

 
575,589

623,846

* Includes excise taxes on petroleum products sales:
$
3,781

3,568

 
11,046

10,254

** Net of provision for income taxes on discontinued operations:
$

8

 
5

23

Prior period amounts have been recast to reflect discontinued operations.
 
 
 
 
 
See Notes to Consolidated Financial Statements.
 
 
 
 
 

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Table of Contents

Consolidated Statement of Comprehensive Income
Phillips 66
 
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
 
 
 
 
 
Net Income
$
1,189

540

 
3,639

2,910

Other comprehensive income (loss)
 
 
 
 
 
Defined benefit plans
 
 
 
 
 
Actuarial gain/loss:
 
 
 
 
 
Amortization to net income of net actuarial loss
15

22

 
41

72

Plans sponsored by equity affiliates
4

6

 
10

(2
)
Income taxes on defined benefit plans
(5
)
(11
)
 
(16
)
(25
)
Defined benefit plans, net of tax
14

17

 
35

45

Foreign currency translation adjustments
(233
)
186

 
(106
)
(98
)
Income taxes on foreign currency translation adjustments
8

(4
)
 
9

(1
)
Foreign currency translation adjustments, net of tax
(225
)
182

 
(97
)
(99
)
Hedging activities by equity affiliates


 

1

Income taxes on hedging activities by equity affiliates


 


Hedging activities by equity affiliates, net of tax


 

1

Other Comprehensive Income (Loss), Net of Tax
(211
)
199

 
(62
)
(53
)
Comprehensive Income
978

739

 
3,577

2,857

Less: comprehensive income attributable to noncontrolling interests
9

5

 
24

10

Comprehensive Income Attributable to Phillips 66
$
969

734

 
3,553

2,847

See Notes to Consolidated Financial Statements.

2

Table of Contents

Consolidated Balance Sheet
Phillips 66
 
 
Millions of Dollars
 
September 30
2014

 
December 31
2013

Assets
 
 
 
Cash and cash equivalents
$
3,108

 
5,400

Accounts and notes receivable (net of allowances of $43 million in 2014 and $47 million in 2013)
7,043

 
7,900

Accounts and notes receivable—related parties
1,723

 
1,732

Inventories
5,673

 
3,354

Prepaid expenses and other current assets
647

 
851

Total Current Assets
18,194

 
19,237

Investments and long-term receivables
10,237

 
11,220

Net properties, plants and equipment
16,951

 
15,398

Goodwill
3,275

 
3,096

Intangibles
819

 
698

Other assets
174

 
149

Total Assets
$
49,650

 
49,798

 
 
 
 
Liabilities
 
 
 
Accounts payable
$
10,381

 
9,948

Accounts payable—related parties
1,089

 
1,142

Short-term debt
35

 
24

Accrued income and other taxes
945

 
872

Employee benefit obligations
363

 
476

Other accruals
956

 
469

Total Current Liabilities
13,769

 
12,931

Long-term debt
6,178

 
6,131

Asset retirement obligations and accrued environmental costs
726

 
700

Deferred income taxes
5,632

 
6,125

Employee benefit obligations
842

 
921

Other liabilities and deferred credits
309

 
598

Total Liabilities
27,456

 
27,406

 
 
 
 
Equity
 
 
 
Common stock (2,500,000,000 shares authorized at $.01 par value)
     Issued (2014—636,940,692 shares; 2013—634,285,955 shares)
 
 
 
Par value
6

 
6

Capital in excess of par
19,028

 
18,887

Treasury stock (at cost: 2014—83,427,290 shares; 2013—44,106,380 shares)
(5,702
)
 
(2,602
)
Retained earnings
8,439

 
5,622

Accumulated other comprehensive income (loss)
(25
)
 
37

Total Stockholders’ Equity
21,746

 
21,950

Noncontrolling interests
448

 
442

Total Equity
22,194

 
22,392

Total Liabilities and Equity
$
49,650

 
49,798

See Notes to Consolidated Financial Statements.

3

Table of Contents

Consolidated Statement of Cash Flows
Phillips 66
 
Millions of Dollars
 
Nine Months Ended
September 30
 
2014

 
2013

Cash Flows From Operating Activities
 
 
 
Net income
$
3,639

 
2,910

Adjustments to reconcile net income to net cash provided by operating activities
 
 
 
Depreciation and amortization
722

 
704

Impairments
16

 
26

Accretion on discounted liabilities
18

 
18

Deferred taxes
(527
)
 
282

Undistributed equity earnings
360

 
(76
)
Net gain on dispositions
(125
)
 
(50
)
Income from discontinued operations
(706
)
 
(43
)
Other
70

 
34

Working capital adjustments
 
 
 
Decrease (increase) in accounts and notes receivable
810

 
535

Decrease (increase) in inventories
(2,336
)
 
(1,353
)
Decrease (increase) in prepaid expenses and other current assets
(95
)
 
(90
)
Increase (decrease) in accounts payable
299

 
2,017

Increase (decrease) in taxes and other accruals
510

 
163

Net cash provided by continuing operating activities
2,655

 
5,077

Net cash provided by discontinued operations
2

 
53

Net Cash Provided by Operating Activities
2,657

 
5,130

 
 
 
 
Cash Flows From Investing Activities
 
 
 
Capital expenditures and investments
(2,647
)
 
(1,156
)
Proceeds from asset dispositions*
663

 
1,188

Advances/loans—related parties
(3
)
 
(65
)
Collection of advances/loans—related parties

 
100

Other
161

 

Net cash provided by (used in) continuing investing activities
(1,826
)
 
67

Net cash used in discontinued operations
(2
)
 
(14
)
Net Cash Provided by (Used in) Investing Activities
(1,828
)
 
53

 
 
 
 
Cash Flows From Financing Activities
 
 
 
Repayment of debt
(30
)
 
(1,015
)
Issuance of common stock
1

 
(4
)
Repurchase of common stock
(1,750
)
 
(1,602
)
Share exchange—PSPI transaction
(450
)
 

Dividends paid on common stock
(787
)
 
(575
)
Distributions to noncontrolling interests
(18
)
 
(1
)
Net proceeds from issuance of Phillips 66 Partners LP common units

 
404

Other
23

 
(4
)
Net cash used in continuing financing activities
(3,011
)
 
(2,797
)
Net cash provided by (used in) discontinued operations

 

Net Cash Used in Financing Activities
(3,011
)
 
(2,797
)
 
 
 
 
Effect of Exchange Rate Changes on Cash and Cash Equivalents
(110
)
 
82

 
 
 
 
Net Change in Cash and Cash Equivalents
(2,292
)
 
2,468

Cash and cash equivalents at beginning of period
5,400

 
3,474

Cash and Cash Equivalents at End of Period
$
3,108

 
5,942

* Includes return of investments in equity affiliates.
Prior period amounts have been recast to reflect discontinued operations.
See Notes to Consolidated Financial Statements.

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Table of Contents

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 Income (Loss)

Noncontrolling
Interests

Total

 
 
 
 
 
 
 
 
December 31, 2012
$
6

18,726

(356
)
2,713

(314
)
31

20,806

Net income



2,900


10

2,910

Other comprehensive loss




(53
)

(53
)
Cash dividends paid on common stock



(575
)


(575
)
Repurchase of common stock


(1,602
)



(1,602
)
Benefit plan activity

116


(8
)


108

Issuance of Phillips 66 Partners LP common units





404

404

Distributions to noncontrolling interests and other

(3
)



(1
)
(4
)
September 30, 2013
$
6

18,839

(1,958
)
5,030

(367
)
444

21,994

 
 
 
 
 
 
 
 
December 31, 2013
$
6

18,887

(2,602
)
5,622

37

442

22,392

Net income



3,615


24

3,639

Other comprehensive loss




(62
)

(62
)
Cash dividends paid on common stock



(787
)


(787
)
Repurchase of common stock


(1,750
)



(1,750
)
Share exchange—PSPI transaction


(1,350
)



(1,350
)
Benefit plan activity

141


(11
)


130

Distributions to noncontrolling interests and other





(18
)
(18
)
September 30, 2014
$
6

19,028

(5,702
)
8,439

(25
)
448

22,194

 

 
Shares in Thousands
 
Common Stock Issued

Treasury Stock

December 31, 2012
631,150

7,604

Repurchase of common stock

26,645

Shares issued—share-based compensation
2,635


September 30, 2013
633,785

34,249

 
 
 
December 31, 2013
634,286

44,106

Repurchase of common stock

21,898

Share exchange—PSPI transaction

17,423

Shares issued—share-based compensation
2,655


September 30, 2014
636,941

83,427

See Notes to Consolidated Financial Statements.

5

Table of Contents

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 2013 Annual Report on Form 10-K. The results of operations for the three and nine months ended September 30, 2014, are not necessarily indicative of the results to be expected for the full year.

Certain prior period financial information has been recast to reflect a change in the composition of our operating segments. See Note 21—Segment Disclosures and Related Information, for additional information.


Note 2—Changes in Accounting Principles

Effective July 1, 2014, we early adopted the Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” This ASU amends the definition of discontinued operations so that only disposals of components of an entity representing major strategic shifts that have a major effect on an entity’s operations and financial results will qualify for discontinued operations reporting. The ASU also requires additional disclosures about discontinued operations and individually material disposals that do not meet the definition of a discontinued operation. The adoption of this ASU did not have an effect on our consolidated financial statements.


Note 3—Variable Interest Entities (VIEs)

In 2013, we formed Phillips 66 Partners LP, a master limited partnership, to own, operate, develop and acquire primarily fee-based crude oil, refined petroleum product and natural gas liquids pipelines and terminals, as well as other transportation and midstream assets. We consolidate Phillips 66 Partners as we determined that Phillips 66 Partners is a VIE and we are the primary beneficiary. As general partner, we have the ability to control its financial interests, as well as the ability to direct the activities of Phillips 66 Partners that most significantly impact its economic performance. See Note 23—Phillips 66 Partners LP, for additional information.

We hold significant variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on these VIEs follows:

Merey Sweeny, L.P. (MSLP) is a limited partnership that owns a delayed coker and related facilities at the Sweeny Refinery. As discussed more fully in Note 7—Investments, Loans and Long-Term Receivables, in August 2009, a call right was exercised to acquire the 50 percent ownership interest in MSLP of the co-venturer, Petróleos de Venezuela S.A. (PDVSA). That exercise was challenged, and the dispute has been arbitrated. In April 2014, the arbitral tribunal upheld the exercise of the call right and the acquisition of the 50 percent ownership interest. In July 2014, PDVSA filed a petition to vacate the tribunal’s award. Until this matter is resolved, we will continue to use the equity method of accounting for MSLP, and the VIE analysis below is based on the ownership and governance structure in place prior to the exercise of the call right. MSLP is a VIE because, in securing lender consents in connection with our separation from ConocoPhillips in 2012 (the Separation), we provided a 100 percent debt guarantee to the lender of the 8.85% senior notes issued by MSLP. PDVSA did not participate in the debt guarantee. In our VIE assessment, this disproportionate debt guarantee, plus other liquidity support provided jointly by us and PDVSA independently of equity ownership, results in MSLP not being exposed to all potential losses. We have determined we are not the primary beneficiary while our call exercise award is subject to vacatur because under the partnership agreement the co-venturers jointly direct the activities of MSLP that most significantly impact economic performance. At September 30, 2014, our maximum exposure to loss represented the outstanding debt principal balance of $203 million and our investment of $131 million.

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We have a 50 percent ownership interest with a 50 percent governance interest in Excel Paralubes (Excel). Excel is a VIE because, in securing lender consents in connection with the Separation, ConocoPhillips provided a 50 percent debt guarantee to the lender of the 7.43% senior secured bonds issued by Excel. We provided a full indemnity to ConocoPhillips for this debt guarantee. Our co-venturer did not participate in the debt guarantee. In our assessment of the VIE, this debt guarantee, plus other liquidity support up to $60 million provided jointly by us and our co-venturer independently of equity ownership, results in Excel not being exposed to all potential losses. We have determined we are not the primary beneficiary because we and our co-venturer jointly direct the activities of Excel that most significantly impact economic performance. We use the equity method of accounting for this investment. At September 30, 2014, our maximum exposure to loss represented 50 percent of the outstanding debt principal balance of $86 million, or $43 million, plus half of the $60 million liquidity support, or $30 million. The book value of our investment in Excel at September 30, 2014, was $124 million.

In 2013, we entered into a multi-year consignment fuels agreement with a marketer who we currently support with debt guarantees. Pursuant to the consignment fuels agreement, we own the fuels inventory, control the fuel marketing at each site and pay a fixed monthly fee to the marketer. We determined the consignment fuels agreement and the debt guarantees together create a variable interest in the marketer, with the marketer not being exposed to all potential losses. We determined we are not the primary beneficiary because we do not have the power to direct the activities that most significantly impact the economic performance of the marketer or its service stations. We have no ownership interest in the marketer. At September 30, 2014, our maximum exposure to loss represented the outstanding debt balance of $190 million and the fixed annual contractual payments under the consignment fuels agreement of approximately $90 million.


Note 4—Inventories

Inventories consisted of the following:

 
Millions of Dollars
 
September 30
2014

 
December 31
2013

 
 
 
 
Crude oil and petroleum products
$
5,412

 
3,093

Materials and supplies
261

 
261

 
$
5,673

 
3,354



Inventories valued on the last-in, first-out (LIFO) basis totaled $5,252 million and $2,945 million at September 30, 2014, and December 31, 2013, respectively. The estimated excess of current replacement cost over LIFO cost of inventories amounted to approximately $7,400 million and $7,600 million at September 30, 2014, and December 31, 2013, respectively.


