10-K 1 psx-20151231_10k.htm 10-K 10-K
2015
 
UNITED STATES
 
 
SECURITIES AND EXCHANGE COMMISSION
 
 
Washington, D.C. 20549
 
 
FORM 10-K
 
(Mark One)
 
 
[X]
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the fiscal year ended
December 31, 2015
 
 
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)
 
 
Registrant’s telephone number, including area code: 281-293-6600
 
 
Securities registered pursuant to Section 12(b) of the Act:
 
 
Title of each class
 
Name of each exchange on which registered
 
 
Common Stock, $.01 Par Value
 
New York Stock Exchange
 
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
[X] Yes [ ] No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
[ ] Yes [X] No
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.
[X] Yes [ ] No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
[X] Yes [ ] No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.
[X]
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 Act).
[ ] Yes [X] No
The aggregate market value of common stock held by non-affiliates of the registrant on June 30, 2015, the last business day of the registrant’s most recently completed second fiscal quarter, based on the closing price on that date of $80.56, was $43.3 billion. The registrant, solely for the purpose of this required presentation, had deemed its Board of Directors and executive officers to be affiliates, and deducted their stockholdings in determining the aggregate market value.
The registrant had 527,459,894 shares of common stock outstanding at January 31, 2016.
Documents incorporated by reference:
Portions of the Proxy Statement for the Annual Meeting of Stockholders to be held on May 4, 2016 (Part III).



TABLE OF CONTENTS
Item
Page
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

 



Unless otherwise indicated, “the company,” “we,” “our,” “us” and “Phillips 66” are used in this report to refer to the businesses of Phillips 66 and its consolidated subsidiaries. This Annual Report on Form 10-K contains forward-looking statements including, without limitation, statements relating to our 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 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.”


PART I

Items 1 and 2. BUSINESS AND PROPERTIES


CORPORATE STRUCTURE

Phillips 66, headquartered in Houston, Texas, was incorporated in Delaware in 2011 in connection with, and in anticipation of, a restructuring of ConocoPhillips resulting in the separation of its downstream businesses into an independent, publicly traded company named Phillips 66. The two companies were separated by ConocoPhillips distributing to its stockholders all the shares of common stock of Phillips 66 after the market closed on April 30, 2012 (the Separation). On May 1, 2012, Phillips 66 stock began trading “regular-way” on the New York Stock Exchange under the “PSX” stock symbol.

Our business is organized into four operating segments:

1)
Midstream—Gathers, processes, transports and markets natural gas; and transports, fractionates and markets natural gas liquids (NGL) in the United States. In addition, this segment transports crude oil and other feedstocks to our refineries and other locations, delivers refined and specialty products to market, and provides terminaling and storage services for crude oil and petroleum products. The Midstream segment includes our master limited partnership, Phillips 66 Partners LP, as well as our 50 percent equity investment in DCP Midstream, LLC (DCP Midstream).

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

3)
Refining—Buys, sells and refines crude oil and other feedstocks at 14 refineries, mainly in the United States and Europe.

4)
Marketing and Specialties (M&S)—Purchases for resale and markets refined petroleum products (such as gasolines, distillates and aviation fuels), mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products, as well as power generation operations.

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

At December 31, 2015, Phillips 66 had approximately 14,000 employees.



1


SEGMENT AND GEOGRAPHIC INFORMATION

For operating segment and geographic information, see Note 26—Segment Disclosures and Related Information, in the Notes to Consolidated Financial Statements, which is incorporated herein by reference.


MIDSTREAM

The Midstream segment consists of three business lines:

Transportation—transports crude oil and other feedstocks to our refineries and other locations, delivers refined and specialty products to market, and provides terminaling and storage services for crude oil and petroleum products.

DCP Midstream—gathers, processes, transports and markets natural gas and transports, fractionates and markets NGL.

NGL—transports, fractionates and markets natural gas liquids.

Phillips 66 Partners LP
In 2013, we formed Phillips 66 Partners LP, a master limited partnership (MLP), 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. At December 31, 2015, we owned a 69 percent limited partner interest and a 2 percent general partner interest in Phillips 66 Partners, while the public owned a 29 percent limited partner interest.

Headquartered in Houston, Texas, Phillips 66 Partners’ assets and equity investments consist of crude oil, NGL and refined petroleum product pipelines, terminals, rail racks and storage systems that are geographically dispersed throughout the United States, most of which are integral to a Phillips 66-operated refinery.

During 2015, Phillips 66 Partners expanded its business by acquiring from us:

One-third equity interests in DCP Sand Hills Pipeline, LLC (Sand Hills) and DCP Southern Hills Pipeline, LLC (Southern Hills), as well as a 19.5 percent equity interest in Explorer Pipeline Company (Explorer). This acquisition closed in March 2015.

A 40 percent equity interest in Bayou Bridge Pipeline, LLC (Bayou Bridge). This acquisition closed in December 2015.

The operations and financial results of Phillips 66 Partners are included in either the Transportation or NGL business line, based on the nature of the activity within the partnership.

Transportation

We own or lease various assets to provide environmentally safe, strategic and timely delivery and terminaling and storage of crude oil, refined products, natural gas and NGL. These assets include pipeline systems; petroleum product, crude oil and liquefied petroleum gas (LPG) terminals; a petroleum coke handling facility; marine vessels; railcars and trucks.

Pipelines and Terminals
At December 31, 2015, our Transportation business managed over 18,000 miles of crude oil, natural gas, NGL and petroleum products pipeline systems in the United States, including those partially owned or operated by affiliates. We owned or operated 39 finished product terminals, 37 storage locations, 5 LPG terminals, 16 crude oil terminals and 1 petroleum coke exporting facility.

During 2015, we continued to invest in our Beaumont Terminal, the largest terminal in the Phillips 66 portfolio, which currently has 4.7 million barrels of crude oil storage capacity and 2.4 million barrels of refined product storage capacity. As of December 31, 2015, we had 2.0 million barrels of incremental crude storage capacity under construction, which is

2


expected to be completed in the third quarter of 2016. In addition, we have initiated a variety of other projects aimed at increasing storage and throughput capabilities as we continue the expansion of the Beaumont terminal from its current 7.1 million barrels of storage capacity to 16 million barrels.

Construction progressed in 2015 on our two crude oil pipeline systems being developed by our joint ventures, Dakota Access LLC (DAPL) and Energy Transfer Crude Oil Company, LLC (ETCOP). Phillips 66 owns 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 pipeline systems. The DAPL pipeline is expected to deliver 470,000 barrels per day of crude oil from the Bakken/Three Forks production area in North Dakota to market centers in the Midwest. The DAPL pipeline will provide shippers with access to Midwestern refineries, unit-train rail loading facilities to facilitate deliveries to East Coast refineries, and the Gulf Coast market through an interconnection in Patoka, Illinois, with ETCOP pipeline. The ETCOP pipeline will provide crude oil transportation service from the Midwest to the Sunoco Logistics Partners L.P. (Sunoco Logistics) and Phillips 66 storage terminals located in Nederland, Texas. The pipelines are expected to be operational in fourth-quarter 2016.

In the third quarter of 2015, Phillips 66 became a joint venture partner with a 40 percent equity interest in Bayou Bridge. Energy Transfer Partners, L.P. (ETP) and Sunoco Logistics each hold a 30 percent interest in the joint venture, with Sunoco Logistics serving as the operator. The joint venture was formed for the funding and development of the Bayou Bridge pipeline.  The Bayou Bridge pipeline is a new-build 30” and 24” pipeline that will deliver crude oil from Nederland, Texas, to Lake Charles, Louisiana and on to St. James, Louisiana. Phillips 66 is constructing the segment to Lake Charles, which will be in service by the end of first-quarter 2016.  The remaining section of the pipeline, which will be constructed by ETP, is scheduled for completion in the second half of 2017. Effective December 1, 2015, Phillips 66 Partners acquired Phillips 66’s 40 percent equity interest in Bayou Bridge.

In the fourth quarter of 2015, Phillips 66 Partners commenced operation of the Palermo Rail Terminal, which is located on a 710-acre site near Palermo, North Dakota. The crude terminal has an initial capacity of 100,000 barrels per day, with the flexibility to be expanded to 200,000 barrels per day.  It is located on a railway with two mainline switches, allowing east- and west-bound deliveries. The terminal includes 6 truck unloading facilities and 206,000 barrels of operational storage, with permits allowing total storage capacity of up to 2.4 million barrels, as well as space for 6 additional truck unloading facilities.  The terminal is owned by the joint venture Phillips 66 Partners Terminal LLC, of which Phillips 66 Partners holds a 70 percent interest, with Paradigm Energy Partners, LLC (Paradigm) owning the remaining 30 percent interest. Phillips 66 Partners is the operator.

In 2016, the Palermo Rail Terminal is anticipated to include a pipeline delivery and receipt connection to the 76-mile Sacagawea Pipeline, allowing the terminal to receive crude oil from areas in Dunn County and McKenzie County, North Dakota, and deliver it to terminals and pipelines located in Stanley, North Dakota.  The Sacagawea Pipeline is owned by the joint venture Sacagawea Pipeline Company, LLC, of which Paradigm Pipeline LLC holds an 88 percent interest, with the remaining 12 percent interest owned by Grey Wolf Midstream, LLC. Phillips 66 Partners and Paradigm each own a 50 percent interest in Paradigm Pipeline LLC.  Paradigm is constructing the pipeline and Phillips 66 Partners will be the operator.





3


The following table depicts our ownership interest in major pipeline systems as of December 31, 2015:
Name
 
Origination/Terminus
 
Interest

 
Size
 
Length(Miles)

 
Gross Capacity
(MBD)

Crude and Feedstocks
 
 
 
 
 
 
 
 
 
 
Glacier
 
Cut Bank, MT/Billings, MT
 
79
%
 
8”-12”
 
865

 
126

Line 80
 
Gaines, TX/Borger, TX
 
100

 
8”, 12”
 
237

 
28

Line O
 
Cushing, OK/Borger, TX
 
100

 
10”
 
276

 
37

WA Line
 
Odessa, TX/Borger, TX
 
100

 
12”, 14”
 
289

 
104

Cushing
 
Cushing, OK/Ponca City, OK
 
100

 
18”
 
62

 
130

North Texas Crude
 
Wichita Falls, TX
 
100

 
2”-16”
 
224

 
28

Oklahoma Mainline
 
Wichita Falls, TX/Ponca City, OK
 
100

 
12”
 
217

 
100

Clifton Ridge †
 
Clifton Ridge, LA/Westlake, LA
 
71

 
20”
 
10

 
260

Eagle Ford Gathering †
 
Helena, TX
 
71

 
6”
 
6

 
20

Eagle Ford Gathering †
 
Tilden, TX/Whitsett, TX
 
71

 
6”, 10”
 
22

 
34

Louisiana Crude Gathering
 
Rayne, LA/Westlake, LA
 
100

 
4”-8”
 
80

 
25

Sweeny Crude
 
Sweeny, TX/Freeport, TX
 
100

 
12”, 24”, 30”
 
56

 
265

Line 100
 
Taft, CA/Lost Hills, CA
 
100

 
8”, 10”, 12”
 
79

 
54

Line 200
 
Lost Hills, CA/Rodeo, CA
 
100

 
12”, 16”
 
228

 
93

Line 300
 
Nipomo, CA/Arroyo Grande, CA
 
100

 
8”, 10”, 12”
 
56

 
48

Line 400
 
Arroyo Grande, CA/Lost Hills, CA
 
100

 
8”, 10”, 12”
 
147

 
40

Petroleum Products
 
 
 
 
 
 
 
 
 
 
Harbor
 
Woodbury, NJ/Linden, NJ
 
33

 
16”
 
80

 
171

Pioneer
 
Sinclair, WY/Salt Lake City, UT
 
50

 
8”, 12”
 
562

 
63

Seminoe
 
Billings, MT/Sinclair, WY
 
100

 
6”-10”
 
342

 
33

Yellowstone
 
Billings, MT/Moses Lake, WA
 
46

 
6”-10”
 
710

 
66

Borger to Amarillo
 
Borger, TX/Amarillo, TX
 
100

 
8”, 10”
 
93

 
76

ATA Line
 
Amarillo, TX/Albuquerque, NM
 
50

 
6”, 10”
 
293

 
34

Borger-Denver
 
McKee, TX/Denver, CO
 
70

 
6”-12”
 
405

 
38

Gold Line †
 
Borger, TX/East St. Louis, IL
 
71

 
8”-16”
 
681

 
120

SAAL
 
Amarillo, TX/Abernathy, TX
 
33

 
6”
 
102

 
33

SAAL
 
Abernathy, TX/Lubbock, TX
 
54

 
6”
 
19

 
30

Cherokee South
 
Ponca City, OK/Oklahoma City, OK
 
100

 
8”
 
90

 
46

Heartland*
 
McPherson, KS/Des Moines, IA
 
50

 
8”, 6”
 
49

 
30

Paola Products †
 
Paola, KS/Kansas City, KS
 
71

 
8”, 10”
 
106

 
96

Standish
 
Marland Junction, OK/Wichita, KS
 
100

 
18”
 
92

 
72

Cherokee North
 
Ponca City, OK/Arkansas City, KS
 
100

 
10”
 
29

 
57

Cherokee East
 
Medford, OK/Mount Vernon, MO
 
100

 
10”, 12”
 
287

 
55

Cross Channel Connector †
 
Pasadena, TX/Galena Park, TX
 
71

 
20”
 
5

 
180

Explorer***†
 
Texas Gulf Coast/Chicago, IL
 
14

 
24”, 28”
 
1,830

 
660

Sweeny to Pasadena †
 
Sweeny, TX/Pasadena, TX
 
71

 
12”, 18”
 
120

 
294

LAX Jet Line
 
Wilmington, CA/Los Angeles, CA
 
50

 
8”
 
19

 
50

Torrance Products
 
Wilmington, CA/Torrance, CA
 
100

 
10”, 12”
 
8

 
161

Los Angeles Products
 
Torrance, CA/Los Angeles, CA
 
100

 
6”, 12”
 
22

 
112

Watson Products Line
 
Wilmington, CA/Long Beach, CA
 
100

 
20”
 
9

 
238

Richmond
 
Rodeo, CA/Richmond, CA
 
100

 
6”
 
14

 
26


4


Name
 
Origination/Terminus
 
Interest

 
Size
 
Length (Miles)

 
Gross Capacity
(MBD)

NGL
 
 
 
 
 
 
 
 
 
 
Powder River
 
Sage Creek, WY/Borger, TX
 
100
%
 
6”-8”
 
705

 
14

Skelly-Belvieu
 
Skellytown, TX/Mont Belvieu, TX
 
50

 
8”
 
571

 
45

TX Panhandle Y1/Y2
 
Sher-Han, TX/Borger, TX
 
100

 
3”-10”
 
299

 
61

Chisholm
 
Kingfisher, OK/Conway, KS
 
50

 
4”-10”
 
202

 
42

Sand Hills**†
 
Permian Basin/Mont Belvieu, TX
 
24

 
20”
 
1,190

 
250

Southern Hills**†
 
U.S. Midcontinent/Mont Belvieu, TX
 
24

 
20”
 
940

 
175

Sweeny NGL
 
Brazoria, TX/Sweeny, TX
 
100

 
20”
 
18

 
204

LPG
 
 
 
 
 
 
 
 
 
 
Blue Line
 
Borger, TX/East St. Louis, IL
 
100

 
8”-12”
 
688

 
29

Brown Line
 
Ponca City, OK/Wichita, KS
 
100

 
8”, 10”
 
76

 
26

Conway to Wichita
 
Conway, KS/Wichita, KS
 
100

 
12”
 
55

 
38

Medford
 
Ponca City, OK/Medford, OK
 
100

 
4”-6”
 
42

 
10

Sweeny LPG Lines
 
Sweeny/Mont Belvieu & Freeport, TX
 
100

 
10”-20”
 
246

 
842

Natural Gas
 
 
 
 
 
 
 
 
 
 
Rockies Express
 
Meeker, CO/Clarington, OH
 
25

 
36”-42”
 
1,712

 
1.8 BCFD

Owned by Phillips 66 Partners LP; Phillips 66 held a 71 percent ownership interest in Phillips 66 Partners LP at December 31, 2015.
*Total pipeline system is 419 miles. Phillips 66 has ownership interest in multiple segments totaling 49 miles.
**Operated by DCP Midstream Partners, LP; Phillips 66 Partners holds a direct one-third ownership in the pipeline entities.
***Phillips 66 Partners holds a 19.5 percent ownership in Explorer.
     


5


The following table depicts our ownership interest in finished product terminals as of December 31, 2015:
Facility Name
 
Location
 
Interest

 
Gross Storage Capacity (MBbl)

 
Gross Rack Capacity (MBD)

Albuquerque
 
New Mexico
 
100
%
 
244

 
18

Amarillo
 
Texas
 
100

 
277

 
29

Beaumont
 
Texas
 
100

 
2,400

 
8

Billings
 
Montana
 
100

 
88

 
16

Bozeman
 
Montana
 
100

 
113

 
13

Colton
 
California
 
100

 
211

 
21

Denver
 
Colorado
 
100

 
310

 
43

Des Moines
 
Iowa
 
50

 
206

 
15

East St. Louis †
 
Illinois
 
71

 
2,085

 
78

Glenpool North
 
Oklahoma
 
100

 
366

 
19

Great Falls
 
Montana
 
100

 
198

 
12

Hartford †
 
Illinois
 
71

 
1,075

 
25

Helena
 
Montana
 
100

 
178

 
10

Jefferson City †
 
Missouri
 
71

 
110

 
16

Kansas City †
 
Kansas
 
71

 
1,294

 
66

La Junta
 
Colorado
 
100

 
101

 
10

Lincoln
 
Nebraska
 
100

 
219

 
21

Linden
 
New Jersey
 
100

 
429

 
121

Los Angeles
 
California
 
100

 
116

 
75

Lubbock
 
Texas
 
100

 
179

 
17

Missoula
 
Montana
 
50

 
368

 
29

Moses Lake
 
Washington
 
50

 
186

 
13

Mount Vernon
 
Missouri
 
100

 
363

 
46

North Salt Lake
 
Utah
 
50

 
657

 
41

Oklahoma City
 
Oklahoma
 
100

 
352

 
48

Pasadena †
 
Texas
 
71

 
3,210

 
65

Ponca City
 
Oklahoma
 
100

 
51

 
23

Portland
 
Oregon
 
100

 
664

 
33

Renton
 
Washington
 
100

 
228

 
20

Richmond
 
California
 
100

 
334

 
28

Rock Springs
 
Wyoming
 
100

 
125

 
19

Sacramento
 
California
 
100

 
141

 
13

Sheridan
 
Wyoming
 
100

 
86

 
15

Spokane
 
Washington
 
100

 
351

 
24

Tacoma
 
Washington
 
100

 
307

 
17

Tremley Point
 
New Jersey
 
100

 
1,593

 
39

Westlake
 
Louisiana
 
100

 
128

 
16

Wichita Falls
 
Texas
 
100

 
303

 
15

Wichita North †
 
Kansas
 
71

 
679

 
19

Owned by Phillips 66 Partners LP; Phillips 66 held a 71 percent ownership interest in Phillips 66 Partners LP at December 31, 2015.