Note 5—Business Combinations

We completed the following acquisitions during the first nine months of 2014:

In August 2014, we acquired a 7.1 million-barrel-storage-capacity crude oil and petroleum products terminal located near Beaumont, Texas, to promote growth plans in our Midstream business.
In July 2014, we acquired Spectrum Corporation, a private label and specialty lubricants business headquartered in Memphis, Tennessee. The acquisition supports our plans to selectively grow stable-return businesses in our Marketing and Specialties (M&S) segment.
In March 2014, we acquired our co-venturer’s interest in an entity that operates a power and steam generation plant located in Texas that is included in our M&S segment. This acquisition provided us with full operational control over a key facility providing utilities and other services to one of our refineries.

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Table of Contents

We funded each of these acquisitions with cash on hand. Total cash consideration paid was $741 million, net of cash acquired, and this amount is included in the “Capital expenditures and investments” line of our consolidated statement of cash flows. In the aggregate, we provisionally recorded $592 million of properties, plants and equipment (PP&E), $179 million of goodwill, $110 million of intangible assets, $70 million of net working capital and $92 million of assumed long-term liabilities. The completion of our acquisition accounting for these transactions is subject to the finalization of valuations of the assets acquired and liabilities assumed.


Note 6—Assets Held for Sale or Sold

In July 2014, we entered into an agreement to sell the Bantry Bay terminal in Ireland, which is included in our Refining segment. Following regulatory review, the transaction is expected to close in the fourth quarter of 2014. As of September 30, 2014, the net assets of the terminal were classified as held for sale, which resulted in a before-tax impairment of $12 million from reducing the carrying value of the long-lived assets to estimated fair value less costs to sell. In addition, we reclassified long-lived assets of $77 million to the “Prepaid expenses and other current assets” line of our consolidated balance sheet. The long-term liabilities reclassified to the “Other accruals” line of our consolidated balance sheet were not material.

In December 2013, we entered into an agreement to exchange the stock of Phillips Specialty Products Inc. (PSPI), a flow improver business, which was included in our M&S segment, for shares of Phillips 66 common stock owned by the other party. Accordingly, as of December 31, 2013, the net assets of PSPI were classified as held for sale and the results of operations of PSPI were reported as discontinued operations. At December 31, 2013, PSPI had a net carrying value of $193 million, which primarily included $58 million of net PP&E and $117 million of allocated goodwill. The carrying amounts of PSPI’s assets and liabilities at December 31, 2013, were reported in the “Prepaid expenses and other current assets” and “Other accruals” lines of our consolidated balance sheet, respectively.

On February 25, 2014, we completed the PSPI share exchange, resulting in the receipt of approximately 17.4 million shares of Phillips 66 common stock, which are held as treasury shares, and the recognition of a before-tax gain of $696 million. At the time of the disposition, PSPI had a net carrying value of $685 million, which primarily included $481 million of cash and cash equivalents, $60 million of net PP&E and $117 million of allocated goodwill. Cash and cash equivalents of $450 million included in PSPI’s net carrying value is reflected as a financing cash outflow in the “Share exchange—PSPI transaction” line of our consolidated statement of cash flows. Revenues, income before-tax and net income from discontinued operations, excluding the recognized before-tax gain of $696 million, were not material for the nine-month periods ended September 30, 2014 and 2013.

In July 2013, we completed the sale of the Immingham Combined Heat and Power Plant (ICHP), which was included in our M&S segment. At the time of the disposition, ICHP had a net carrying value of $762 million, which primarily included $724 million of net PP&E, $110 million of allocated goodwill, and $111 million of deferred tax liabilities. A gain was deferred due to an indemnity provided to the buyer. A portion of the deferred gain is denominated in a foreign currency; accordingly, the amount of the deferred gain translated into U.S. dollars is subject to change based on currency fluctuations. Absent claims under the indemnity, the deferred gain will be recognized into earnings as our exposure under this indemnity declines. As of December 31, 2013, the deferred gain was $375 million. In the third quarter of 2014, we recognized $109 million of the previously deferred gain, which is included in the “Net gain on dispositions” line of our consolidated statement of income. As of September 30, 2014, the remaining deferred gain was $265 million.

In May 2013, we sold our E-Gas™ Technology business. The business was included in our M&S segment and at the time of disposition had a net carrying value of approximately $13 million, including a goodwill allocation. The $48 million before-tax gain is included in the “Net gain on dispositions” line of our consolidated income statement.



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Table of Contents

Note 7—Investments, Loans and Long-Term Receivables

Equity Investments
Summarized 100 percent financial information for WRB Refining LP (WRB) and Chevron Phillips Chemical Company LLC (CPChem) were as follows:
 
 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

 
2013

 
2014

 
2013

 
 
 
 
 
 
 
 
Revenues
$
7,896

 
8,754

 
24,579

 
24,974

Income before income taxes
784

 
820

 
3,094

 
3,585

Net income
758

 
801

 
3,021

 
3,526




WRB
WRB is a 50-percent-owned business venture with Cenovus Energy Inc. (Cenovus). Cenovus was obligated to contribute $7.5 billion, plus accrued interest, to WRB over a 10-year period that began in 2007. In the first quarter of 2014, Cenovus prepaid its remaining balance under this obligation. As a result, WRB declared a special dividend, which was distributed to the co-venturers in March 2014. Of the $1,232 million that we received, $760 million was considered a return on our investment in WRB (an operating cash inflow), and $472 million was considered a return of our investment in WRB (an investing cash inflow). The return of investment portion of the dividend was included in the “Proceeds from assets dispositions” line in our consolidated statement of cash flows. At September 30, 2014, the book value of our investment in WRB was $1,933 million and our basis difference was $3,418 million.

Other
MSLP owns a delayed coker and related facilities at the Sweeny Refinery. MSLP processes long residue, which is produced from heavy sour crude oil, for a processing fee. Fuel-grade petroleum coke is produced as a by-product and becomes the property of MSLP. Prior to August 28, 2009, MSLP was owned 50/50 by ConocoPhillips and PDVSA. Under the agreements that govern the relationships between the partners, certain defaults by PDVSA with respect to supply of crude oil to the Sweeny Refinery triggered the right to acquire PDVSA’s 50 percent ownership interest in MSLP, which was exercised on August 28, 2009. PDVSA initiated arbitration with the International Chamber of Commerce challenging the exercise of the call right and claiming it was invalid. The arbitral tribunal held hearings on the merits of the dispute in December 2012, and post-hearing briefs were exchanged in March 2013. The arbitral tribunal issued its ruling in April 2014, which upheld the exercise of the call right and the acquisition of the 50 percent ownership interest. In July 2014, PDVSA filed a petition in U.S. district court to vacate the tribunal’s ruling.  Following the Separation, Phillips 66 generally indemnifies ConocoPhillips for liabilities, if any, arising out of the exercise of the call right or otherwise with respect to the joint venture or the refinery. Until this matter is resolved, we will continue to use the equity method of accounting for our investment in MSLP.



9

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Note 8—Properties, Plants and Equipment

Our investment in PP&E, with the associated accumulated depreciation and amortization (Accum. D&A), was:

 
Millions of Dollars
 
September 30, 2014
 
December 31, 2013
 
Gross
PP&E

 
Accum.
D&A

 
Net
PP&E

 
Gross
PP&E

 
Accum.
D&A

 
Net
PP&E

 
 
 
 
 
 
 
 
 
 
 
 
Midstream
$
4,285

 
1,160

 
3,125

 
2,865

 
1,104

 
1,761

Chemicals

 

 

 

 

 

Refining
19,699

 
7,162

 
12,537

 
19,191

 
6,718

 
12,473

Marketing and Specialties
1,493

 
744

 
749

 
1,395

 
749

 
646

Corporate and Other
1,063

 
523

 
540

 
975

 
457

 
518

Discontinued Operations*

 

 

 

 

 

 
$
26,540

 
9,589

 
16,951

 
24,426

 
9,028

 
15,398

* At December 31, 2013, net PP&E of $58 million associated with discontinued operations was classified as current assets.


Note 9—Goodwill

Effective January 1, 2014, we reallocated $52 million of goodwill from the Refining segment to the M&S segment based upon the realignment of certain assets between the reporting units. Goodwill was reassigned to the reporting units using a relative fair value approach. Goodwill impairment testing was completed and no impairment recognition was required. See Note 21—Segment Disclosures and Related Information, for additional information on this segment realignment.

See Note 5—Business Combinations, and Note 6—Assets Held for Sale or Sold, for information on goodwill assigned to business acquisitions and dispositions, respectively.

The carrying amount of goodwill was as follows:
 
Millions of Dollars
 
September 30
2014

 
December 31
2013

 
 
 
 
Midstream
$
543

 
518

Refining
1,867

 
1,867

Marketing and Specialties
865

 
711

 
$
3,275

 
3,096




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Note 10—Impairments

The three- and nine-month periods ended September 30, 2014 and 2013, included the following before-tax impairment charges:

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013


 
 
 
 
 
Refining
$
12

1

 
14

2

Marketing and Specialties


 
2

15

Corporate and Other


 

9

 
$
12

1

 
16

26



During the third quarter of 2014, we recorded a $12 million held-for-sale impairment in our Refining segment related to the Bantry Bay terminal. See Note 6—Assets Held for Sale or Sold, for additional information.

During the nine-month period of 2013, we recorded a $15 million held-for-use impairment in our M&S segment, primarily related to PP&E associated with our planned exit from the composite graphite business.
  

Note 11—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.
  

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Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014
 
2013
 
2014
 
2013
 
Basic

Diluted

 
Basic

Diluted

 
Basic

Diluted

 
Basic

Diluted

Amounts attributed to Phillips 66 Common Stockholders (millions):
 
 
 
 
 
 
 
 
 
 
 
Income from continuing operations attributable to Phillips 66
$
1,180

1,180

 
521

521

 
2,909

2,909

 
2,857

2,857

Income allocated to participating securities
(2
)

 
(2
)

 
(5
)

 
(4
)

Income from continuing operations available to common stockholders
1,178

1,180

 
519

521

 
2,904

2,909

 
2,853

2,857

Discontinued operations


 
14

14

 
706

706

 
43

43

Net Income available to common stockholders
$
1,178

1,180

 
533

535

 
3,610

3,615

 
2,896

2,900

 
 
 
 
 
 
 
 
 
 
 
 
Weighted-average common shares outstanding (thousands):
555,677

559,492

 
605,176

608,934

 
565,831

569,692

 
613,896

617,654

Effect of stock-based compensation
3,815

5,466

 
3,758

5,585

 
3,861

5,897

 
3,758

6,192

Weighted-average common shares outstanding—EPS
559,492

564,958

 
608,934

614,519

 
569,692

575,589

 
617,654

623,846

 
 
 
 
 
 
 
 
 
 
 
 
Earnings Per Share of Common Stock (dollars):
 
 
 
 
 
 
 
 
 
 
 
Income from continuing operations attributable to Phillips 66
$
2.11

2.09

 
0.86

0.85

 
5.10

5.05

 
4.62

4.58

Discontinued operations


 
0.02

0.02

 
1.24

1.23

 
0.07

0.07

Earnings Per Share
$
2.11

2.09

 
0.88

0.87

 
6.34

6.28

 
4.69

4.65



12

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Note 12—Debt

At both September 30, 2014, and December 31, 2013, we had no direct outstanding borrowings under our $4.5 billion revolving credit agreement, while $51 million in letters of credit had been issued that were supported by it. At September 30, 2014, and December 31, 2013, no amount had been drawn on the $250 million revolving credit agreement of Phillips 66 Partners. Accordingly, as of September 30, 2014, an aggregate $4.7 billion of total capacity was available under these facilities.

At September 30, 2014, we classified $800 million of debt due within one year as long-term debt, based on our intent to refinance the obligation on a long-term basis and our ability to do so under our revolving credit facility.

Effective September 30, 2014, we terminated our $696 million trade receivables securitization facility. No amounts were drawn against this facility throughout its duration, and at the time of termination no letters of credit were outstanding thereunder.


Note 13—Guarantees

At September 30, 2014, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, 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 April 2012, in connection with the Separation, we issued a guarantee for 100 percent of the 8.85% senior notes issued by MSLP in July 1999. At September 30, 2014, the maximum potential amount of future payments to third parties under the guarantee was estimated to be $203 million, which could become payable if MSLP fails to meet its obligations under the senior notes agreement. The senior notes mature in 2019.

Other Guarantees
We have residual value guarantees associated with leases with maximum future potential payments totaling $292 million. We have other guarantees with maximum future potential payment amounts totaling $310 million, which consist primarily of guarantees to fund the short-term cash liquidity deficits of certain joint ventures, guarantees of third parties related to prior asset dispositions, and guarantees of the lease payment obligations of a joint venture. These guarantees generally extend up to 10 years or life of the venture.

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 qualifying indemnifications. Agreements associated with these sales include indemnifications for taxes, litigation, environmental liabilities, permits and licenses, supply arrangements, and employee claims; and real estate indemnity against tenant defaults. The provisions of these indemnifications vary greatly. The majority of these indemnifications are related to environmental issues, the term is generally indefinite, and the maximum amount of future payments is generally unlimited. The carrying amount recorded for indemnifications at September 30, 2014, was $234 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 the liability is 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. Included in the recorded carrying amount were $107 million of environmental accruals for known contamination that were included in asset retirement obligations and accrued environmental costs at September 30, 2014. For additional information about environmental liabilities, see Note 14—Contingencies and Commitments.


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Table of Contents

Indemnification and Release Agreement
In 2012, we entered into the Indemnification and Release Agreement with ConocoPhillips. 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 14—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 accounting 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 record 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.

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 liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring 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 of those potentially responsible 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 the 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 and some of the indemnifications are subject to dollar and time limits.


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Table of Contents

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 purchase 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, 2014, our total environmental accrual was $519 million, compared with $492 million at December 31, 2013. 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. This process also enables us to track 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.

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, 2014, we had performance obligations secured by letters of credit and bank guarantees of $834 million ($51 million of which were issued under the provisions of our revolving credit facility, and the remainder were issued as direct bank letters of credit and bank guarantees) related to various purchase and other commitments incident to the ordinary conduct of business.