6


The following table depicts our ownership interest in crude and other terminals as of December 31, 2015:
Facility Name
 
Location
 
Interest

 
Gross Storage Capacity (MBbl)

 
 Gross Loading Capacity**

Crude
 
 
 
 
 
 
 
 
Beaumont
 
Texas
 
100
%
 
4,704

 
N/A

Billings
 
Montana
 
100

 
270

 
N/A

Borger
 
Texas
 
100

 
721

 
N/A

Clifton Ridge †
 
Louisiana
 
71

 
3,410

 
N/A

Cushing
 
Oklahoma
 
100

 
700

 
N/A

Junction
 
California
 
100

 
523

 
N/A

McKittrick
 
California
 
100

 
237

 
N/A

Odessa
 
Texas
 
100

 
523

 
N/A

Palermo*
 
North Dakota
 
50

 
206

 
N/A

Pecan Grove †
 
Louisiana
 
71

 
142

 
N/A

Ponca City
 
Oklahoma
 
100

 
1,200

 
N/A

Santa Margarita
 
California
 
100

 
335

 
N/A

Santa Maria
 
California
 
100

 
112

 
N/A

Tepetate
 
Louisiana
 
100

 
152

 
N/A

Torrance
 
California
 
100

 
309

 
N/A

Wichita Falls
 
Texas
 
100

 
240

 
N/A

Petroleum Coke
 
 
 
 
 
 
 
 
Lake Charles
 
Louisiana
 
50

 
N/A

 
N/A

Rail
 
 
 
 
 
 
 
 
Bayway †
 
New Jersey
 
71

 
N/A

 
75

Beaumont
 
Texas
 
100

 
N/A

 
20

Ferndale †
 
Washington
 
71

 
N/A

 
30

Missoula
 
Montana
 
50

 
N/A

 
82

Palermo*
 
North Dakota
 
50

 
N/A

 
100

Thompson Falls
 
Montana
 
50

 
N/A

 
84

Marine
 
 
 
 
 
 
 
 
Beaumont
 
Texas
 
100

 
N/A

 
13

Clifton Ridge †
 
Louisiana
 
71

 
N/A

 
48

Hartford †
 
Illinois
 
71

 
N/A

 
3

Pecan Grove †
 
Louisiana
 
71

 
N/A

 
6

Portland
 
Oregon
 
100

 
N/A

 
10

Richmond
 
California
 
100

 
N/A

 
3

Tacoma
 
Washington
 
100

 
N/A

 
12

Tremley Point
 
New Jersey
 
100

 
N/A

 
7

Owned by Phillips 66 Partners LP; Phillips 66 held a 71 percent ownership interest in Phillips 66 Partners LP at December 31, 2015.
*Owned by Phillips 66 Partners Terminal LLC; Phillips 66 Partners holds a 70 percent ownership interest in Phillips 66 Partners Terminal LLC.
**Rail in thousands of barrels daily (MBD); Marine in thousands of barrels per hour.
 

Rockies Express Pipeline LLC (REX)
We have a 25 percent interest in REX. The REX natural gas pipeline runs 1,712 miles from Meeker, Colorado, to Clarington, Ohio, and has a natural gas transmission capacity of 1.8 billion cubic feet per day (BCFD), with most of its system having a pipeline diameter of 42 inches. Numerous compression facilities support the pipeline system. The REX pipeline was originally designed to enable natural gas producers in the Rocky Mountain region to deliver natural gas supplies to the Midwest and eastern regions of the United States. During 2015, as a result of east-to-west expansion projects, the REX Pipeline began transporting natural gas supplies from the Appalachian Basin to Midwest markets.

7


Marine Vessels
At December 31, 2015, we had 12 double-hulled, international-flagged crude oil and product tankers under term charter, with capacities ranging in size from 300,000 to 1,100,000 barrels. Additionally, we had under term charter three Jones Act compliant tankers and 66 tug/barge units. These vessels are used primarily to transport feedstocks or provide product transportation for certain of our refineries, including delivery of domestic crude oil to our Gulf Coast and East Coast refineries.
 
Truck and Rail
Truck and rail operations support our feedstock and distribution operations. Rail movements are provided via a fleet of more than 12,300 owned and leased railcars. Truck movements are provided through approximately 170 third-party truck companies, as well as through Sentinel Transportation LLC, in which we hold a 20 percent equity interest.

DCP Midstream

Our Midstream segment includes our 50 percent equity investment in DCP Midstream, which is headquartered in Denver, Colorado. As of December 31, 2015, DCP Midstream owned or operated 64 natural gas processing facilities, with a net processing capacity of approximately 8.0 BCFD. DCP Midstream’s owned or operated natural gas pipeline systems included gathering services for these facilities, as well as natural gas transmission, and totaled approximately 68,000 miles of pipeline. DCP Midstream also owned or operated 12 NGL fractionation plants, along with natural gas and NGL storage facilities, a propane wholesale marketing business and NGL pipeline assets.

The residual natural gas, primarily methane, which results from processing raw natural gas, is sold by DCP Midstream at market-based prices to marketers and end users, including large industrial companies, natural gas distribution companies and electric utilities. DCP Midstream purchases or takes custody of substantially all of its raw natural gas from producers, principally under contractual arrangements that expose DCP Midstream to the prices of NGL, natural gas and condensate. DCP Midstream also has fee-based arrangements with producers to provide midstream services such as gathering and processing.

DCP Midstream markets a portion of its NGL to us and CPChem under existing 15-year contracts, the primary commitment of which began a ratable wind-down period in December 2014 and expires in January 2019. These purchase commitments are on an “if-produced, will-purchase” basis.
During 2015, DCP Midstream and DCP Midstream Partners, LP (DCP Partners), the MLP formed by DCP Midstream, completed or advanced the following growth projects:
The Sand Hills laterals were placed into service in the second and third quarters of 2015. The Sand Hills pipeline capacity expansion is underway and expected to be in service in the middle of 2016.
In March 2015, construction began on a gathering system in the Denver-Julesburg (DJ) Basin, named the Grand Parkway gathering project, with expected completion in the first quarter of 2016.
The expansion of the Keathley Canyon natural gas gathering pipeline system, which is part of DCP Partners’ Discovery joint venture, was placed into service in the first quarter of 2015.
The Lucerne 2 plant was placed into service in mid-2015.


8


NGL

Our NGL business includes the following:
 
The 100,000 barrels-per-day (BPD) Sweeny Fractionator One is located in Old Ocean, Texas. The fractionator is supported by 250 miles of new pipelines and the Clemens Caverns storage facility located near Brazoria, Texas, with connectivity to local petrochemical customers, the Mont Belvieu market hub and our marine terminal in Freeport, Texas.

A 22.5 percent equity interest in Gulf Coast Fractionators, which owns an NGL fractionation plant in Mont Belvieu, Texas. We operate the facility, and our net share of its capacity is 32,625 barrels per day.

A 12.5 percent equity interest in a fractionation plant in Mont Belvieu, Texas. Our net share of its capacity is 30,250 barrels per day.

A 40 percent interest in a fractionation plant in Conway, Kansas. Our net share of its capacity is 43,200 barrels per day.

Phillips 66 Partners owns a direct one-third interest in both Sand Hills and Southern Hills, whose pipelines connect Eagle Ford, Permian and Midcontinent production to the Mont Belvieu, Texas market.

In December 2015, operations began at Sweeny Fractionator One. Sweeny Fractionator One is located adjacent to our Sweeny Refinery and supplies purity ethane and LPG to the petrochemical industry and heating markets. Raw NGL supply to the fractionator is delivered from nearby major pipelines, including the Sand Hills pipeline.

The fractionator is supported by significant new infrastructure including connectivity to two NGL supply pipelines, a 180,000 BPD bi-directional pipeline to the Mont Belvieu market center and a multi-million barrel salt dome storage facility with access to our marine terminal in Freeport, Texas.

During 2015, construction progressed on the Freeport LPG Export Terminal located at the site of our existing marine terminal in Freeport, Texas. The terminal expansion will leverage our transportation and storage infrastructure to supply petrochemical, heating and transportation markets globally. In addition, a 100,000 BPD unit to upgrade domestic propane for export is being installed near the Sweeny Fractionator One. The terminal will have an initial export capacity of 150,000 BPD of LPG with a ship loading rate of 36,000 barrels per hour. The terminal is currently exporting 10,000 to 15,000 BPD of natural gasoline (C5+) from Sweeny Fractionator One.