Note 15—Derivatives and Financial Instruments

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

Purchase and sales contracts with fixed minimum notional volumes for commodities that are readily convertible to cash (e.g., crude oil and gasoline) are recorded on the balance sheet as derivatives unless the contracts are eligible for, and we elect, the normal purchases and normal sales exception (i.e., contracts to purchase or sell quantities we expect to use or sell over a reasonable period in the normal course of business). We generally apply this normal purchases and normal sales exception to eligible crude oil, refined product, natural gas and power commodity purchase and sales contracts; however, we may elect not to apply this exception (e.g., when another derivative instrument will be used to mitigate the risk of the purchase or sales contract but hedge accounting will not be applied, in which case both the purchase or sales contract and the derivative contract mitigating the resulting risk will be recorded on the balance sheet at fair value).

Our derivative instruments are held at fair value on our consolidated balance sheet. For further information on the fair value of derivatives, see Note 16—Fair Value Measurements.

Commodity Derivative Contracts—We operate in the worldwide crude oil, refined products, natural gas liquids (NGL), natural gas and electric power markets and are exposed to fluctuations in the prices for these commodities. These fluctuations can affect our revenues, as well as the cost of operating, investing and financing activities. Generally, our policy is to remain exposed to the market prices of commodities; however, we use futures, forwards, swaps and options

15

Table of Contents

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. 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. Derivatives may be used to optimize these activities, which may move our risk profile away from market average prices.

The following table indicates the balance sheet line items that include the fair values of commodity derivative assets and liabilities presented net (i.e., commodity derivative assets and liabilities with the same counterparty are netted where the right of setoff exists); however, the balances in the following table are presented gross. For information on the impact of counterparty netting and collateral netting, see Note 16—Fair Value Measurements.

 
Millions of Dollars
 
September 30
2014

 
December 31
2013

Assets
 
 
 
Accounts and notes receivable
$

 
2

Prepaid expenses and other current assets
1,359

 
592

Other assets
9

 
2

Liabilities
 
 
 
Other accruals
1,151

 
633

Other liabilities and deferred credits
6

 
1

Hedge accounting has not been used for any item in the table.


The gains (losses) from commodity derivatives incurred, 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
 
2014

 
2013

 
2014

 
2013

 
 
 
 
 
 
 
 
Sales and other operating revenues
$
179

 
(44
)
 
208

 
74

Equity in earnings of affiliates
6

 
(12
)
 
4

 
(13
)
Other income (loss)
(3
)
 
(24
)
 
12

 
3

Purchased crude oil and products
71

 
(78
)
 
28

 
85

Hedge accounting has not been used for any item in the table.


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. As of September 30, 2014, and December 31, 2013, the percentage of our derivative contract volume expiring within the next 12 months was over 99 percent for both periods.
 
 
Open Position
Long/(Short)
 
September 30
2014

 
December 31
2013

Commodity
 
 
 
Crude oil, refined products and NGL (millions of barrels)
(31
)
 
(9
)



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Table of Contents

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, and 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 us.

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 not material at September 30, 2014, or December 31, 2013.


Note 16—Fair Value Measurements

Fair Values of Financial Instruments
We used the following methods and assumptions to estimate the fair value of financial instruments:

Cash and cash equivalents: The carrying amount reported on the consolidated balance sheet approximates fair value.
Accounts and notes receivable: The carrying amount reported on the consolidated balance sheet approximates fair value.
Debt: The carrying amount of our floating-rate debt approximates fair value. The fair value of our fixed-rate debt is estimated based on quoted market prices.
Commodity swaps: Fair value is estimated based on forward market prices and approximates the exit price at period end. When forward market prices are not available, fair value is estimated using the forward prices of a similar commodity with adjustments for differences in quality or location.
Futures: Fair values are based on quoted market prices obtained from the New York Mercantile Exchange, the InterContinental Exchange Futures or other traded exchanges.
Forward-exchange contracts: Fair values are estimated by comparing the contract rate to the forward rate in effect at the end of the respective reporting periods and approximating the exit price at those dates.

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Table of Contents

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 with: 1) adjusted quoted prices from an active market for similar assets; 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 lowest level of input significant to its 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. We made no material transfers in or out of Level 1 during the nine-month periods ended September 30, 2014 and 2013.

Recurring Fair Value Measurements
Financial assets and liabilities recorded at fair value on a recurring basis consist primarily of investments to support nonqualified deferred compensation plans and derivative instruments. The deferred compensation investments are measured at fair value using unadjusted prices available from national securities exchanges; therefore, these assets are categorized as Level 1 in the fair value hierarchy. We value our exchange-traded commodity derivatives using closing prices provided by the exchange as of the balance sheet date, and these are also classified 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. OTC financial swaps and physical commodity forward purchase and sales contracts are generally valued using quotations 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. In certain less liquid markets or for longer-term contracts, forward prices are not as readily available. In these circumstances, OTC swaps and 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. Financial OTC and 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 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.

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 gross (i.e., without the effect of netting where the legal right of setoff exists) in the hierarchy sections of these tables. These tables also show that our Level 3 activity was not material.

We have master netting arrangements for all of our exchange-cleared derivative instruments, the majority of our OTC derivative instruments, and certain physical commodity forward contracts (primarily pipeline crude oil deliveries). The following tables show these contracts on a net basis in the column “Effect of Counterparty Netting.” We have no contracts that are subject to master netting arrangements that are reflected gross on the consolidated balance sheet.


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Table of Contents

The carrying values and fair values by hierarchy of our material financial instruments, either carried or disclosed at fair value, and derivative assets and liabilities, including any effects of master netting agreements or collateral, were:
 
Millions of Dollars
 
September 30, 2014
 
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

Cash Collateral Received or Paid, Not Offset on Balance Sheet

 
Level 1

 
Level 2

 
Level 3

Commodity Derivative Assets
 
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
918

 
326

 

 
1,244

(1,098
)
(13
)

133

3

OTC instruments

 
55

 

 
55

(18
)


37


Physical forward contracts*

 
64

 
5

 
69

(8
)


61


Rabbi trust assets
75

 

 

 
75

N/A

N/A


75

N/A

 
$
993

 
445

 
5

 
1,443

(1,124
)
(13
)

306

 
 
 
 
 
 
 
 
 
 
 
 
 
 
Commodity Derivative Liabilities
 
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
837

 
261

 

 
1,098

(1,098
)




OTC instruments

 
21

 

 
21

(18
)


3


Physical forward contracts*

 
38

 

 
38

(8
)


30


Floating-rate debt
51

 

 

 
51

N/A

N/A


51

N/A

Fixed-rate debt, excluding capital leases**

 
6,405

 

 
6,405

N/A

N/A

(452
)
5,953

N/A

 
$
888

 
6,725

 

 
7,613

(1,124
)

(452
)
6,037


* Physical forward contracts may have a larger value on the balance sheet than disclosed in the fair value hierarchy when the remaining contract term at the reporting date is greater than 12 months and the short-term portion is an asset while the long-term portion is a liability, or vice versa.
** We carry fixed-rate debt on the balance sheet at amortized cost.


 
Millions of Dollars
 
December 31, 2013
 
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

Cash Collateral Received or Paid, Not Offset on Balance Sheet

 
Level 1

 
Level 2

 
Level 3

 
Commodity Derivative Assets
 
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
227

 
332

 

 
559

(538
)


21


OTC instruments

 
10

 

 
10

(8
)


2


Physical forward contracts*

 
25

 
2

 
27




27


Rabbi trust assets
64

 

 

 
64

N/A

N/A


64

N/A

 
$
291

 
367

 
2

 
660

(546
)


114



 
 
 
 
 
 
 
 
 
 
 
 
 
Commodity Derivative Liabilities
 
 
 
 
 
 
 
 
 
 
 
 
Exchange-cleared instruments
$
253

 
326

 

 
579

(538
)
(41
)



OTC instruments

 
11

 

 
11

(8
)


3


Physical forward contracts*

 
43

 
1

 
44




44


Floating-rate debt
50

 

 

 
50

N/A

N/A


50

N/A

Fixed-rate debt, excluding capital leases**

 
6,168

 

 
6,168

N/A

N/A

(262
)
5,906

N/A

 
$
303

 
6,548

 
1

 
6,852

(546
)
(41
)
(262
)
6,003


* Physical forward contracts may have a larger value on the balance sheet than disclosed in the fair value hierarchy when the remaining contract term at the reporting date is greater than 12 months and the short-term portion is an asset while the long-term portion is a liability, or vice versa.
** We carry fixed-rate debt on the balance sheet at amortized cost.

19

Table of Contents

The values presented in the preceding tables appear on our balance sheet as follows: for commodity derivative assets and liabilities, see the first table in Note 15—Derivatives and Financial Instruments; rabbi trust assets appear in the “Investments and long-term receivables” line; and floating-rate and fixed-rate debt appear in the “Short-term debt” and “Long-term debt” lines.

Nonrecurring Fair Value Remeasurements
The following table shows the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition during the nine-month periods ended September 30, 2014 and 2013:

 
Millions of Dollars
 
 
 
Fair Value
Measurements Using
 
 
 
Fair Value*

 
Level 1
Inputs

 
Level 2
Inputs

 
Level 3
Inputs

 
Before-
Tax Loss

September 30, 2014
 
 
 
 
 
 
 
 
 
Net asset disposal group (held for sale)
$
72

 
72

 

 

 
12

 
 
 
 
 
 
 
 
 
 
September 30, 2013
 
 
 
 
 
 
 
 
 
Net properties, plants and equipment (held for use)
$
22

 
22

 

 

 
27

* Represents the fair value at the time of the impairment.


During the nine-month period ended September 30, 2014, net assets related to the Bantry Bay terminal in our Refining segment, with a carrying amount of $84 million, primarily consisting of net PP&E, were written down to fair value less costs to sell, resulting in a before-tax loss of $12 million. This impairment was attributed to the long-lived assets in the disposal group. The fair value was determined by a negotiated selling price with a third party. See Note 6—Assets Held for Sale or Sold, for additional information.

During the nine-month period ended September 30, 2013, net PP&E held for use related to the composite graphite business in our M&S segment, with a carrying amount of $18 million, was written down to its fair value, resulting in a before-tax loss of $18 million. The fair value was based on an internal assessment of expected discounted future cash flows. During this same period, corporate net PP&E held for use, with a carrying amount of $31 million, was written down to its fair value of $22 million, resulting in a before-tax loss of $9 million. The fair value was primarily determined by a third-party valuation.



20

Table of Contents

Note 17—Employee Benefit Plans

Pension and Postretirement Plans
The components of net periodic benefit cost for the three and nine months ended September 30, 2014 and 2013, were as follows:
 
 
Millions of Dollars
 
Pension Benefits
 
Other Benefits
 
2014
 
2013
 
2014

 
2013

 
U.S.

 
Int’l.

 
U.S.

 
Int’l.

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

 
9

 
31

 
9

 
1

 
2

Interest cost
27

 
9

 
23

 
7

 
2

 
2

Expected return on plan assets
(35
)
 
(9
)
 
(30
)
 
(7
)
 

 

Amortization of prior service cost
1

 

 
1

 

 

 

Recognized net actuarial loss
10

 
3

 
21

 
4

 

 

Total net periodic benefit cost
$
33


12


46


13


3


4

 
 
 
 
 
 
 
 
 
 
 
 
Nine Months Ended September 30
 
 
 
 
 
 
 
 
 
 
 
Service cost
$
91

 
29

 
93

 
27

 
5

 
6

Interest cost
81

 
27

 
69

 
23

 
6

 
5

Expected return on plan assets
(106
)
 
(28
)
 
(90
)
 
(22
)
 

 

Amortization of prior service cost (credit)
2

 
(1
)
 
2

 
(1
)
 
(1
)
 
(1
)
Recognized net actuarial loss (gain)
30

 
9

 
63

 
12

 
(1
)
 

Total net periodic benefit cost
$
98

 
36

 
137

 
39

 
9

 
10



During the first nine months of 2014, we contributed $166 million to our U.S. plans and $46 million to our international plans. We currently expect to make additional contributions of approximately $30 million in 2014, primarily to our international plans.


21

Table of Contents

Note 18—Accumulated Other Comprehensive Income (Loss)

The following table depicts changes in accumulated other comprehensive income (loss) by component, as well as detail on reclassifications out of accumulated other comprehensive income (loss):
 
 
Millions of Dollars
 
Defined Benefit Plans

 
Foreign Currency Translation

 
Hedging

 
Accumulated Other Comprehensive Income (Loss)

 
 
 
 
 
 
 
 
December 31, 2012
$
(778
)
 
466

 
(2
)
 
(314
)
Other comprehensive income (loss) before reclassifications
(1
)
 
(99
)
 
1

 
(99
)
Amounts reclassified from accumulated other comprehensive income (loss)*
 
 
 
 
 
 
 
Amortization of defined benefit plan items**
 
 
 
 
 
 
 
Actuarial losses
46

 

 

 
46

Net current period other comprehensive income (loss)
45

 
(99
)
 
1

 
(53
)
September 30, 2013
$
(733
)
 
367

 
(1
)
 
(367
)
 
 
 
 
 
 
 
 
December 31, 2013
$
(404
)
 
443

 
(2
)
 
37

Other comprehensive income (loss) before reclassifications
6

 
(97
)
 

 
(91
)
Amounts reclassified from accumulated other comprehensive income (loss)*
 
 
 
 
 
 


Amortization of defined benefit plan items**
 
 
 
 
 
 
 
Actuarial losses
29

 

 

 
29

Net current period other comprehensive income (loss)
35

 
(97
)
 

 
(62
)
September 30, 2014
$
(369
)
 
346

 
(2
)
 
(25
)
* There were no significant reclassifications related to foreign currency translation or hedging.
** These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 17—Employee Benefit Plans, for additional information).


Note 19—Cash Flow Information
 
 
Millions of Dollars
 
Nine Months Ended
 
September 30
 
2014

 
2013

Noncash Investing and Financing Activities
 
 
 
Increase in net PP&E and debt related to capital lease obligation
$
24

 
177

 
 
 
 
Cash Payments
 
 
 
Interest
$
131

 
146

Income taxes
1,734

 
1,001



PSPI Noncash Stock Exchange
As discussed more fully in Note 6—Assets Held for Sale or Sold, on February 25, 2014, we completed the exchange of our flow improvers business for shares of Phillips 66 common stock owned by the other party to the transaction. The noncash portion of the net assets surrendered by us in the exchange was $204 million, and we received approximately 17.4 million shares of our common stock, with a fair value at the time of the exchange of $1.35 billion.


22

Table of Contents

Note 20—Related Party Transactions

Significant transactions with related parties were:

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

 
2013

 
2014

 
2013

 
 
 
 
 
 
 
 
Operating revenues and other income (a)
$
1,653

 
2,066

 
5,306

 
5,865

Purchases (b)
3,772

 
4,996

 
12,298

 
13,757

Operating expenses and selling, general and administrative expenses (c)
33

 
28

 
109

 
80

Interest expense (d)
2

 
2

 
6

 
6


(a)
We sold crude oil to the Malaysian Refining Company Sdn. Bdh. (MRC). NGL and other petrochemical feedstocks, along with solvents, were sold to CPChem, and gas oil and hydrogen feedstocks were sold to Excel. Certain feedstocks and intermediate products were sold to WRB. We also acted as agent for WRB in supplying other crude oil and feedstocks, wherein the transactional amounts did not impact operating revenues. In addition, we charged several of our affiliates, including CPChem and MSLP, for the use of common facilities, such as steam generators, waste and water treaters, and warehouse facilities.

(b)
We purchased refined products from WRB. We also acted as agent for WRB in distributing asphalt and solvents, wherein the transactional amounts did not impact purchases. We purchased natural gas and NGL from DCP Midstream, LLC (DCP Midstream) and CPChem for use in our refinery processes and other feedstocks from various affiliates. We purchased refined products from MRC. We also paid fees to various pipeline equity companies for transporting finished refined products. In addition, we paid a price upgrade to MSLP for heavy crude processing. We purchased base oils and fuel products from Excel for use in our refining and specialty businesses.

(c)
We paid utility, commission and processing fees to various affiliates.

(d)
We incurred interest expense on a note payable to MSLP.


23

Table of Contents

Note 21—Segment Disclosures and Related Information

Our operating segments are:

1)
Midstream—Gathers, processes, transports and markets natural gas; and transports, fractionates and markets NGL in the United States. In addition, this segment transports crude oil and other feedstocks to our refineries and other locations, and delivers refined and specialty products to market. The Midstream segment includes, among other businesses, our 50 percent equity investment in DCP Midstream and our investment in Phillips 66 Partners LP.

2)
Chemicals—Manufactures and markets petrochemicals and plastics on a worldwide basis. The Chemicals segment consists of our 50 percent equity investment in CPChem.

3)
Refining—Buys, sells and refines crude oil and other feedstocks at 15 refineries, mainly in the United States, Europe and Asia.

4)
Marketing and Specialties—Purchases for resale and markets refined products, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products (such as base oils and lubricants), 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.

We evaluate performance and allocate resources based on net income attributable to Phillips 66. Intersegment sales are at prices that approximate market.

Effective January 1, 2014, we changed the organizational structure of the internal financial information reviewed by our chief executive officer, and determined this resulted in a change in the composition of our operating segments. The primary effects of this reporting reorganization were as follows:

We moved two of our equity investments, Excel and Jupiter Sulphur, LLC, as well as the commission revenues related to needle and anode coke, polypropylene and solvents, from the Refining segment to the M&S segment.

We moved several refining logistics projects from the Refining segment to the Midstream segment.

The new segment alignment is presented for the three- and nine-month periods ended September 30, 2014, with the prior periods recast for comparability.

24

Table of Contents

Analysis of Results by Operating Segment

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

Sales and Other Operating Revenues
 
 
 
 
 
Midstream
 
 
 
 
 
Total sales
$
1,323

1,480

 
4,633

4,589

Intersegment eliminations
(255
)
(224
)
 
(821
)
(666
)
Total Midstream
1,068

1,256

 
3,812

3,923

Chemicals
2

3

 
6

7

Refining
 
 
 
 
 
Total sales
28,910

32,343

 
91,753

93,099

Intersegment eliminations
(17,768
)
(18,868
)
 
(54,119
)
(55,235
)
Total Refining
11,142

13,475

 
37,634

37,864

Marketing and Specialties
 
 
 
 
 
Total sales
28,663

29,798

 
86,198

87,707

Intersegment eliminations
(466
)
(393
)
 
(1,424
)
(976
)
Total Marketing and Specialties
28,197

29,405

 
84,774

86,731

Corporate and Other
8

7

 
23

22

Consolidated sales and other operating revenues
$
40,417

44,146

 
126,249

128,547

 
 
 
 
 
 
Net Income (Loss) Attributable to Phillips 66
 
 
 
 
 
Midstream
$
115

147

 
411

348

Chemicals
230

262

 
870

725

Refining
558

(30
)
 
1,254

1,329

Marketing and Specialties
368

255

 
667

789

Corporate and Other
(91
)
(113
)
 
(293
)
(334
)
Discontinued operations

14

 
706

43

Consolidated net income attributable to Phillips 66
$
1,180

535

 
3,615

2,900



 
Millions of Dollars
 
September 30
2014

 
December 31
2013

Total Assets
 
 
 
Midstream
$
6,901

 
5,485

Chemicals
4,926

 
4,377

Refining
26,225

 
26,046

Marketing and Specialties
7,756

 
7,331

Corporate and Other
3,842

 
6,348

Discontinued operations

 
211

Consolidated total assets
$
49,650

 
49,798




25

Table of Contents

Note 22—Income Taxes

Our effective tax rate for the third quarter and the first nine months of 2014 was 31 percent and 33 percent, respectively, compared with 35 percent and 34 percent for the corresponding periods of 2013. The decrease in the effective tax rate for the third quarter of 2014, compared with the third quarter of 2013, was primarily attributable to the utilization of foreign tax credit carryforwards for which no benefit has been recognized and the recognition of a nontaxable gain associated with the sale of ICHP. For additional information on the nontaxable gain, see Note 6—Assets Held for Sale or Sold. The effective tax rate varies from the federal statutory tax rate of 35 percent primarily as a result of state tax expense, offset by the manufacturing deduction and foreign operations.


Note 23—Phillips 66 Partners LP

In 2013, we formed Phillips 66 Partners, a master limited partnership, to own, operate, develop and acquire primarily fee-based crude oil, refined petroleum product and NGL pipelines and terminals, as well as other transportation and midstream assets.
On March 1, 2014, we contributed to Phillips 66 Partners certain transportation, terminaling and storage assets for total consideration of $700 million, which consisted of $400 million in cash, the receipt of 3,530,595 common units and 72,053 general partner units of Phillips 66 Partners and a 5-year, $160 million note receivable. These assets consisted of our Gold Line products system and the Medford spheres, which are two newly constructed refinery-grade propylene storage spheres. Since we consolidate Phillips 66 Partners for financial reporting purposes, this transaction was eliminated upon consolidation and did not impact our financial position or cash flow.

At September 30, 2014, we owned a 73 percent limited partner interest and a 2 percent general partner interest in Phillips 66 Partners, while the public owned a 25 percent limited partner interest. We consolidate Phillips 66 Partners because we control the partnership through our general partner interest (see Note 3—Variable Interest Entities (VIEs), for additional information). The public’s ownership interest in Phillips 66 Partners was $413 million at September 30, 2014, and is reflected as a noncontrolling interest in our financial statements. The most significant assets of Phillips 66 Partners that are available to settle only its obligations were net PP&E of $274 million at September 30, 2014.


Note 24—New Accounting Standards

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The new standard converged guidance on recognizing revenues in contracts with customers under accounting principles generally accepted in the United States and International Financial Reporting Standards. This ASU is intended to improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. ASU 2014-09 is effective for annual and quarterly reporting periods of public entities beginning after December 15, 2016. Early application for public entities is not permitted. We are currently evaluating the provisions of ASU 2014-09 and assessing the impact, if any, it may have on our financial position and results of operations.



26

Table of Contents

Note 25—Condensed Consolidating Financial Information

Our $5.8 billion of Senior Notes were issued by Phillips 66, and are guaranteed by Phillips 66 Company, a 100-percent-owned subsidiary. Phillips 66 Company has fully and unconditionally guaranteed the payment obligations of Phillips 66 with respect to these debt securities. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for:

Phillips 66 and Phillips 66 Company (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting).
All other nonguarantor subsidiaries.
The consolidating adjustments necessary to present Phillips 66’s results on a consolidated basis.

This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes.

Effective with fiscal year 2013, we revised the cash flow presentation of inter-column transactions associated with our centralized cash management program and intercompany loans, from operating cash flows to investing cash flows, in a new line item labeled “Intercompany lending activities.” Additionally, interest and debt expense in the statement of income was revised to eliminate intra-column lending transactions. All periods have been revised to conform to this presentation.

27

Table of Contents

 
Millions of Dollars
 
Three Months Ended September 30, 2014
Statement of Income
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues
$

27,700

12,717


40,417

Equity in earnings of affiliates
1,225

812

87

(1,613
)
511

Net gain on dispositions


109


109

Other income

3

8


11

Intercompany revenues

749

4,757

(5,506
)

Total Revenues and Other Income
1,225

29,264

17,678

(7,119
)
41,048

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products

24,785

14,272

(5,455
)
33,602

Operating expenses

893

221

(10
)
1,104

Selling, general and administrative expenses

301

122

(22
)
401

Depreciation and amortization

189

60


249

Impairments


12


12

Taxes other than income taxes

1,405

2,470

(1
)
3,874

Accretion on discounted liabilities

5

1


6

Interest and debt expense
69

(3
)
12

(18
)
60

Foreign currency transaction losses


13


13

Total Costs and Expenses
69

27,575

17,183

(5,506
)
39,321

Income from continuing operations before income taxes
1,156

1,689

495

(1,613
)
1,727

Provision (benefit) for income taxes
(24
)
464

98


538

Income From Continuing Operations
1,180

1,225

397

(1,613
)
1,189

Income from discontinued operations





Net income
1,180

1,225

397

(1,613
)
1,189

Less: net income attributable to noncontrolling interests


9


9

Net Income Attributable to Phillips 66
$
1,180

1,225

388

(1,613
)
1,180

 
 
 
 
 
 
Comprehensive Income
$
969

1,014

174

(1,179
)
978

* Net of provision for income taxes on discontinued operations:
$






28

Table of Contents

 
Millions of Dollars
 
Three Months Ended September 30, 2013
Statement of Income
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues
$

29,197

14,949


44,146

Equity in earnings of affiliates
580

697

166

(796
)
647

Net gain on dispositions

8



8

Other income (loss)
(1
)
(13
)
7


(7
)
Intercompany revenues

346

5,314

(5,660
)

Total Revenues and Other Income
579

30,235

20,436

(6,456
)
44,794

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products

26,865

17,476

(5,624
)
38,717

Operating expenses

814

184

(6
)
992

Selling, general and administrative expenses
2

243

127

(23
)
349

Depreciation and amortization

182

51


233

Impairments

1



1

Taxes other than income taxes

1,324

2,301

(1
)
3,624

Accretion on discounted liabilities

4

2


6

Interest and debt expense
66

4

4

(6
)
68

Foreign currency transaction losses (gains)

1

(1
)


Total Costs and Expenses
68

29,438

20,144

(5,660
)
43,990

Income from continuing operations before income taxes
511

797

292

(796
)
804

Provision (benefit) for income taxes
(24
)
217

85


278

Income From Continuing Operations
535

580

207

(796
)
526

Income from discontinued operations*


14


14

Net income
535

580

221

(796
)
540

Less: net income attributable to noncontrolling interests


5


5

Net Income Attributable to Phillips 66
$
535

580

216

(796
)
535

 
 
 
 
 
 
Comprehensive Income
$
734

778

406

(1,179
)
739

* Net of provision for income taxes on discontinued operations:
$


8


8


29

Table of Contents

 
Millions of Dollars
 
Nine Months Ended September 30, 2014
Statement of Income
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues
$

85,084

41,165


126,249

Equity in earnings of affiliates
3,055

2,262

395

(3,659
)
2,053

Net gain on dispositions


125


125

Other income

43

16


59

Intercompany revenues

2,084

15,158

(17,242
)

Total Revenues and Other Income
3,055

89,473

56,859

(20,901
)
128,486

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products

76,839

47,568

(17,108
)
107,299

Operating expenses
2

2,658

638

(27
)
3,271

Selling, general and administrative expenses
5

903

377

(70
)
1,215

Depreciation and amortization

552

170


722

Impairments

2

14


16

Taxes other than income taxes

4,122

7,223

(1
)
11,344

Accretion on discounted liabilities

14

4


18

Interest and debt expense
202

3

25

(36
)
194

Foreign currency transaction losses


23


23

Total Costs and Expenses
209

85,093

56,042

(17,242
)
124,102

Income from continuing operations before income taxes
2,846

4,380

817

(3,659
)
4,384

Provision (benefit) for income taxes
(73
)
1,325

199


1,451

Income from Continuing Operations
2,919

3,055

618

(3,659
)
2,933

Income from discontinued operations*
696


10


706

Net income
3,615

3,055

628

(3,659
)
3,639

Less: net income attributable to noncontrolling interests


24


24

Net Income Attributable to Phillips 66
$
3,615

3,055

604

(3,659
)
3,615

 
 
 
 
 
 
Comprehensive Income
$
3,553

2,993

539

(3,508
)
3,577

* Net of provision for income taxes on discontinued operations:
$


5


5




30

Table of Contents

 
Millions of Dollars
 
Nine Months Ended September 30, 2013
Statement of Income
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues
$

86,169

42,378


128,547

Equity in earnings of affiliates
3,035

2,473

402

(3,606
)
2,304

Net gain on dispositions

49

1


50

Other income (loss)
(3
)
36

32


65

Intercompany revenues

1,248

15,677

(16,925
)