The LPG produced at Sweeny Fractionator One is being delivered via pipeline to local petrochemical customers, as well as to the market hub at Mont Belvieu, Texas. We will have the capability to place the LPG into global markets upon completion of our Freeport LPG Export Terminal in the second half of 2016. Sweeny Fractionator One and the Freeport LPG Export Terminal represent a combined capital investment of more than $3 billion.


CHEMICALS

The Chemicals segment consists of our 50 percent equity investment in CPChem, which is headquartered in The Woodlands, Texas. At the end of 2015, CPChem owned or had joint-venture interests in 34 manufacturing facilities and two research and development centers located around the world.

We structure our reporting of CPChem’s operations around two primary business segments: Olefins and Polyolefins (O&P) and Specialties, Aromatics and Styrenics (SA&S). The O&P business segment produces and markets ethylene and other olefin products; the ethylene produced is primarily consumed within CPChem for the production of polyethylene, normal alpha olefins and polyethylene pipe. The SA&S business segment manufactures and markets aromatics and styrenics products, such as benzene, styrene, paraxylene and cyclohexane, as well as polystyrene and styrene-butadiene copolymers. SA&S also manufactures and/or markets a variety of specialty chemical products including organosulfur chemicals, solvents, catalysts, drilling chemicals and mining chemicals.


9


The manufacturing of petrochemicals and plastics involves the conversion of hydrocarbon-based raw material feedstocks into higher-value products, often through a thermal process referred to in the industry as “cracking.” For example, ethylene can be produced from cracking the feedstocks ethane, propane, butane, natural gasoline or certain refinery liquids, such as naphtha and gas oil. The produced ethylene has a number of uses, primarily as a raw material for the production of plastics, such as polyethylene and polyvinyl chloride. Plastic resins, such as polyethylene, are manufactured in a thermal/catalyst process, and the produced output is used as a further raw material for various applications, such as packaging and plastic pipe.

CPChem, including through its subsidiaries and equity affiliates, has manufacturing facilities located in Belgium, China, Colombia, Qatar, Saudi Arabia, Singapore, South Korea and the United States.

The following table reflects CPChem’s petrochemicals and plastics product capacities at December 31, 2015:
 
 
Millions of Pounds per Year
 
 
U.S.

 
Worldwide

O&P
 
 
 
Ethylene
8,030

 
10,505

Propylene
2,675

 
3,180

High-density polyethylene
4,205

 
6,500

Low-density polyethylene
620

 
620

Linear low-density polyethylene
490

 
490

Polypropylene

 
310

Normal alpha olefins
2,335

 
2,850

Polyalphaolefins
105

 
235

Polyethylene pipe
590

 
590

Total O&P
19,050

 
25,280

 
 
 
 
SA&S
 
 
 
Benzene
1,600

 
2,530

Cyclohexane
1,060

 
1,455

Paraxylene
1,000

 
1,000

Styrene
1,050

 
1,875

Polystyrene
835

 
1,070

K-Resin® SBC

 
70

Specialty chemicals
430

 
550

Nylon 6,6

 
55

Nylon compounding

 
20

Polymer conversion

 
130

Total SA&S
5,975

 
8,755

Total O&P and SA&S
25,025

 
34,035

Capacities include CPChem’s share in equity affiliates and excludes CPChem’s NGL fractionation capacity.


In 2015, CPChem continued construction of a world-scale ethane cracker and polyethylene facilities in the U.S. Gulf Coast region. The project will leverage the development of the significant shale resources in the United States. CPChem’s Cedar Bayou facility, in Baytown, Texas, will be the location of the 3.3 billion-pound-per-year ethylene unit. The polyethylene facility will have two polyethylene units, each with an annual capacity of 1.1 billion pounds, and will be located near CPChem’s Sweeny facility in Old Ocean, Texas. The project is expected to be completed in 2017.

In the second quarter of 2015, CPChem completed construction and started commercial operations of a 220-million-pounds-per-year expansion of normal alpha olefin (NAO) production capacity at its Cedar Bayou plant. NAO and its derivatives are used extensively as polyethylene co-monomers, synthetic motor oils, lubricants, automotive additives and in a wide range of specialty applications.

10


Saudi Polymers Company (SPCo), a 35-percent-owned joint venture company of CPChem, owns an integrated petrochemicals complex adjacent to S-Chem (two 50/50 SA&S joint ventures) at Jubail Industrial City, Saudi Arabia. SPCo produces ethylene, propylene, polyethylene, polypropylene, polystyrene and 1-hexene.

In association with the SPCo project, CPChem committed to build a nylon 6,6 manufacturing plant and a number of polymer conversion projects at Jubail Industrial City, Saudi Arabia. The projects were undertaken through CPChem’s 50-percent-owned joint venture company, Petrochemical Conversion Company Ltd. The projects started operations in stages during 2014 through 2015, with the nylon 6,6 project achieving commercial production in December 2015.




11


REFINING

Our Refining segment buys, sells, and refines crude oil and other feedstocks into petroleum products (such as gasolines, distillates and aviation fuels) at 14 refineries, mainly in the United States and Europe.

The table below depicts information for each of our U.S. and international refineries at December 31, 2015:

 
 
 
 
 
 
Thousands of Barrels Daily
 
 
Region/Refinery
 
Location
 
Interest

 
Net Crude Throughput
Capacity
 
Net Clean Product
Capacity**
 
Clean
Product
Yield
Capability

At
December 31
2015

Effective January 1
2016

 
Gasolines

 
Distillates

 
Atlantic Basin/Europe
 
 
 
 
 
 
 
 
 
 
 
 
 
Bayway
 
Linden, NJ
 
100.00
%
 
238

238

 
145

 
115

 
92
%
Humber
 
N. Lincolnshire, United Kingdom
 
100.00

 
221

221

 
85

 
115

 
81

Whitegate
 
Cork, Ireland
 
100.00

 
71

71

 
15

 
30

 
65

MiRO*
 
Karlsruhe, Germany
 
18.75

 
58

58

 
25

 
25

 
86

 
 
 
 
 
 
588

588

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gulf Coast
 
 
 
 
 
 
 
 
 
 
 
 
 
Alliance
 
Belle Chasse, LA
 
100.00

 
247

247

 
125

 
120

 
88

Lake Charles
 
Westlake, LA
 
100.00

 
244

249

 
90

 
115

 
70

Sweeny
 
Old Ocean, TX
 
100.00

 
247

247

 
125

 
120

 
87

 
 
 
 
 
 
738

743

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Central Corridor
 
 
 
 
 
 
 
 
 
 
 
 
 
Wood River
 
Roxana, IL
 
50.00

 
157

157

 
75

 
55

 
81

Borger
 
Borger, TX
 
50.00

 
73

73

 
50

 
25

 
90

Ponca City
 
Ponca City, OK
 
100.00

 
203

203

 
110

 
90

 
93

Billings
 
Billings, MT
 
100.00

 
59

60

 
35

 
25

 
90

 
 
 
 
 
 
492

493

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Western/Pacific
 
 
 
 
 
 
 
 
 
 
 
 
 
Ferndale
 
Ferndale, WA
 
100.00

 
101

101

 
55

 
30

 
81

Los Angeles
 
Carson/ Wilmington, CA
 
100.00

 
139

139

 
80

 
65

 
90

San Francisco
 
Arroyo Grande/San Francisco, CA
 
100.00

 
120

120

 
55

 
60

 
84

 
 
 
 
 
 
360

360

 
 
 
 
 
 
 
 
 
 
 
 
2,178

2,184

 
 
 
 
 
 
*Mineraloelraffinerie Oberrhein GmbH.
**Clean product capacities are maximum rates for each clean product category, independent of each other. They are not additive when calculating the clean product yield capability for each refinery.


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Primary crude oil characteristics and sources of crude oil for our refineries are as follows:
 
 
Characteristics
 
Sources
 
Sweet
Medium
Sour
Heavy
Sour
High
TAN* 
 
United
States
Canada
South
America
Europe
Middle East
& Africa
Bayway
l
l
 
 
 
 l
l
 
 
l
Humber
l
l
 
l
 
 
 
 
l
l
Whitegate
l
 
 
 
 
 
 
 
l
l
MiRO
l
l
 
 
 
 
 
 
l
l
Alliance
l
 
 
 
 
l
 
 
 
 
Lake Charles
l
l
l
l
 
l
l
l
 
l
Sweeny
l
l
l
l
 
l
l
l
 
l
Wood River
l
 
l
l
 
l
l
 
 
 
Borger
 
l
l
 
 
l
l
 
 
 
Ponca City
l
l
l
 
 
l
l
 
 
 
Billings
 
l
l
l
 
 
l
 
 
 
Ferndale
l
l
 
 
 
l
l
 
 
 
Los Angeles
 
l
l
l
 
l
l
l
 
l
San Francisco
l
l
l
l
 
l
 
l
 
l
*High TAN (Total Acid Number): acid content greater than or equal to 1.0 milligram of potassium hydroxide (KOH) per gram.