Total Revenues and Other Income
3,032

89,975

58,490

(20,531
)
130,966

 
 
 
 
 
 
Costs and Expenses
 
 
 
 
 
Purchased crude oil and products

78,037

50,003

(16,823
)
111,217

Operating expenses

2,434

588

(20
)
3,002

Selling, general and administrative expenses
5

713

395

(69
)
1,044

Depreciation and amortization

542

162


704

Impairments

(2
)
28


26

Taxes other than income taxes

3,828

6,622

(1
)
10,449

Accretion on discounted liabilities

14

4


18

Interest and debt expense
200

10

9

(12
)
207

Foreign currency transaction losses (gains)

1

(17
)

(16
)
Total Costs and Expenses
205

85,577

57,794

(16,925
)
126,651

Income from continuing operations before income taxes
2,827

4,398

696

(3,606
)
4,315

Provision (benefit) for income taxes
(73
)
1,363

158


1,448

Income from Continuing Operations
2,900

3,035

538

(3,606
)
2,867

Income from discontinued operations*


43


43

Net income
2,900

3,035

581

(3,606
)
2,910

Less: net income attributable to noncontrolling interests


10


10

Net Income Attributable to Phillips 66
$
2,900

3,035

571

(3,606
)
2,900

 
 
 
 
 
 
Comprehensive Income
$
2,847

2,982

493

(3,465
)
2,857

* Net of provision for income taxes on discontinued operations:
$


23


23




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Table of Contents

 
Millions of Dollars
 
At September 30, 2014
Balance Sheet
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Assets
 
 
 
 
 
Cash and cash equivalents
$

670

2,438


3,108

Accounts and notes receivable
11

5,283

4,673

(1,201
)
8,766

Inventories

3,359

2,314


5,673

Prepaid expenses and other current assets
6

289

352


647

Total Current Assets
17

9,601

9,777

(1,201
)
18,194

Investments and long-term receivables
35,546

26,535

8,109

(59,953
)
10,237

Net properties, plants and equipment

12,243

4,708


16,951

Goodwill

3,093

182


3,275

Intangibles

695

124


819

Other assets
34

117

27

(4
)
174

Total Assets
$
35,597

52,284

22,927

(61,158
)
49,650

 
 
 
 
 
 
Liabilities and Equity
 
 
 
 
 
Accounts payable
$

7,428

5,243

(1,201
)
11,470

Short-term debt

16

19


35

Accrued income and other taxes

321

624


945

Employee benefit obligations

318

45


363

Other accruals
99

299

558


956

Total Current Liabilities
99

8,382

6,489

(1,201
)
13,769

Long-term debt
5,795

164

219


6,178

Asset retirement obligations and accrued environmental costs

537

189


726

Deferred income taxes

4,481

1,155

(4
)
5,632

Employee benefit obligations

663

179


842

Other liabilities and deferred credits
7,928

2,565

4,164

(14,348
)
309

Total Liabilities
13,822

16,792

12,395

(15,553
)
27,456

Common stock
13,332

25,401

8,256

(33,657
)
13,332

Retained earnings
8,468

10,116

1,597

(11,742
)
8,439

Accumulated other comprehensive income (loss)
(25
)
(25
)
231

(206
)
(25
)
Noncontrolling interests


448


448

Total Liabilities and Equity
$
35,597

52,284

22,927

(61,158
)
49,650




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Table of Contents

 
Millions of Dollars
 
At December 31, 2013
Balance Sheet
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Assets
 
 
 
 
 
Cash and cash equivalents
$

2,162

3,238


5,400

Accounts and notes receivable
9

2,174

8,130

(681
)
9,632

Inventories

1,962

1,392


3,354

Prepaid expenses and other current assets
10

368

473


851

Total Current Assets
19

6,666

13,233

(681
)
19,237

Investments and long-term receivables
33,178

27,417

7,135

(56,510
)
11,220

Net properties, plants and equipment

12,031

3,367


15,398

Goodwill

3,094

2


3,096

Intangibles

694

4


698

Other assets
40

112

1

(4
)
149

Total Assets
$
33,237

50,014

23,742

(57,195
)
49,798

 
 
 
 
 
 
Liabilities and Equity
 
 
 
 
 
Accounts payable
$
1

7,507

4,263

(681
)
11,090

Short-term debt

18

6


24

Accrued income and other taxes

250

622


872

Employee benefit obligations

422

54


476

Other accruals
49

178

242


469

Total Current Liabilities
50

8,375

5,187

(681
)
12,931

Long-term debt
5,796

152

183


6,131

Asset retirement obligations and accrued environmental costs

527

173


700

Deferred income taxes

5,045

1,084

(4
)
6,125

Employee benefit obligations

724

197


921

Other liabilities and deferred credits
5,441

2,155

6,691

(13,689
)
598

Total Liabilities
11,287

16,978

13,515

(14,374
)
27,406

Common stock
16,291

25,938

8,302

(34,240
)
16,291

Retained earnings
5,622

7,061

1,163

(8,224
)
5,622

Accumulated other comprehensive income
37

37

320

(357
)
37

Noncontrolling interests


442


442

Total Liabilities and Equity
$
33,237

50,014

23,742

(57,195
)
49,798




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Table of Contents

 
Millions of Dollars
 
Nine Months Ended September 30, 2014
Statement of Cash Flows
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Cash Flows From Operating Activities
 
 
 
 
 
Net cash provided by continuing operating activities
$
60

991

1,750

(146
)
2,655

Net cash provided by discontinued operations


2


2

Net Cash Provided by Operating Activities
60

991

1,752

(146
)
2,657

 
 
 
 
 
 
Cash Flows From Investing Activities
 
 
 
 
 
Capital expenditures and investments*

(1,756
)
(1,876
)
985

(2,647
)
Proceeds from asset dispositions

999

64

(400
)
663

Intercompany lending activities
2,937

(1,743
)
(1,194
)


Advances/loans—related parties


(3
)

(3
)
Other

(1
)
162


161

Net cash provided by (used in) continuing investing activities
2,937

(2,501
)
(2,847
)
585

(1,826
)
Net cash used in discontinued operations


(2
)

(2
)
Net Cash Provided by (Used in) Investing Activities
2,937

(2,501
)
(2,849
)
585

(1,828
)
 
 
 
 
 
 
Cash Flows From Financing Activities
 
 
 
 
 
Repayment of debt

(15
)
(15
)

(30
)
Issuance of common stock
1




1

Repurchase of common stock
(1,750
)



(1,750
)
Share exchange—PSPI transaction
(450
)



(450
)
Dividends paid on common stock
(787
)

(102
)
102

(787
)
Distributions to controlling interests


(305
)
305


Distributions to noncontrolling interests


(18
)

(18
)
Other*
(11
)
33

847

(846
)
23

Net cash provided by (used in) continuing financing activities
(2,997
)
18

407

(439
)
(3,011
)
Net cash provided by (used in) discontinued operations





Net Cash Provided by (Used in) Financing Activities
(2,997
)
18

407

(439
)
(3,011
)
 
 
 
 
 
 
Effect of Exchange Rate Changes on Cash and Cash Equivalents


(110
)

(110
)
 
 
 
 
 
 
Net Change in Cash and Cash Equivalents

(1,492
)
(800
)

(2,292
)
Cash and cash equivalents at beginning of period

2,162

3,238


5,400

Cash and Cash Equivalents at End of Period
$

670

2,438


3,108

* Includes intercompany capital contributions.


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Table of Contents

 
Millions of Dollars
 
Nine Months Ended September 30, 2013
Statement of Cash Flows
Phillips 66

Phillips 66 Company

All Other Subsidiaries

Consolidating Adjustments

Total Consolidated

Cash Flows From Operating Activities
 
 
 
 
 
Net cash provided by continuing operating activities
$
60

2,732

2,355

(70
)
5,077

Net cash provided by discontinued operations


53


53

Net Cash Provided by Operating Activities
60

2,732

2,408

(70
)
5,130

 
 
 
 
 
 
Cash Flows From Investing Activities
 
 
 
 
 
Capital expenditures and investments*

(683
)
(494
)
21

(1,156
)
Proceeds from asset dispositions

62

1,126


1,188

Intercompany lending activities
3,130

(2,626
)
(504
)


Advances/loans—related parties


(65
)

(65
)
Collection of advances/loans—related parties


100


100

Net cash provided by (used in) continuing investing activities
3,130

(3,247
)
163

21

67

Net cash used in discontinued operations


(14
)

(14
)
Net Cash Provided by (Used in) Investing Activities
3,130

(3,247
)
149

21

53

 
 
 
 
 
 
Cash Flows From Financing Activities
 
 
 
 
 
Repayment of debt
(1,000
)
(14
)
(1
)

(1,015
)
Issuance of common stock
(4
)



(4
)
Repurchase of common stock
(1,602
)



(1,602
)
Dividends paid on common stock
(575
)

(70
)
70

(575
)
Distributions to noncontrolling interests


(1
)

(1
)
Net proceeds from issuance of Phillips 66 Partners LP common units


404


404

Other*
(9
)
5

21

(21
)
(4
)
Net cash provided by (used in) continuing financing activities
(3,190
)
(9
)
353

49

(2,797
)
Net cash provided by (used in) discontinued operations





Net Cash Provided by (Used in) Financing Activities
(3,190
)
(9
)
353

49

(2,797
)
 
 
 
 
 
 
Effect of Exchange Rate Changes on Cash and Cash Equivalents


82


82

 
 
 
 
 
 
Net Change in Cash and Cash Equivalents

(524
)
2,992


2,468

Cash and cash equivalents at beginning of period

2,410

1,064


3,474

Cash and Cash Equivalents at End of Period
$

1,886

4,056


5,942

* Includes intercompany capital contributions.




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Table of Contents

Item 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis is the company’s analysis of its financial performance, financial condition, and significant trends that may affect future performance. It should be read in conjunction with the consolidated financial statements and notes included elsewhere in this report. It contains forward-looking statements including, without limitation, statements relating to the company’s plans, strategies, objectives, expectations and intentions that are made pursuant to the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. The words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target” and similar expressions identify forward-looking statements. The company does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. Readers are cautioned that such forward-looking statements should be read in conjunction with the company’s disclosures under the heading: “CAUTIONARY STATEMENT FOR THE PURPOSES OF THE ‘SAFE HARBOR’ PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995,” beginning on page 53.

The terms “earnings” and “loss” as used in Management’s Discussion and Analysis refer to net income (loss) attributable to Phillips 66.


BUSINESS ENVIRONMENT AND EXECUTIVE OVERVIEW

Phillips 66 is an energy manufacturing and logistics company with midstream, chemicals, refining, and marketing and specialties businesses. At September 30, 2014, we had total assets of $50 billion. Our common stock trades on the New York Stock Exchange under the symbol “PSX.”

Executive Overview
We reported earnings of $1,180 million in the third quarter of 2014 and generated $429 million in cash from operating activities. We used available cash to fund capital expenditures and investments of $1,514 million, pay dividends of $277 million, and repurchase $494 million of our common stock. We ended the third quarter of 2014 with $3.1 billion of cash and cash equivalents and approximately $4.7 billion of total capacity available under our liquidity facilities.

Basis of Presentation
Effective January 1, 2014, we changed the organizational structure of the internal financial information reviewed by our chief executive officer, and determined this resulted in a change in the composition of our operating segments. The primary effects of this reporting reorganization were as follows:

We moved two of our equity investments, Excel Paralubes and Jupiter Sulphur, LLC, as well as the commission revenues related to needle and anode coke, polypropylene and solvents, from the Refining segment to the Marketing and Specialties (M&S) segment.

We moved several refining logistics projects from the Refining segment to the Midstream segment.

The new segment alignment is presented for the three- and nine-month periods ended September 30, 2014, with the prior periods recast for comparability.


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Table of Contents

Business Environment
The Midstream segment includes our 50 percent equity investment in DCP Midstream, LLC (DCP Midstream). Earnings of DCP Midstream are closely linked to natural gas liquids (NGL) prices, natural gas prices and crude oil prices. Industry NGL prices decreased in the third quarter of 2014, compared with the second quarter of 2014 and the third quarter of 2013. Ethane prices decreased in the third quarter of 2014, compared with the second quarter of 2014 and the third quarter of 2013, primarily due to increased supply in the market. Propane prices continued to decrease from the second quarter of 2014 to the third quarter of 2014, due to a lack of seasonal demand. Natural gas prices decreased in the third quarter of 2014, compared with the second quarter of 2014, but increased from the third quarter of 2013. The decline in natural gas prices in the third quarter of 2014 was a result of a seasonal inventory restocking. The increase from the third quarter of 2013 reflects concerns over low industry inventory levels heading into the winter season.

The Chemicals segment consists of our 50 percent equity investment in Chevron Phillips Chemical Company LLC (CPChem). The chemicals and plastics industry is mainly a commodity-based industry where the margins for key products are based on market factors. The chemicals industry continues to experience higher ethylene margins in regions of the world where production is based upon NGL versus crude-derived feedstocks. In particular, companies with North American ethane-based crackers benefited from lower-priced feedstocks and improved ethylene margins, as well as improved margins for polyethylene, an ethylene derivative.