Atlantic Basin/Europe Region

Bayway Refinery
The Bayway Refinery is located on the New York Harbor in Linden, New Jersey. Bayway refining units include a fluid catalytic cracking unit, two hydrodesulfurization units, a naphtha reformer, an alkylation unit and other processing equipment. The refinery produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels, as well as petrochemical feedstocks, residual fuel oil and home heating oil. Refined products are distributed to East Coast customers by pipeline, barge, railcar and truck. The complex also includes a 775-million-pound-per-year polypropylene plant.

Humber Refinery
The Humber Refinery is located on the east coast of England in North Lincolnshire, United Kingdom. It produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels. Humber’s facilities encompass fluid catalytic cracking, thermal cracking and coking. The refinery has two coking units with associated calcining plants, which upgrade the heaviest part of the crude barrel and imported feedstocks into light oil products and high-value graphite and anode petroleum cokes. Humber is the only coking refinery in the United Kingdom, and a major producer of specialty graphite cokes and anode coke. Approximately 70 percent of the light oils produced in the refinery are marketed in the United Kingdom, while the other products are exported to the rest of Europe, West Africa and the United States.

Whitegate Refinery
The Whitegate Refinery is located in Cork, Ireland, and is Ireland’s only refinery. The refinery primarily produces transportation fuels, such as gasoline, diesel and fuel oil, which are distributed to the inland market, as well as being exported to international markets. In the first quarter of 2015 we sold the Bantry Bay terminal, a crude oil and products storage complex located in Bantry Bay, about 80 miles southwest of the refinery in southern Cork County.

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MiRO Refinery
The Mineraloelraffinerie Oberrhein GmbH (MiRO) Refinery, located on the Rhine River in Karlsruhe in southwest Germany, is a joint venture in which we own an 18.75 percent interest. Facilities include three crude unit trains, fluid catalytic cracking, petroleum coking and calcining, hydrodesulfurization, naphtha reformer, isomerization, ethyl tert-butyl ether and alkylation units. MiRO produces a high percentage of transportation fuels, such as gasoline and diesel fuels. Other products include petrochemical feedstocks, home heating oil, bitumen, and anode- and fuel-grade petroleum coke. Refined products are delivered to customers in Germany, Switzerland and Austria by truck, railcar and barge.

Gulf Coast Region

Alliance Refinery
The Alliance Refinery is located on the Mississippi River in Belle Chasse, Louisiana. The single-train facility includes fluid catalytic cracking units, alkylation, delayed coking, hydrodesulfurization units, a naphtha reformer and aromatics unit. Alliance produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels. Other products include petrochemical feedstocks, home heating oil and anode-grade petroleum coke. The majority of the refined products are distributed to customers in the southeastern and eastern United States through major common carrier pipeline systems and by barge. Refined products are also sold into export markets through the refinery’s marine terminal.

Lake Charles Refinery
The Lake Charles Refinery is located in Westlake, Louisiana. Its facilities include fluid catalytic cracking, hydrocracking, delayed coking and hydrodesulfurization units. The refinery produces a high percentage of transportation fuels, such as low-sulfur gasoline and off-road diesel, along with home heating oil. The majority of its refined products are distributed by truck, railcar, barge or major common carrier pipelines to customers in the southeastern and eastern United States. Refined products can also be sold into export markets through the refinery’s marine terminal. Refinery facilities also include a specialty coker and calciner, which produce graphite petroleum coke for the steel industry.

Sweeny Refinery
The Sweeny Refinery is located in Old Ocean, Texas, approximately 65 miles southwest of Houston. Refinery facilities include fluid catalytic cracking, delayed coking, alkylation, a naphtha reformer and hydrodesulfurization units. The refinery receives crude oil primarily via tankers, through wholly and jointly owned terminals on the Gulf Coast, including a deepwater terminal at Freeport, Texas. It produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels. Other products include petrochemical feedstocks, home heating oil and fuel-grade petroleum coke. We operate nearby terminals and storage facilities, along with pipelines that connect these facilities to the refinery. Refined products are distributed throughout the Midwest and southeastern United States by pipeline, barge and railcar.

MSLP
Merey Sweeny, L.P. (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. See the “Other” section of Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements, for information on the ownership of MSLP.

Central Corridor Region

WRB Refining LP (WRB)
We are the operator and managing partner of WRB, a 50/50 joint venture with Cenovus Energy Inc., which consists of the Wood River and Borger refineries.

WRB’s gross processing capability of heavy Canadian or similar crudes ranges between 235,000 and 255,000 barrels per day.
 
Wood River Refinery
The Wood River Refinery is located in Roxana, Illinois, about 15 miles northeast of St. Louis, Missouri, at the confluence of the Mississippi and Missouri rivers. Operations include three distilling units, two fluid catalytic cracking units, alkylation, hydrocracking, two delayed coking units, naphtha reforming, hydrotreating and sulfur recovery. The refinery produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels.

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Other products include petrochemical feedstocks, asphalt and coke. Finished product leaves Wood River by pipeline, rail, barge and truck.
 
Borger Refinery
The Borger Refinery is located in Borger, Texas, in the Texas Panhandle, approximately 50 miles north of Amarillo. The refinery facilities encompass coking, fluid catalytic cracking, alkylation, hydrodesulfurization and naphtha reforming, and a 45,000-barrel-per-day NGL fractionation facility. It produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels, as well as coke, NGL and solvents. Refined products are transported via pipelines from the refinery to West Texas, New Mexico, Colorado and the Midcontinent region.

Ponca City Refinery
The Ponca City Refinery is located in Ponca City, Oklahoma. Its facilities include fluid catalytic cracking, alkylation, delayed coking and hydrodesulfurization units. It produces a high percentage of transportation fuels, such as gasoline, diesel, and jet fuels, as well as LPG and anode-grade petroleum coke. Finished petroleum products are primarily shipped by company-owned and common-carrier pipelines to markets throughout the Midcontinent region.

Billings Refinery
The Billings Refinery is located in Billings, Montana. Its facilities include fluid catalytic cracking and hydrodesulfurization units, in addition to a delayed coker, which converts heavy, high-sulfur residue into higher-value light oils. The refinery produces a high percentage of transportation fuels, such as gasoline, diesel and aviation fuels, as well as fuel-grade petroleum coke. Finished petroleum products from the refinery are delivered by pipeline, railcar and truck. The pipelines transport most of the refined products to markets in Montana, Wyoming, Idaho, Utah, Colorado and Washington.

Western/Pacific Region

Ferndale Refinery
The Ferndale Refinery is located on Puget Sound in Ferndale, Washington, approximately 20 miles south of the U.S.-Canada border. Facilities include a fluid catalytic cracker, an alkylation unit and a diesel hydrotreater unit. The refinery produces transportation fuels such as gasoline and diesel fuels. Other products include residual fuel oil, which is supplied to the northwest marine transportation market. Most refined products are distributed by pipeline and barge to major markets in the northwest United States.

Los Angeles Refinery
The Los Angeles Refinery consists of two linked facilities located about five miles apart in Carson and Wilmington, California, approximately 15 miles southeast of Los Angeles International Airport. Carson serves as the front end of the refinery by processing crude oil, and Wilmington serves as the back end by upgrading the intermediate products to finished products. The refinery produces a high percentage of transportation fuels, such as gasoline, diesel and jet fuels. Other products include fuel-grade petroleum coke. The facilities include fluid catalytic cracking, alkylation, hydrocracking, coking, and naphtha reforming units. The refinery produces California Air Resources Board (CARB)-grade gasoline. Refined products are distributed to customers in California, Nevada and Arizona by pipeline and truck.

San Francisco Refinery
The San Francisco Refinery consists of two facilities linked by a 200-mile pipeline. The Santa Maria facility is located in Arroyo Grande, California, about 200 miles south of San Francisco, California, while the Rodeo facility is in the San Francisco Bay Area. Semi-refined liquid products from the Santa Maria facility are sent by pipeline to the Rodeo facility for upgrading into finished petroleum products. The refinery produces a high percentage of transportation fuels, such as gasoline and diesel fuels. Other products include petroleum coke. Process facilities include coking, hydrocracking, hydrotreating and naphtha reforming units. It also produces CARB-grade gasoline. The majority of the refined products are distributed by pipeline and barge to customers in California.



15


MARKETING AND SPECIALTIES

Our M&S segment purchases for resale and markets refined petroleum products (such as gasolines, 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.

Marketing

Marketing—United States
In the United States, as of December 31, 2015, we marketed gasoline, diesel and aviation fuel through approximately 8,350 marketer-owned or -supplied outlets in 48 states. These sites utilize the Phillips 66, Conoco or 76 brands.

At December 31, 2015, our wholesale operations utilized a network of marketers operating approximately 6,700 outlets. We have placed a strong emphasis on the wholesale channel of trade because of its lower capital requirements. In addition, we held brand-licensing agreements with approximately 800 sites. Our refined products are marketed on both a branded and unbranded basis. A high percentage of our branded marketing sales are made in the Midcontinent, Rockies and West Coast regions, where our wholesale marketing operations provide efficient off-take from our refineries. We continue to utilize consignment fuels agreements with several marketers whereby we own the fuel inventory and pay the marketers a fixed monthly fee.