Results for our Refining segment depend largely on refining margins, cost control, refinery throughput, and product yields. The crack spread is a measure of the difference between market prices for refined petroleum products and crude oil, and it is used within our industry as an indicator for refining margins. The U.S. 3:2:1 crack spread (three barrels of crude oil producing two barrels of gasoline and one barrel of diesel) decreased in the third quarter of 2014, compared with the second quarter of 2014, but increased compared with the third quarter of 2013. The third-quarter 2014 domestic industry crack spread decreased compared with the second quarter of 2014, largely as the result of higher supply due to higher than anticipated refinery output, and a decrease in gasoline prices in part driven by the transition to winter gasoline specifications. The increase in the third-quarter 2014 domestic industry crack spread compared with the third quarter of 2013 was due to the average market crude oil price declining more than the average market gasoline and distillate prices.
The Northwest Europe benchmark crack spread in the third quarter of 2014 increased compared with the second quarter of 2014 and the third quarter of 2013.  The increase from the second quarter of 2014 was a result of crude prices declining faster than gasoline and distillate prices, as well as lower supply due to lower refinery output.
Results for our M&S segment depend largely on marketing fuel margins, base oil margins, lubricant margins and other specialty product margins. These margins are primarily based on market factors, largely determined by the relationship between demand and supply. Marketing fuel margins are influenced by crude oil pricing trends, which drive spot prices for refined products. Generally, in a period of rising crude oil prices, refined product spot prices will increase at a faster pace than the corresponding wholesale “rack” price of products sold to retailers, thereby tightening marketing margins. In a period of falling crude oil prices, the inverse occurs, and marketing margins generally benefit. Crude oil prices declined significantly during the third quarter of 2014, which resulted in the expected benefit to marketing margins.


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Table of Contents

RESULTS OF OPERATIONS

Unless otherwise indicated, discussion of results for the three- and nine-month periods ended September 30, 2014, is based on a comparison with the corresponding periods of 2013.

Consolidated Results
A summary of net income (loss) attributable to Phillips 66 by business segment follows:

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
 
 
 
 
 
Midstream
$
115

147

 
411

348

Chemicals
230

262

 
870

725

Refining
558

(30
)
 
1,254

1,329

Marketing and Specialties
368

255

 
667

789

Corporate and Other
(91
)
(113
)
 
(293
)
(334
)
Discontinued Operations

14

 
706

43

Net income attributable to Phillips 66
$
1,180

535

 
3,615

2,900



Earnings for Phillips 66 increased $645 million, or 121 percent, in the third quarter of 2014. The increase was due to higher realized refining margins primarily driven by lower crude prices. In addition, third-quarter 2014 results included the recognition of $109 million of the previously deferred gain related to the sale of Immingham Combined Heat and Power Plant (ICHP). See Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements, for additional information on this transaction.

Earnings for the nine months ended September 30, 2014, increased $715 million, or 25 percent, largely due to the recognition of a noncash $696 million gain related to the Phillips Specialty Products, Inc. (PSPI) share exchange, as well as improved realized margins in our Chemicals segment, resulting from increased ethylene and polyethylene margins.

See the “Segment Results” section, for additional information on our segment results.

Statement of Income Analysis

Sales and other operating revenues for the third quarter and nine-month period of 2014 decreased 8 percent and 2 percent, respectively, and purchased crude oil and products decreased 13 percent and 4 percent, respectively. The decreases for the third quarter of 2014 were primarily due to lower prices for petroleum products, crude oil and NGL.

Equity in earnings of affiliates decreased 21 percent in the third quarter of 2014, primarily resulting from decreased earnings from DCP Midstream and CPChem. Equity in earnings for the nine-month period of 2014 decreased 11 percent, primarily due to decreased earnings from WRB Refining LP (WRB), partially offset by increased earnings from CPChem. Equity in earnings of WRB decreased 54 percent during the nine-month period of 2014, mainly due to lower refining margins. See the “Segment Results” section, for additional information on CPChem and DCP Midstream earnings.

Gain on dispositions for the third quarter of 2014 was $109 million, compared with $8 million for the third quarter of 2013. During the nine-month period of 2014, there was a $125 million gain on dispositions, compared with $50 million for the nine-month period of 2013. The increase for the third quarter and nine-month period of 2014 is due to the recognition of $109 million of the previously deferred gain related to the sale of ICHP. See Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements, for additional information on this transaction.

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Table of Contents

Operating expenses for the third quarter and nine-month period of 2014 increased $112 million, or 11 percent, and $269 million, or 9 percent, respectively, primarily related to higher turnaround costs at our refineries, as well as increased utility costs, largely due to higher natural gas prices.

Selling, general and administrative expenses increased $52 million, or 15 percent, and $171 million, or 16 percent, in the third quarter and nine-month period of 2014, respectively. These increases were primarily due to additional fees under marketing consignment fuels agreements. In addition, the nine-month period of 2014 was impacted by the costs associated with the acquisition of an additional interest in an entity that operates a power and steam generation plant.

See Note 22—Income Taxes, in the Notes to Consolidated Financial Statements, for information regarding our provision for income taxes and effective tax rates.

Income from discontinued operations increased $663 million in the nine-month period of 2014, due to the completion of the PSPI share exchange on February 25, 2014. See Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements, for additional information on this transaction.



39

Table of Contents

Segment Results

Midstream

 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
Millions of Dollars
Net Income Attributable to Phillips 66
 
 
 
 
 
Transportation
$
58

54

 
180

149

DCP Midstream
31

87

 
147

173

NGL
26

6

 
84

26

Total Midstream
$
115

147

 
411

348


 
Dollars Per Unit
Weighted Average NGL Price*
 
 
 
 
 
DCP Midstream (per barrel)
$
37.66

37.84

 
40.42

36.63

DCP Midstream (per gallon)
0.90

0.90

 
0.96

0.87

* Based on index prices from the Mont Belvieu and Conway market hubs that are weighted by NGL component and location mix. 2013 weighted average NGL prices have been recast to reflect the impact of ethane rejection.

 
Thousands of Barrels Daily
Transportation Volumes
 
 
 
 
 
Pipelines*
3,142

3,222

 
3,162

3,142

Terminals
1,763

1,419

 
1,617

1,219

Refining Logistics
17


 
6


 
 
 
 
 
 
Operating Statistics
 
 
 
 
 
NGL extracted**
471

442

 
456

417

NGL fractionated***
110

123

 
113

118

* Pipelines represent the sum of volumes transported through each separately tariffed pipeline segment, including our share of equity volumes from Yellowstone Pipe Line Company and Lake Charles Pipe Line Company.
** Includes 100 percent of DCP Midstream’s volumes.
*** Excludes DCP Midstream.


The Midstream segment purchases raw natural gas from producers and gathers natural gas through an extensive network of pipeline gathering systems. The natural gas is then processed to extract NGL from the raw gas stream. The remaining “residue” gas is marketed to electric utilities, industrial users and gas marketing companies. Most of the NGLs are fractionated—separated into individual components such as ethane, propane and butane—and marketed as chemical feedstock, fuel or blendstock. In addition, the Midstream segment includes U.S. transportation, pipeline, terminaling, and refining logistics services associated with the movement of crude oil, refined and specialty products, natural gas and NGL, as well as NGL fractionation, trading and marketing businesses in the United States. The Midstream segment includes our 50 percent equity investment in DCP Midstream and the consolidated results of Phillips 66 Partners LP.

Earnings from the Midstream segment decreased $32 million, or 22 percent, in the third quarter of 2014 and increased $63 million, or 18 percent, in the nine-month period of 2014.

Transportation earnings increased $4 million in the third quarter of 2014 and increased $31 million in the nine-month period of 2014. The increases in both periods of 2014 primarily resulted from increased throughput fees, as well as

40

Table of Contents

higher earnings associated with railcar activity. These increases were partially offset by higher earnings attributable to noncontrolling interests, reflecting the contribution of previously wholly owned assets to Phillips 66 Partners.

Earnings associated with our investment in DCP Midstream decreased $56 million in the third quarter of 2014 and $26 million in the nine-month period. A portion of the decreased earnings in both periods reflects DCP Midstream’s contribution of assets to its publicly traded master limited partnership, DCP Midstream Partners, LP (DCP Partners). After contribution to DCP Partners, a percentage of these assets’ earnings are attributable to public unitholders, thus decreasing income attributable to DCP Midstream, and, thereby, Phillips 66. Earnings in both periods benefited from higher volumes resulting from growth projects. Lower commodity prices had a negative impact on third-quarter 2014 results, while higher commodity prices benefited the year-to-date 2014 period. Higher interest expense, primarily associated with debt incurred by DCP Partners to finance its growth activities, as well as lower capitalized interest associated with certain projects placed into service in 2013, also reduced earnings in the nine-month period ended September 30, 2014. See the “Business Environment and Executive Overview” section for information on market factors impacting this quarter’s results.

DCP Partners issues, from time to time, limited partner units to the public. These issuances benefited our equity in earnings from DCP Midstream, on an after-tax basis, by $6 million and $41 million in the three- and nine-month periods ended September 30, 2014, respectively, compared with $24 million and $56 million in the corresponding periods of 2013.

Earnings of our NGL business increased $20 million in the third quarter of 2014 and $58 million for the nine-month period of 2014. The third quarter of 2014 benefited from gains related to seasonal storage activities. The increase for the nine-month period of 2014 was primarily due to improved margins driven by strong propane prices, positive asset performance and inventory impacts. In addition, both periods benefited from equity earnings from the DCP Sand Hills and DCP Southern Hills pipeline entities.



41

Table of Contents

Chemicals

 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
 
 
 
 
 
 
Millions of Dollars
 
 
 
 
 
 
Net Income Attributable to Phillips 66
$
230

262

 
870

725

 
 
Millions of Pounds
CPChem Externally Marketed Sales Volumes*
 
 
 
 
 
Olefins and Polyolefins
4,067

3,927

 
12,764

11,825

Specialties, Aromatics and Styrenics
1,571

1,577

 
4,670

4,558

 
5,638

5,504

 
17,434

16,383

* Includes 100 percent of CPChem’s outside sales of produced petrochemical products, as well as commission sales from equity affiliates.

Olefins and Polyolefins Capacity Utilization (percent)
83
%
87
%
 
90
%
85
%


The Chemicals segment consists of our 50 percent interest in CPChem, which we account for under the equity method. CPChem uses NGL and other feedstocks to produce petrochemicals. These products are then marketed and sold or used as feedstocks to produce plastics and other chemicals.

Earnings from the Chemicals segment decreased $32 million, or 12 percent, in the third quarter of 2014 and increased $145 million, or 20 percent, in the nine-month period of 2014. The decrease in the third quarter of 2014 was primarily driven by $45 million of impairments related to two of CPChem’s equity affiliate investments, as well as an impairment of $24 million related to the sale of Engineering Polymers. In addition, lower ethylene volumes and increased controllable costs related to the Port Arthur facility fire described below further reduced earnings in the third quarter of 2014. These decreases were partially offset by an improvement in ethylene margins, as well as increased earnings from CPChem’s equity affiliates.

The increase in earnings in the nine-month period of 2014 was primarily due to improved ethylene and polyethylene realized margins and higher earnings from CPChem’s equity affiliates. These increases were partially offset by an increase in utility costs due to higher natural gas prices, as well as the asset impairments discussed above. See the “Business Environment and Executive Overview” section for information on market factors impacting this quarter’s results.

CPChem’s Port Arthur facility experienced a localized fire in a portion of its ethylene unit in early July 2014, shutting down the ethylene and cyclohexane production. Cyclohexane production resumed in mid-July at reduced rates, but ethylene production is not expected to restart until late fourth quarter of 2014. We expect CPChem’s results in the fourth quarter of 2014 to continue to be negatively impacted by this shutdown.


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Table of Contents

Refining

 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
 
 
 
 
 
 
Millions of Dollars
Net Income (Loss) Attributable to Phillips 66
 
 
 
 
 
Atlantic Basin/Europe
$
125

47

 
131

166

Gulf Coast
43

(79
)
 
238

(126
)
Central Corridor
300

119

 
751

1,102

Western/Pacific
(3
)
(94
)
 
15

2

Other Refining
93

(23
)
 
119

185

Worldwide
$
558

(30
)
 
1,254

1,329

 
 
 
 
 
 
 
Dollars Per Barrel
Refining Margins*
 
 
 
 
 
Atlantic Basin/Europe
$
9.99

6.59

 
7.82

7.34

Gulf Coast
6.80

3.35

 
7.81

4.93

Central Corridor
16.87

9.80

 
15.66

18.65

Western/Pacific
8.71

4.77

 
8.79

7.75

Worldwide
10.89

5.94

 
10.15

9.70

* Based on total processed inputs and includes proportional share of refining margins contributed by certain equity affiliates.
 
 
 
 
 
 
 
Thousands of Barrels Daily
Operating Statistics
 
 
 
 
 
Refining operations*
 
 
 
 
 
Atlantic Basin/Europe
 
 
 
 
 
Crude oil capacity
588

588

 
588

588

Crude oil processed
538

574

 
550

567

Capacity utilization (percent)
92
%
98

 
94

96

Refinery production
593

609

 
599

609

Gulf Coast
 
 
 


Crude oil capacity
733

733

 
733

733

Crude oil processed
710

671

 
666

640

Capacity utilization (percent)
97
%
92

 
91

87

Refinery production
798

774

 
766

723

Central Corridor
 
 
 


Crude oil capacity
485

478

 
485

476

Crude oil processed
476

480

 
478

470

Capacity utilization (percent)
98
%
101

 
99

99

Refinery production
494

497

 
497

487

Western/Pacific
 
 
 


Crude oil capacity
440

440

 
440

440

Crude oil processed
390

403

 
403

407

Capacity utilization (percent)
89
%
91

 
92

92

Refinery production
425

432

 
436

442

Worldwide
 
 
 


Crude oil capacity
2,246

2,239

 
2,246

2,237

Crude oil processed
2,114

2,128

 
2,097

2,084

Capacity utilization (percent)
94
%
95

 
93

93

Refinery production
2,310

2,312

 
2,298

2,261

* Includes our share of equity affiliates.
 
 
 
 
 


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The Refining segment buys, sells and refines crude oil and other feedstocks into petroleum products (such as gasoline, distillates and aviation fuels) at 15 refineries, mainly in the United States, Europe and Asia.

Earnings for the Refining segment increased $588 million in the third quarter of 2014. The increase was primarily due to higher realized refining margins resulting from increased market crack spreads, as well as the improvement of refined petroleum product differentials. See the “Business Environment and Executive Overview” section for information on market factors impacting this quarter’s results.

Earnings for the nine-month period of 2014 decreased $75 million, or 6 percent, primarily related to higher utility costs due to increased natural gas prices and higher turnaround costs. In addition, earnings were impacted by improved refined petroleum product differentials, partially offset by decreased market crack spreads. See the “Business Environment and Executive Overview” section for information on industry crack spreads and other market factors impacting this quarter’s results.

Our worldwide refining crude oil capacity utilization rate was 94 percent in the third quarter of 2014, compared with 95 percent in the third quarter of 2013. The current year decrease was primarily due to turnaround activity.

Industry refining margins can vary by region of the world, due to differing crude slates and refined product demand fundamentals. In addition to monitoring for interim indicators of impairment, we perform an annual review for impairment indicators of property and equity investments in the fourth quarter, in conjunction with our long-range planning efforts. This review takes into account our outlook on economic factors that influence refinery cash flows, including commodity prices, industry refining margins, capital spending and other operating plan assumptions. As we finalize our plans and conduct our review, it is reasonably possible non-cash impairments of some of our properties and equity investments may be required.




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Marketing and Specialties

 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

 
 
 
 
 
 
 
Millions of Dollars
Net Income Attributable to Phillips 66
 
 
 
 
 
Marketing and Other
$
325

199

 
537

634

Specialties
43

56

 
130

155

Total Marketing and Specialties
$
368

255

 
667

789


 
Dollars Per Barrel
Realized Marketing Fuel Margin*
 
 
 
 
 
U.S.
$
1.78

1.25

 
1.38

1.36

International
6.10

5.55

 
4.79

4.56

* On third-party petroleum products sales.

 
Dollars Per Gallon
U.S. Average Wholesale Prices*
 
 
 
 
 
Gasoline
$
2.90

2.98

 
2.92

2.97

Distillates
3.02

3.16

 
3.08

3.12

* Excludes excise taxes.
 
 
 
 
 

 
Thousands of Barrels Daily
Marketing Petroleum Products Sales Volumes
 
 
 
 
 
Gasoline
1,188

1,206

 
1,181

1,181

Distillates
940

951

 
952

971

Other products
17

18

 
17

17

Total
2,145

2,175

 
2,150

2,169



The M&S segment purchases for resale and markets refined petroleum products (such as gasoline, distillates and aviation fuels), mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products (such as base oils and lubricants), as well as power generation operations.

The M&S segment earnings increased $113 million, or 44 percent, in the third quarter of 2014, primarily due to the first tranche of the deferred gain related to the ICHP sale that was recognized in the third quarter of 2014.

Earnings for the nine-month period of 2014 decreased $122 million, or 15 percent. The decrease was primarily due to lower credits associated with renewable fuels blending activities. In addition, earnings in the nine-month period of 2013 benefited from earnings from our U.K. power generation business, which was sold in July 2013, the sale of our E-GasTM Technology business in May 2013, and the biodiesel tax credit program that was discontinued in 2014. These decreases were partially offset by the deferred gain related to the sale of ICHP that was recognized in the third quarter of 2014.

See the “Business Environment and Executive Overview” section for information on marketing fuel margins and other market factors impacting this quarter’s results.



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Corporate and Other

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

Net Income (Loss) Attributable to Phillips 66
 
 
 
 
 
Net interest
$
(36
)
(41
)
 
(116
)
(126
)
Corporate general and administrative expenses
(32
)
(32
)
 
(116
)
(102
)
Technology
(14
)
(12
)
 
(41
)
(36
)
Other
(9
)
(28
)
 
(20
)
(70
)
Total Corporate and Other
$
(91
)
(113
)
 
(293
)
(334
)


Net interest consists of interest and financing expense, net of interest income and capitalized interest. Net interest decreased $5 million and $10 million, respectively, in the three- and nine-month periods ended September 30, 2014, primarily due to increased capitalized interest and a lower average debt principal balance. Corporate general and administrative expenses increased $14 million in the nine-month period ended September 30, 2014, primarily due to increased employee benefit costs and charitable contributions.

The category “Other” includes certain income tax expenses, environmental costs associated with sites no longer in operation, foreign currency transaction gains and losses and other costs not directly associated with an operating segment. The decrease in costs for the three- and nine-month periods of 2014 was primarily due to increased utilization of foreign tax credit carry forwards. In addition, the nine-month period of 2013 was negatively impacted by an asset impairment and higher environmental costs.



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Discontinued Operations

 
Millions of Dollars
 
Three Months Ended
September 30
 
Nine Months Ended
September 30
 
2014

2013

 
2014

2013

Net Income Attributable to Phillips 66
 
 
 
 
 
Discontinued operations
$

14

 
706

43



In December 2013, we entered into an agreement to exchange the stock of PSPI, a flow improver business, which was included in our M&S segment, for shares of Phillips 66 common stock owned by the other party to the transaction. On February 25, 2014, we completed the PSPI share exchange, resulting in the receipt of approximately 17.4 million shares of Phillips 66 common stock, which are held as treasury shares, and the recognition of a before-tax noncash gain of $696 million. See Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements, for additional information on this transaction.

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CAPITAL RESOURCES AND LIQUIDITY

Financial Indicators

 
Millions of Dollars
Except as Indicated
 
September 30
2014

December 31
2013

 
 
 
Short-term debt
$
35

24

Total debt
6,213

6,155

Total equity
22,194

22,392

Percent of total debt to capital*
22
%
22

Percent of floating-rate debt to total debt
1
%
1

* Capital includes total debt and total equity.


To meet our short- and long-term liquidity requirements, we look to a variety of funding sources, but rely primarily on cash generated from operating activities. During the first nine months of 2014, we generated $2,657 million in cash from operations and received $663 million from asset dispositions, including return of investments in equity affiliates. Available cash was primarily used for capital expenditures and investments ($2,647 million), repurchases of our common stock ($1,750 million), the PSPI share exchange ($450 million), debt repayments ($30 million) and dividend payments on our common stock ($787 million). During the first nine months of 2014, cash and cash equivalents decreased by $2,292 million to $3,108 million.

In addition to cash flows from operating activities, we rely on our credit facility programs, asset sales and our ability to issue securities using our shelf registration statement to support our short- and long-term liquidity requirements. We believe current cash and cash equivalents and cash generated by operations, together with access to external sources of funds as described below in the “Significant Sources of Capital” section, will be sufficient to meet our funding requirements in the near and long term, including our capital spending, dividend payments, defined benefit plan contributions, repayment of debt and share repurchases.

Significant Sources of Capital

Operating Activities
During the first nine months of 2014, cash provided by operating activities was $2,657 million, compared with $5,130 million for the first nine months of 2013. The decrease in the 2014 period primarily reflected negative working capital impacts, driven mainly by higher inventory builds relative to the prior year, compared to positive working capital impacts during the comparable period of 2013.

Our short- and long-term operating cash flows are highly dependent upon refining and marketing margins, NGL prices, and chemicals margins. Prices and margins in our industry are typically volatile, and are driven by market conditions over which we have little or no control. Absent other mitigating factors, as these prices and margins fluctuate, we would expect a corresponding change in our operating cash flows.

The level and quality of output from our refineries impacts our cash flows. The output at our refineries is impacted by such factors as operating efficiency, maintenance turnarounds, market conditions, feedstock availability and weather conditions. We actively manage the operations of our refineries and, typically, any variability in their operations has not been as significant to cash flows as that caused by margins and prices.

During the third quarter of 2014, we increased inventory levels, which reduced cash from operating activities by $772 million. We are currently forecasting inventory reductions in the fourth quarter of 2014 that are estimated to increase cash from operating activities by a similar amount.


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Our operating cash flows are also impacted by dividend decisions made by our equity affiliates, including DCP Midstream, CPChem and WRB. During the first nine months of 2014, cash from operations included dividends of $2,413 million from our equity affiliates, compared with $2,228 million during the same period of 2013. We cannot control the amount of future dividends from equity affiliates; therefore, future dividend payments by these companies are not assured.

WRB
WRB is a 50-percent-owned business venture with Cenovus Energy Inc. (Cenovus). Cenovus was obligated to contribute $7.5 billion, plus accrued interest, to WRB over a 10-year period that began in 2007. In the first quarter of 2014, Cenovus prepaid its remaining balance under this obligation. As a result, WRB declared a special dividend, which was distributed to the co-venturers in March 2014. Of the $1,232 million that we received, $760 million was considered a return on our investment in WRB (an operating cash inflow), and $472 million was considered a return of our investment in WRB (an investing cash inflow). The return of investment portion of the dividend was included in the “Proceeds from assets dispositions” line in our consolidated statement of cash flows. A further $129 million of distributions from WRB during the first nine months of 2014 was considered a return of investment.

Contribution to Phillips 66 Partners LP
Effective March 1, 2014, we contributed to Phillips 66 Partners certain transportation, terminaling and storage assets for total consideration of $700 million. These assets consisted of the Gold Line products system and the Medford spheres, which are two newly constructed refinery-grade propylene storage spheres. Phillips 66 Partners financed the acquisition with cash on hand of $400 million, the issuance to us of 3,530,595 and 72,053 additional common and general partner units, respectively, valued at $140 million, and a five-year, $160 million note payable to a subsidiary of Phillips 66. See Note 23—Phillips 66 Partners LP, in the Notes to Consolidated Financial Statements, for additional information.

Credit Facilities
As of September 30, 2014, no amount had been drawn under our $4.5 billion credit facility; however, $51 million in letters of credit had been issued that were supported by this facility. As of September 30, 2014, no amount had been drawn under Phillips 66 Partners’ $250 million revolving credit facility.

Trade Receivables Securitization Facility
Effective September 30, 2014, we terminated our $696 million trade receivables securitization facility. No amounts were drawn on this facility throughout its duration, and at the time of termination no letters of credit were outstanding thereunder.

Shelf Registration
We have a universal shelf registration statement on file with the U.S. Securities and Exchange Commission (SEC) under which we, as a well-known seasoned issuer, have the ability to issue and sell an indeterminate amount of various types of debt and equity securities.

Off-Balance Sheet Arrangements
In April 2012, in connection with our separation from ConocoPhillips (the Separation), we entered into an agreement to guarantee 100 percent of certain outstanding debt obligations of Merey Sweeny, L.P. (MSLP). At September 30, 2014, the aggregate principal amount of MSLP debt guaranteed by us was $203 million.

For additional information about guarantees, see Note 13—Guarantees, in the Notes to Consolidated Financial Statements.

Capital Requirements
For information about our capital expenditures and investments, see the “Capital Spending” section.

Our debt balance at both September 30, 2014, and December 31, 2013, was $6.2 billion. Our debt-to-capital ratio was 22 percent at both September 30, 2014, and December 31, 2013, within our target range of 20-to-30 percent.

On July 9, 2014, our Board of Directors declared a quarterly cash dividend of $0.50 per common share. The dividend was paid on September 2, 2014, to holders of record at the close of business on August 15, 2014. On October 1, 2014, our Board of Directors declared a quarterly cash dividend of $0.50 per common share. The dividend is payable on

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December 1, 2014, to holders of record at the close of business on November 14, 2014. We are forecasting annual double-digit dividend rate increases in 2015 and 2016.

During 2012 and 2013, our Board of Directors authorized repurchases totaling up to $5 billion of our outstanding common stock. The share repurchases are expected to be funded primarily through available cash. In July 2014, our Board of Directors authorized additional share repurchases totaling up to $2 billion. During the third quarter of 2014, we repurchased 5,970,667 shares at a cost of $494 million. Since the inception of our share repurchases in 2012, through September 30, 2014, we have repurchased a total of 66,004,675 shares at a cost of $4,352 million. Shares of stock repurchased are held as treasury shares.

On October 15, 2014, we signed agreements to form two joint ventures to develop the Dakota Access Pipeline (DAPL) and Energy Transfer Crude Oil Pipeline (ETCOP) projects. We own a 25 percent interest in each joint venture, with our co-venturer holding the remaining 75 percent interest and acting as operator of both the DAPL and ETCOP systems. Our share of construction cost is estimated to be approximately $1.2 billion, which will be reflected as investments in equity-method affiliates. We expect the majority of this capital spending commitment to be incurred in 2015 and 2016, and anticipate it to be funded as part of our overall capital program.

In December 2013, we announced that we had entered into an agreement to exchange the stock of PSPI for shares of our common stock held by the other party to the transaction. On February 25, 2014, we completed the PSPI share exchange, resulting in the receipt of approximately 17.4 million shares of Phillips 66 common stock, which are held as treasury shares, and the recognition of a before-tax, noncash gain of $696 million.

Capital Spending
 
 
Millions of Dollars
 
Nine Months Ended
September 30
 
2014

 
2013

Capital Expenditures and Investments
 
 
 
Midstream
$
1,532

 
377

Chemicals

 

Refining
679

 
511

Marketing and Specialties
358

 
180

Corporate and Other
78

 
88

Total consolidated from continuing operations
$
2,647

 
1,156

 
 
 
 
Discontinued operations
$

 
14

 


 


Selected Equity Affiliates*
 
 
 
DCP Midstream
$
561

 
760

CPChem**
623

 
420

WRB
96

 
78

 
$
1,280

 
1,258

* Our share of capital spending, which is self-funded by the equity affiliate.
** 2013 has been recast to reflect a change in CPChem’s basis of presentation.


In July 2014, our Board of Directors authorized an increase of $1.2 billion to the 2014 planned capital budget previously reported in our 2013 Annual Report on Form 10-K. The increased capital budget is designed to support planned or completed acquisitions, including a U.S. Gulf Coast crude oil and refined products terminal and a specialty lubricants company, as well as the construction of Midstream organic growth projects. The Midstream segment budget was increased by approximately $0.8 billion, while the M&S segment budget was increased by approximately $0.4 billion.


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Midstream
During the first nine months of 2014, DCP Midstream had a self-funded capital program, and thus required no new capital infusions from us or our co-venturer. During this period, on a 100 percent basis, DCP Midstream’s capital expenditures and investments were approximately $1,122 million.