In the Gulf Coast and East Coast regions, most sales are conducted via unbranded sales which do not require a highly integrated marketing and distribution infrastructure to secure product placement for refinery pull through. We are expanding our export capability at our U.S. coastal refineries to meet growing international demand and increase flexibility to provide product to the highest-value markets.

In addition to automotive gasoline and diesel, we produce and market jet fuel and aviation gasoline, which is used by smaller piston-engine aircraft. At December 31, 2015, aviation gasoline and jet fuel were sold through dealers and independent marketers at approximately 850 Phillips 66-branded locations in the United States.

Marketing—International
We have marketing operations in five European countries. Our European marketing strategy is to sell primarily through owned, leased or joint venture retail sites using a low-cost, high-volume approach. We use the JET brand name to market retail and wholesale products in Austria, Germany and the United Kingdom. In addition, a joint venture in which we have an equity interest markets products in Switzerland under the Coop brand name.

We also market aviation fuels, LPG, heating oils, transportation fuels, marine bunker fuels, bitumen and fuel coke specialty products to commercial customers and into the bulk or spot markets in the above countries and Ireland.

As of December 31, 2015, we had approximately 1,280 marketing outlets in our European operations, of which approximately 950 were company owned and 330 were dealer owned. In addition, through our joint venture operations in Switzerland, we have interests in 295 additional sites.

Specialties

We manufacture and sell a variety of specialty products, including petroleum coke products, waxes, solvents and polypropylene. Certain manufacturing operations are included in the Refining segment, while the marketing function for these products is included in the Specialties business.

Premium Coke & Polypropylene
We market high-quality graphite and anode-grade petroleum cokes in the United States and Europe for use in the global steel and aluminum industries. We also market polypropylene in North America under the COPYLENE brand name.

Excel Paralubes
We own a 50 percent interest in Excel Paralubes, a joint venture which owns a hydrocracked lubricant base oil manufacturing plant located adjacent to the Lake Charles Refinery. The facility produces approximately 22,000 barrels per day of high-quality, clear hydrocracked base oils.

16


Lubricants
We manufacture and sell automotive, commercial, industrial and specialty lubricants which are marketed worldwide under the Phillips 66, Conoco, 76, Kendall, Red Line and Smart Blend brands, as well as other private label brands. We also market Group II Pure Performance base oils globally as well as import and market Group III Ultra-S base oils through an agreement with South Korea’s S-Oil corporation.

Other

Power Generation
We own a cogeneration power plant located adjacent to the Sweeny Refinery. The plant generates electricity and provides process steam to the refinery, as well as merchant power into the Texas market. The plant has a net electrical output of 440 megawatts and is capable of generating up to 3.6 million pounds per hour of process steam.


TECHNOLOGY DEVELOPMENT

Our Technology organization conducts applied and fundamental research in three areas: 1) support for our current business, 2) new environmental solutions for governmental regulations and 3) future growth. Technology programs include evaluating advantaged crudes, modeling for increased clean product yield, and increasing reliability. Our sustainability group concentrates on alternative and renewable energy, carbon dioxide capture, processing improvements, and product innovation. Another ongoing initiative studies whether fuel cells can be converted to use abundant natural gas, as opposed to hydrogen, to produce electricity. Additionally, we research in the areas of solar panels and water use and quality.


COMPETITION

The Midstream segment, through our equity investment in DCP Midstream and our other operations, competes with numerous integrated petroleum companies, as well as natural gas transmission and distribution companies, to deliver components of natural gas to end users in commodity natural gas markets. DCP Midstream is one of the leading natural gas gatherers and processors in the United States based on wellhead volumes, and one of the largest U.S. producers and marketers of NGL, based on published industry sources. Principal methods of competing include economically securing the right to purchase raw natural gas for gathering systems, managing the pressure of those systems, operating efficient NGL processing plants and securing markets for the products produced.

In the Chemicals segment, CPChem is ranked among the top 10 producers of many of its major product lines, based on average 2015 production capacity, as published by industry sources. Petroleum products, petrochemicals and plastics are typically delivered into the worldwide commodity markets. Our Refining and M&S segments compete primarily in the United States and Europe. Based on the statistics published in the December 7, 2015, issue of the Oil & Gas Journal, we are one of the largest refiners of petroleum products in the United States. Elements of competition for both our Chemicals and Refining segments include product improvement, new product development, low-cost structures, and efficient manufacturing and distribution systems. In the marketing portion of the business, competitive factors include product properties and processibility, reliability of supply, customer service, price and credit terms, advertising and sales promotion, and development of customer loyalty to branded products.


GENERAL

At December 31, 2015, we held a total of 404 active patents in 30 countries worldwide, including 260 active U.S. patents. During 2015, we received 31 patents in the United States and 14 foreign patents. The overall profitability of any business segment is not dependent on any single patent, trademark, license or franchise.

Company-sponsored research and development activities charged against earnings were $65 million, $62 million and $69 million in 2015, 2014 and 2013, respectively.


17


In support of our goal to attain zero incidents, we have implemented a comprehensive Health, Safety and Environmental (HSE) management system to support our business units in achieving consistent management of HSE risks across our enterprise.  The management system is designed to ensure that personal safety, process safety, and environmental impact risks are identified and mitigation steps are taken to reduce the risk.  The management system requires periodic audits to ensure compliance with government regulations, as well as our internal requirements. Our commitment to continuous improvement is reflected in annual goal setting and performance measurement.

See the environmental information contained in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Resources and Liquidity—Contingencies” under the captions “Environmental” and “Climate Change.” It includes information on expensed and capitalized environmental costs for 2015 and those expected for 2016 and 2017.


Website Access to SEC Reports

Our Internet website address is http://www.phillips66.com. Information contained on our Internet website is not part of this report on Form 10-K.

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to these reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 are available on our website, free of charge, as soon as reasonably practicable after such reports are filed with, or furnished to, the U.S. Securities and Exchange Commission (SEC). Alternatively, you may access these reports at the SEC’s website at http://www.sec.gov.



18


Item 1A. RISK FACTORS

You should carefully consider the following risk factors in addition to the other information included in this Annual Report on Form 10-K. Each of these risk factors could adversely affect our business, operating results and financial condition, as well as affect the value of an investment in our common stock.

Our operating results and future rate of growth are exposed to the effects of changing commodity prices and refining, marketing and petrochemical margins.

Our revenues, operating results and future rate of growth are highly dependent on a number of factors, including fixed and variable expenses (including the cost of crude oil, NGLs, and other refinery and petrochemical feedstocks) and the margin we can derive from selling refined and Chemicals segment products. The prices of feedstocks and our products fluctuate substantially. These prices depend on numerous factors beyond our control, including the global supply and demand for feedstocks and our products, which are subject to, among other things:
 
Changes in the global economy and the level of foreign and domestic production of crude oil, natural gas and NGLs and refined, petrochemical and plastics products.
Availability of feedstocks and refined products and the infrastructure to transport feedstocks and refined products.
Local factors, including market conditions, the level of operations of other facilities in our markets, and the volume of products imported and exported.
Threatened or actual terrorist incidents, acts of war and other global political conditions.
Government regulations.
Weather conditions, hurricanes or other natural disasters.

The price of crude oil influences prices for refined products. We do not produce crude oil and must purchase all of the crude oil we process. Many crude oils available on the world market will not meet the quality restrictions for use in our refineries. Others are not economical to use due to excessive transportation costs or for other reasons. The prices for crude oil and refined products can fluctuate differently based on global, regional and local market conditions. In addition, the timing of the relative movement of the prices (both among different classes of refined products and among various global markets for similar refined products), as well as the overall change in refined product prices, can reduce refining margins and could have a significant impact on our refining, wholesale marketing and retail operations, revenues, operating income and cash flows. Also, crude oil supply contracts generally have market-responsive pricing provisions. We normally purchase our refinery feedstocks weeks before manufacturing and selling the refined products. During the period between the time we purchase feedstocks and sell the refined products from these feedstocks, price changes could have a significant effect on our financial results. We also purchase refined products produced by others for sale to our customers. Price changes during the periods between purchasing and selling these refined products also could have a material adverse effect on our business, financial condition and results of operations.

The price of feedstocks also influences prices for petrochemical and plastics products. Although our Chemicals segment gathers, transports, and fractionates feedstocks to meet a portion of their demand and has certain long-term feedstock supply contracts with others, it is still subject to volatile feedstock prices. In addition, the petrochemicals industry is both cyclical and volatile. Cyclicality occurs when periods of tight supply, resulting in increased prices and profit margins, are followed by periods of capacity expansion, resulting in oversupply and declining prices and profit margins. Volatility occurs as a result of changes in supply and demand for products, changes in energy prices, and changes in various other economic conditions around the world.

Uncertainty and illiquidity in credit and capital markets can impair our ability to obtain credit and financing on acceptable terms and can adversely affect the financial strength of our business partners.

Our ability to obtain credit and capital depends in large measure on the state of the credit and capital markets, which is beyond our control. Our ability to access credit and capital markets may be restricted at a time when we would like, or need, access to those markets, which could constrain our flexibility to react to changing economic and business conditions. In addition, the cost and availability of debt and equity financing may be adversely impacted by unstable or illiquid market conditions. Protracted uncertainty and illiquidity in these markets also could have an adverse impact on our lenders, commodity hedging counterparties, or our customers, preventing them from meeting their obligations to us.