During the first nine months of 2014, other capital spending in our Midstream segment not related to DCP Midstream included construction activities related to our Sweeny Fractionator One and Freeport Liquid Petroleum Gas Export Terminal projects, our acquisition of a 7.1 million-barrel-storage-capacity crude oil and petroleum products terminal located near Beaumont, Texas, the purchase of an additional 5.7 percent interest in the refined products Explorer Pipeline, and spending associated with return, reliability and maintenance projects. In addition to our Sweeny Fractionator One and Freeport Liquid Petroleum Gas Export Terminal projects, our major construction activities in progress include the installation of rail racks to accept advantaged crude deliveries at our Ferndale refinery.

Chemicals
During the first nine months of 2014, CPChem had a self-funded capital program, and thus required no new capital infusions from us or our co-venturer. During this period, on a 100 percent basis, CPChem’s capital expenditures and investments were $1,245 million, primarily for its U.S. Gulf Coast Petrochemicals Project. We are currently forecasting CPChem to remain self-funding through 2014.

Refining
Capital spending for the Refining segment during the first nine months of 2014 was primarily for air emission reduction projects to meet new environmental standards, refinery upgrade projects to increase accessibility of advantaged crudes and improve product yields, improvements to the operating integrity of key processing units and safety-related projects.

Major construction activities in progress include:

Installation of facilities to reduce nitrous oxide emissions from the fluid catalytic cracker at the Alliance Refinery.
Installation of a tail gas treating unit at the Humber Refinery to reduce emissions from the sulfur recovery units.

Generally, our equity affiliates in the Refining segment are intended to have self-funding capital programs.

Marketing and Specialties
Capital spending for the M&S segment during the first nine months of 2014 included our acquisition of a private label specialty lubricants business headquartered in Memphis, Tennessee, as well as the remaining interest that we did not already own in an entity that operates a power and steam generation plant. The remaining spend was primarily for projects targeted at growing our international marketing business.

Contingencies

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 accounting 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.

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

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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.

Legal and Tax Matters
Our legal and tax matters are handled by our legal and tax organizations. These organizations apply their knowledge, experience and professional judgment to the specific characteristics of our cases and uncertain tax positions. We employ 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. In the case of income-tax-related contingencies, we monitor tax legislation and court decisions, the status of tax audits and the statute of limitations within which a taxing authority can assert a liability.

Environmental
We are subject to the same numerous international, federal, state and local environmental laws and regulations as other companies in our industry. For a discussion of the most significant of these environmental laws and regulations, including those with associated remediation obligations, see the “Environmental” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 50, 51 and 52 of our 2013 Annual Report on Form 10-K.

From time to time, we receive requests for information or notices of potential liability from the U.S. Environmental Protection Agency (EPA) and state environmental agencies alleging that we are a potentially responsible party under the Federal Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) or an equivalent state statute. On occasion, we also have been made a party to cost recovery litigation by those agencies or by private parties. These requests, notices and lawsuits assert potential liability for remediation costs at various sites that typically are not owned by us, but allegedly contain wastes attributable to our past operations. As of December 31, 2013, we reported that we had been notified of potential liability under CERCLA and comparable state laws at 35 sites around the United States. During the first nine months of 2014, there were no new sites for which we received notification of potential liability and one site was deemed resolved and closed, leaving 34 unresolved sites with potential liability at September 30, 2014.

At September 30, 2014, our total environmental accrual was $519 million, compared with $492 million at December 31, 2013. We expect to incur a substantial amount of these expenditures within the next 30 years.

Notwithstanding any of the foregoing, and as with other companies engaged in similar businesses, environmental costs and liabilities are inherent concerns in our operations and products, and there can be no assurance that material costs and liabilities will not be incurred. However, we currently do not expect any material adverse effect on our results of operations or financial position as a result of compliance with current environmental laws and regulations.

Climate Change
There has been a broad range of proposed or promulgated state, national and international laws focusing on greenhouse gas (GHG) emissions reduction, including various regulations proposed or issued by the EPA. These proposed or promulgated laws apply or could apply in states and/or countries where we have interests or may have interests in the future. We consider and take into account future GHG emissions in designing and developing major facilities and projects, and implement energy efficiency initiatives to reduce such emissions. Laws in this field continue to evolve, and while it is not possible to accurately estimate either a timetable for implementation or our future compliance costs relating to implementation, such laws, if enacted, potentially could have a material impact on our results of operations and financial condition as a result of increasing costs of compliance, lengthening project implementation and agency review times, or reducing demand for certain hydrocarbon products. We continue to monitor legislative and regulatory actions and legal proceedings globally relating to GHG emissions for potential impacts on our operations.


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For examples of legislation or precursors for possible regulation that do or could affect our operations, see the “Climate Change” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 53 and 54 of our 2013 Annual Report on Form 10-K.


NEW ACCOUNTING STANDARDS

In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The new standard converged guidance on recognizing revenues in contracts with customers under accounting principles generally accepted in the United States and International Financial Reporting Standards. This ASU is intended to improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. ASU 2014-09 is effective for annual and quarterly reporting periods of public entities beginning after December 15, 2016. Early application for public entities is not permitted. We are currently evaluating the provisions of ASU 2014-09 and assessing the impact, if any, it may have on our financial position and results of operations.


OUTLOOK

On October 22, 2014, we entered into an agreement to contribute to Phillips 66 Partners certain logistics assets for total consideration of $340 million. These assets consist of two new crude oil rail-unloading facilities located at or adjacent to our Bayway and Ferndale refineries, and the Cross-Channel Connector pipeline assets located near the partnership’s Pasadena terminal. Phillips 66 Partners expects to finance the acquisition with the borrowing of $28 million under its revolving credit facility, the assumption of a 5-year, $244 million note payable to a subsidiary of Phillips 66, and the issuance to Phillips 66 of 1,066,412 common and 21,764 general partner units valued at $68 million. The transaction is anticipated to close in December 2014. Since we consolidate Phillips 66 Partners for financial reporting purposes, the note payable and unit issuances will eliminate in consolidation, while consolidated cash and debt will both increase by $28 million.


CAUTIONARY STATEMENT FOR THE PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. You can identify our forward-looking statements by the words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target” and similar expressions.

We based the forward-looking statements on our current expectations, estimates and projections about us and the industries in which we operate in general. We caution you these statements are not guarantees of future performance as they involve assumptions that, while made in good faith, may prove to be incorrect, and involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecast in the forward-looking statements. Any differences could result from a variety of factors, including the following:

Fluctuations in NGL, crude oil and natural gas prices and petrochemical and refining margins.
Failure of new products and services to achieve market acceptance.
Unexpected changes in costs or technical requirements for constructing, modifying or operating our facilities or transporting our products.
Unexpected technological or commercial difficulties in manufacturing, refining or transporting our products, including chemicals products.
Lack of, or disruptions in, adequate and reliable transportation for our NGL, crude oil, natural gas and refined products.

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The level and success of natural gas drilling around DCP Midstream’s assets, the level and quality of gas production volumes around its assets and its ability to connect supplies to its gathering and processing systems in light of competition.
Inability to timely obtain or maintain permits, including those necessary for capital projects; comply with government regulations; or make capital expenditures required to maintain compliance.
Failure to complete definitive agreements and feasibility studies for, and to timely complete construction of, announced and future capital projects.
Potential disruption or interruption of our operations due to accidents, weather events, civil unrest, political events, terrorism or cyber attacks.
International monetary conditions and exchange controls.
Substantial investment or reduced demand for products as a result of existing or future environmental rules and regulations.
Liability resulting from litigation or for remedial actions, including removal and reclamation obligations under environmental regulations.
General domestic and international economic and political developments including: armed hostilities; expropriation of assets; changes in governmental policies relating to NGL, crude oil, natural gas or refined product pricing, regulation or taxation; and other political, economic or diplomatic developments.
Changes in tax, environmental and other laws and regulations (including alternative energy mandates) applicable to our business.
Limited access to capital or significantly higher cost of capital related to changes to our credit profile or illiquidity or uncertainty in the domestic or international financial markets.
The operation, financing and distribution decisions of our joint ventures.
Domestic and foreign supplies of crude oil and other feedstocks.
Domestic and foreign supplies of petrochemicals and refined products, such as gasoline, diesel, jet fuel and home heating oil.
Governmental policies relating to exports of crude oil and natural gas.
Overcapacity or undercapacity in the midstream, chemicals and refining industries.
Fluctuations in consumer demand for refined products.
The factors generally described in Item 1A.—Risk Factors in our 2013 Annual Report on Form 10-K.


Item 3.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market risks at September 30, 2014, do not differ materially from the risks discussed under Item 7A in our 2013 Annual Report on Form 10-K.


Item 4.   CONTROLS AND PROCEDURES

We maintain disclosure controls and procedures designed to ensure that information required to be disclosed in reports we file or submit under the Securities Exchange Act of 1934, as amended (the Act), is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to management, including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. As of September 30, 2014, with the participation of management, our Chairman and Chief Executive Officer and our Executive Vice President, Finance and Chief Financial Officer carried out an evaluation, pursuant to Rule 13a-15(b) of the Act, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) of the Act). Based upon that evaluation, our Chairman and Chief Executive Officer and our Executive Vice President, Finance and Chief Financial Officer concluded that our disclosure controls and procedures were operating effectively as of September 30, 2014.

There have been no changes in our internal control over financial reporting, as defined in Rule 13a-15(f) of the Act, in the quarterly period ended September 30, 2014, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.



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PART II. OTHER INFORMATION

Item 1.   LEGAL PROCEEDINGS

The following is a description of reportable legal proceedings, including those involving governmental authorities under federal, state and local laws regulating the discharge of materials into the environment, for this reporting period. The information below includes material developments with respect to matters previously reported in our 2013 Annual Report on Form 10-K or our Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2014, and June 30, 2014. There were no new matters that arose during the third quarter of 2014. While it is not possible to accurately predict the final outcome of these pending proceedings, if any one or more of such proceedings were decided adversely to Phillips 66, we expect there would be no material effect on our consolidated financial position. Nevertheless, such proceedings are reported pursuant to the SEC regulations.

Our U.S. refineries are implementing two separate consent decrees, regarding alleged violations of the Federal Clean Air Act, with the EPA, six states and one local air pollution agency. Some of the requirements and limitations contained in the decrees provide for stipulated penalties for violations. Stipulated penalties under the decrees are not automatic, but must be requested by one of the agency signatories. As part of periodic reports under the decrees or other reports required by permits or regulations, we occasionally report matters that could be subject to a request for stipulated penalties. If a specific request for stipulated penalties meeting the reporting threshold set forth in SEC rules is made pursuant to these decrees based on a given reported exceedance, we will separately report that matter and the amount of the proposed penalty.

Matters Previously Reported
On May 19, 2010, we received a Consolidated Compliance Order and Notice of Potential Penalty from the Louisiana Department of Environmental Quality (LDEQ) alleging various violations of applicable air emission regulations at the Lake Charles Refinery, as well as certain provisions of the consent decree in Civil Action No. H-01-4430. In July 2014, we resolved the consent decree issues and are working with the LDEQ to resolve the remaining allegations.


Item 1A.   RISK FACTORS

There have been no material changes from the risk factors disclosed in Item 1A of our 2013 Annual Report on
Form 10-K.


Item 2.   UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Issuer Purchases of Equity Securities

 
 
 
 
 
 
Millions of Dollars

Period
Total Number of Shares Purchased*
 
Average Price Paid per Share

Total Number of Shares Purchased
as Part of Publicly Announced Plans
or Programs**
 
Approximate Dollar Value of Shares
that May Yet Be Purchased Under the Plans or Programs

July 1-31, 2014
2,722,915
 
$
80.81

2,722,915
 
$
2,922

August 1-31, 2014
1,713,329
 
83.48

1,713,329
 
2,779

September 1-30, 2014
1,534,423
 
85.39

1,534,423
 
2,648

Total
5,970,667
 
$
82.76

5,970,667
 

* Includes repurchase of shares of common stock from company employees in connection with the company’s broad-based employee incentive plans, when applicable.
** During 2012 and 2013, our Board of Directors authorized the repurchase of up to $5 billion of our outstanding common stock. We began purchases under this authorization, which has no expiration date, in the third quarter of 2012. In July 2014, our Board of Directors approved the repurchase of an additional $2 billion of our outstanding common stock. The share repurchases are expected to be funded primarily through available cash. The shares under these authorizations will be repurchased from time to time in the open market at the company’s discretion, subject to market conditions and other factors, and in accordance with applicable regulatory requirements. We are not obligated to acquire any particular amount of common stock and may commence, suspend or discontinue purchases at any time or from time to time without prior notice. Shares of stock repurchased are held as treasury shares.

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Item 6. EXHIBITS
 
Exhibit
Number
 
Exhibit Description
 
 
 
10.1
 
Fifth Amendment to July 5, 2005 Second Amended and Restated Limited Liability Company Agreement of DCP Midstream, LLC (formerly Duke Energy Field Services, LLC), dated September 9, 2014, by and between Phillips Gas Company (formerly ConocoPhillips Gas Company), Spectra Energy DEFS Holding, LLC, and Spectra Energy DEFS Holding II, LLC.
 
 
 
12
 
Computation of Ratio of Earnings to Fixed Charges.
 
 
 
31.1
 
Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
 
 
 
31.2
 
Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
 
 
 
32
 
Certifications pursuant to 18 U.S.C. Section 1350.
 
 
 
101.INS
 
XBRL Instance Document.
 
 
 
101.SCH
 
XBRL Schema Document.
 
 
 
101.CAL
 
XBRL Calculation Linkbase Document.
 
 
 
101.LAB
 
XBRL Labels Linkbase Document.
 
 
 
101.PRE
 
XBRL Presentation Linkbase Document.
 
 
 
101.DEF
 
XBRL Definition Linkbase Document.
 
 
 
 
    

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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 
PHILLIPS 66
 
 
 
/s/ C. Doug Johnson
 
C. Doug Johnson
Vice President and Controller
(Chief Accounting and Duly Authorized Officer)
 
 
October 30, 2014
 



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