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From time to time, our cash needs may exceed our internally generated cash flow, and our business could be materially and adversely affected if we are unable to obtain necessary funds from financing activities. From time to time, we may need to supplement cash generated from operations with proceeds from financing activities. Uncertainty and illiquidity in financial markets may materially impact the ability of the participating financial institutions to fund their commitments to us under our liquidity facilities. Accordingly, we may not be able to obtain the full amount of the funds available under our liquidity facilities to satisfy our cash requirements, and our failure to do so could have a material adverse effect on our operations and financial position.

Deterioration in our credit profile could increase our costs of borrowing money and limit our access to the capital markets and commercial credit, and could trigger co-venturer rights under joint venture arrangements.

Our or Phillips 66 Partners’ credit ratings could be lowered or withdrawn entirely by a rating agency if, in its judgment, the circumstances warrant. If a rating agency were to downgrade our rating below investment grade, our or Phillips 66 Partners’ borrowing costs would increase, and our funding sources could decrease. In addition, a failure by us to maintain an investment grade rating could affect our business relationships with suppliers and operating partners. For example, our agreement with Chevron regarding CPChem permits Chevron to buy our 50 percent interest in CPChem for fair market value if we experience a change in control or if both S&P and Moody’s lower our credit ratings below investment grade and the credit rating from either rating agency remains below investment grade for 365 days thereafter, with fair market value determined by agreement or by nationally recognized investment banks. As a result of these factors, a downgrade of credit ratings could have a materially adverse impact on our future operations and financial position.

We expect to continue to incur substantial capital expenditures and operating costs as a result of our compliance with existing and future environmental laws and regulations. Likewise, future environmental laws and regulations may impact or limit our current business plans and reduce demand for our products.

Our business is subject to numerous laws and regulations relating to the protection of the environment. These laws and regulations continue to increase in both number and complexity and affect our operations with respect to, among other things:
 
The discharge of pollutants into the environment.
Emissions into the atmosphere (such as nitrogen oxides, sulfur dioxide and mercury emissions, and greenhouse gas emissions as they are, or may become, regulated).
The quantity of renewable fuels that must be blended into motor fuels.
The handling, use, storage, transportation, disposal and cleanup of hazardous materials and hazardous and nonhazardous wastes.
The dismantlement, abandonment and restoration of our properties and facilities at the end of their useful lives.

We have incurred and will continue to incur substantial capital, operating and maintenance, and remediation expenditures as a result of these laws and regulations. To the extent these expenditures, as with all costs, are not ultimately reflected in the prices of our products and services, our business, financial condition, results of operations and cash flows in future periods could be materially adversely affected.

The U.S. Environmental Protection Agency (EPA) has implemented a Renewable Fuel Standard (RFS) pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007. The RFS program sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States. To provide certain flexibility in compliance options available to the industry, a Renewable Identification Number (RIN) is assigned to each gallon of renewable fuel produced in, or imported into, the United States. As a producer of petroleum-based motor fuels, we are obligated to blend renewable fuels into the products we produce at a rate that is at least commensurate to the EPA’s quota and, to the extent we do not, we must purchase RINs in the open market to satisfy our obligation under the RFS program. To the extent the EPA mandates a quantity of renewable fuel that exceeds the amount that is commercially feasible to blend into motor fuel (a situation commonly referred to as “the blend wall”), our operations could be materially adversely impacted, up to and including a reduction in produced motor fuel.


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The adoption of climate change legislation could result in increased operating costs and reduced demand for the refined products we produce.

The U.S. government, including the EPA, as well as several state and international governments, have either considered or adopted legislation or regulations in an effort to reduce greenhouse gas (GHG) emissions. 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. In addition, various groups suggest that additional laws may be needed in an effort to address climate change. We cannot predict the extent to which any such legislation will be enacted and, if so, what its provisions would be. To the extent we incur additional costs required to comply with the adoption of new laws and regulations that are not ultimately reflected in the prices of our products and services, our business, financial condition, results of operations and cash flows in future periods could be materially adversely affected. In addition, demand for the refined products we produce could be adversely affected.

Climate change may adversely affect our facilities and our ongoing operations.

The potential physical effects of climate change on our operations are highly uncertain and depend upon the unique geographic and environmental factors present. Examples of such effects include rising sea levels at our coastal facilities, changing storm patterns and intensities, and changing temperature levels. As many of our facilities are located near coastal areas, rising sea levels may disrupt our ability to operate those facilities or transport crude oil and refined petroleum products. Extended periods of such disruption could have an adverse effect on our results of operation. We could also incur substantial costs to protect or repair these facilities.

Domestic and worldwide political and economic developments could damage our operations and materially reduce our profitability and cash flows.

Actions of the U.S., state, local and international governments through tax and other legislation, executive order and commercial restrictions could reduce our operating profitability both in the United States and abroad. The U.S. government can prevent or restrict us from doing business in foreign countries. These restrictions and those of foreign governments could limit our ability to operate in, or gain access to, opportunities in various countries, as well as limit our ability to obtain the optimum slate of crude oil and other refinery feedstocks. Our foreign operations and those of our joint ventures are further subject to risks of loss of revenue, equipment and property as a result of expropriation, acts of terrorism, war, civil unrest and other political risks; unilateral or forced renegotiation, modification or nullification of existing contracts with governmental entities; and difficulties enforcing rights against a governmental agency because of the doctrine of sovereign immunity and foreign sovereignty over international operations. Our foreign operations and those of our joint ventures are also subject to fluctuations in currency exchange rates. Actions by both the United States and host governments may affect our operations significantly in the future.

Renewable fuels, alternative energy mandates and energy conservation efforts could reduce demand for refined products. Tax incentives and other subsidies can make renewable fuels and alternative energy more competitive with refined products than they otherwise might be, which may reduce refined product margins and hinder the ability of refined products to compete with renewable fuels.

Large capital projects can take many years to complete, and market conditions could deteriorate significantly between the project approval date and the project startup date, negatively impacting project returns.

To approve a large-scale capital project, the project must meet an acceptable level of return on the capital invested in the project. We base these forecasted project economics on our best estimate of future market conditions. Most large-scale projects take several years to complete. During this multi-year period, market conditions can change from those we forecast, and these changes could be significant. Accordingly, we may not be able to realize our expected returns from a large investment in a capital project, and this could negatively impact our results of operations, cash flows and our return on capital employed.

Our investments in joint ventures decrease our ability to manage risk.

We conduct some of our operations, including parts of our Midstream, Refining and M&S segments, and our entire Chemicals segment, through joint ventures in which we share control with our joint venture participants. Our joint

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venture participants may have economic, business or legal interests or goals that are inconsistent with those of the joint venture or us, or our joint venture participants may be unable to meet their economic or other obligations, and we may be required to fulfill those obligations alone. Failure by us, or an entity in which we have a joint-venture interest, to adequately manage the risks associated with any acquisitions or joint ventures could have a material adverse effect on the financial condition or results of operations of our joint ventures and, in turn, our business and operations.

Activities in our Chemicals and Midstream segments involve numerous risks that may result in accidents or otherwise affect the ability of our equity affiliates to make distributions to us.

There are a variety of hazards and operating risks inherent in the manufacturing of petrochemicals and the gathering, processing, transmission, storage, and distribution of natural gas and NGL, such as spills, leaks, explosions and mechanical problems that could cause substantial financial losses. In addition, these risks could result in significant injury, loss of human life, damage to property, environmental pollution and impairment of operations, any of which could result in substantial losses. For assets located near populated areas, including residential areas, commercial business centers, industrial sites and other public gathering areas, the level of damage resulting from these risks could be greater. Should any of these risks materialize, it could have a material adverse effect on the business and financial condition of CPChem, DCP Midstream or REX and negatively impact their ability to make future distributions to us.

Our operations present hazards and risks, which may not be fully covered by insurance, if insured. If a significant accident or event occurs for which we are not adequately insured, our operations and financial results could be adversely affected.

The scope and nature of our operations present a variety of operational hazards and risks, including explosions, fires, toxic emissions, maritime hazards and natural catastrophes, that must be managed through continual oversight and control. For example, the operation of refineries, power plants, fractionators, pipelines, terminals and vessels is inherently subject to the risks of spills, discharges or other inadvertent releases of petroleum or hazardous substances. If any of these events had previously occurred or occurs in the future in connection with any of our refineries, pipelines or refined products terminals, or in connection with any facilities that receive our wastes or by-products for treatment or disposal, other than events for which we are indemnified, we could be liable for all costs and penalties associated with their remediation under federal, state, local and international environmental laws or common law, and could be liable for property damage to third parties caused by contamination from releases and spills. These and other risks are present throughout our operations. As protection against these hazards and risks, we maintain insurance against many, but not all, potential losses or liabilities arising from such operating risks. As such, our insurance coverage may not be sufficient to fully cover us against potential losses arising from such risks. Uninsured losses and liabilities arising from operating risks could reduce the funds available to us for capital and investment spending and could have a material adverse effect on our business, financial condition, results of operations and cash flows.

We are subject to interruptions of supply and increased costs as a result of our reliance on third-party transportation of crude oil, NGL and refined products.

We often utilize the services of third parties to transport crude oil, NGL and refined products to and from our facilities. In addition to our own operational risks discussed above, we could experience interruptions of supply or increases in costs to deliver refined products to market if the ability of the pipelines or vessels to transport crude oil or refined products is disrupted because of weather events, accidents, governmental regulations or third-party actions. A prolonged disruption of the ability of a pipeline or vessel to transport crude oil, NGL or refined product to or from one or more of our refineries or other facilities could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Increased regulation of hydraulic fracturing could result in reductions or delays in U.S. production of crude oil and natural gas, which could adversely impact our results of operations.

An increasing percentage of crude oil supplied to our refineries and the crude oil and gas production of our Midstream segment’s customers is being produced from unconventional sources. These reservoirs require hydraulic fracturing completion processes to release the hydrocarbons from the rock so they can flow through casing to the surface. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into the formation to stimulate hydrocarbon production. The U.S. Environmental Protection Agency, as well as several state agencies, have commenced

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studies and/or convened hearings regarding the potential environmental impacts of hydraulic fracturing activities. At the same time, certain environmental groups have suggested that additional laws may be needed to more closely and uniformly regulate the hydraulic fracturing process, and legislation has been proposed to provide for such regulation. In addition, some communities have adopted measures to ban hydraulic fracturing in their communities. We cannot predict whether any such legislation will ever be enacted and, if so, what its provisions would be. Any additional levels of regulation and permits required with the adoption of new laws and regulations at the federal or state level could result in our having to rely on higher priced crude oil for our refineries. This could lead to delays, increased operating costs and process prohibitions that could reduce the volumes of natural gas that move through DCP Midstream’s gathering systems and could reduce supplies and increase costs of NGL feedstocks to CPChem ethylene facilities. This could materially adversely affect our results of operations and the ability of DCP Midstream and CPChem to make cash distributions to us.

DCP Midstream’s success depends on its ability to obtain new sources of natural gas and NGL. Any decrease in the volumes of natural gas DCP Midstream gathers could adversely affect its business and operating results.

DCP Midstream’s gathering and transportation pipeline systems are connected to or dependent on the level of production from natural gas wells, which will naturally decline over time. As a result, its cash flows associated with these wells will also decline over time. In order to maintain or increase throughput levels on its gathering and transportation pipeline systems and NGL pipelines and the asset utilization rates at its natural gas processing plants, DCP Midstream must continually obtain new supplies. The primary factors affecting DCP Midstream’s ability to obtain new supplies of natural gas and NGL, and to attract new customers to its assets, include the level of successful drilling activity near these assets, prices of, and the demand for, natural gas and crude oil, producers’ desire and ability to obtain necessary permits in an efficient manner, natural gas field characteristics and production performance, surface access and infrastructure issues, and its ability to compete for volumes from successful new wells. If DCP Midstream is not able to obtain new supplies of natural gas to replace the natural decline in volumes from existing wells or because of competition, throughput on its pipelines and the utilization rates of its treating and processing facilities would decline. This could have a material adverse effect on its business, results of operations, financial position and cash flows, and its ability to make cash distributions to us.

Competitors that produce their own supply of feedstocks, have more extensive retail outlets, or have greater financial resources may have a competitive advantage.

The refining and marketing industry is highly competitive with respect to both feedstock supply and refined product markets. We compete with many companies for available supplies of crude oil and other feedstocks and for outlets for our refined products. We do not produce any of our crude oil feedstocks. Some of our competitors, however, obtain a portion of their feedstocks from their own production and some have more extensive retail outlets than we have. Competitors that have their own production or extensive retail outlets (and greater brand-name recognition) are at times able to offset losses from refining operations with profits from producing or retailing operations, and may be better positioned to withstand periods of depressed refining margins or feedstock shortages.

Some of our competitors also have materially greater financial and other resources than we have. Such competitors have a greater ability to bear the economic risks inherent in all phases of our business. In addition, we compete with other industries that provide alternative means to satisfy the energy and fuel requirements of our industrial, commercial and individual customers.

We may incur losses as a result of our forward-contract activities and derivative transactions.

We currently use commodity derivative instruments, and we expect to use them in the future. If the instruments we utilize to hedge our exposure to various types of risk are not effective, we may incur losses. Derivative transactions involve the risk that counterparties may be unable to satisfy their obligations to us. A large percentage of our future production is subject to commodity price changes and our ability to fund our planned activities could be adversely affected if any of our counterparties were to default on their obligations to us under the hedging contracts or seek bankruptcy protection.  The risk of counterparty default is heightened in a poor economic environment.


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One of our subsidiaries acts as the general partner of a publicly traded master limited partnership, Phillips 66 Partners LP, which may involve a greater exposure to legal liability than our historic business operations.

One of our subsidiaries acts as the general partner of Phillips 66 Partners LP, a publicly traded master limited partnership. Our control of the general partner of Phillips 66 Partners may increase the possibility that we could be subject to claims of breach of fiduciary duties, including claims of conflicts of interest, related to Phillips 66 Partners. Any liability resulting from such claims could have a material adverse effect on our future business, financial condition, results of operations and cash flows.

A significant interruption in one or more of our facilities could adversely affect our business.

Our operations could be subject to significant interruption if one or more of our facilities were to experience a major accident, mechanical failure, or power outage, encounter work stoppages relating to organized labor issues, be damaged by severe weather or other natural or man-made disaster, such as an act of terrorism, or otherwise be forced to shut down. If any facility were to experience an interruption in operations, earnings from the facility could be materially adversely affected (to the extent not recoverable through insurance, if insured) because of lost production and repair costs. A significant interruption in one or more of our facilities could also lead to increased volatility in prices for feedstocks and refined products, and could increase instability in the financial and insurance markets, making it more difficult for us to access capital and to obtain insurance coverage that we consider adequate.

Our performance depends on the uninterrupted operation of our facilities, which are becoming increasingly dependent on our information technology systems.

Our performance depends on the efficient and uninterrupted operation of the manufacturing equipment in our production facilities. The inability to operate one or more of our facilities due to a natural disaster; power outage; labor dispute; or failure of one or more of our information technology, telecommunications, or other systems could significantly impair our ability to manufacture our products. Our manufacturing equipment is becoming increasingly dependent on our information technology systems. A disruption in our information technology systems due to a catastrophic event or security breach could interrupt or damage our operations.

Security breaches and other disruptions could compromise our information and expose us to liability, which would cause our business and reputation to suffer.

In the ordinary course of our business, we collect sensitive data, including personally identifiable information of our customers using credit cards at our branded retail outlets. Despite our security measures, our information technology and infrastructure may be vulnerable to attacks by hackers or breached due to employee error, malfeasance or other disruptions. Although we have experienced occasional, actual or attempted breaches of our cybersecurity, none of these breaches has had a material effect on our business, operations or reputation (or compromised any customer data). Any such breaches could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of customer information, disrupt the services we provide to customers, and damage our reputation, any of which could adversely affect our business.

The level of returns on pension and postretirement plan assets and the actuarial assumptions used for valuation purposes could affect our earnings and cash flows in future periods.

Assumptions used in determining projected benefit obligations and the expected return on plan assets for our pension plan and other postretirement benefit plans are evaluated by us based on a variety of independent market information and in consultation with outside actuaries. If we determine that changes are warranted in the assumptions used, such as the discount rate, expected long-term rate of return, or health care cost trend rate, our future pension and postretirement benefit expenses and funding requirements could increase. In addition, several factors could cause actual results to differ significantly from the actuarial assumptions that we use. Funding obligations are determined based on the value of assets and liabilities on a specific date as required under relevant regulations. Future pension funding requirements, and the timing of funding payments, could be affected by legislation enacted by governmental authorities.


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In connection with the Separation, ConocoPhillips has agreed to indemnify us for certain liabilities and we have agreed to indemnify ConocoPhillips for certain liabilities. If we are required to act on these indemnities to ConocoPhillips, we may need to divert cash to meet those obligations and our financial results could be negatively impacted. The ConocoPhillips indemnity may not be sufficient to insure us against the full amount of liabilities for which it has been allocated responsibility, and ConocoPhillips may not be able to satisfy its indemnification obligations in the future.

Pursuant to the Indemnification and Release Agreement and certain other agreements with ConocoPhillips entered into in connection with the Separation, ConocoPhillips agreed to indemnify us for certain liabilities, and we agreed to indemnify ConocoPhillips for certain liabilities. Indemnities that we may be required to provide ConocoPhillips are not subject to any cap, may be significant and could negatively impact our business, particularly indemnities relating to our actions that could impact the tax-free nature of the distribution of Phillips 66 stock. Third parties could also seek to hold us responsible for any of the liabilities that ConocoPhillips has agreed to retain. Further, the indemnity from ConocoPhillips may not be sufficient to protect us against the full amount of such liabilities, and ConocoPhillips may not be able to fully satisfy its indemnification obligations. Moreover, even if we ultimately succeed in recovering from ConocoPhillips any amounts for which we are held liable, we may be temporarily required to bear these losses ourselves. Each of these risks could negatively affect our business, results of operations and financial condition.

We are subject to continuing contingent liabilities of ConocoPhillips following the Separation.

Notwithstanding the Separation, there are several significant areas where the liabilities of ConocoPhillips may become our obligations. For example, under the Internal Revenue Code and the related rules and regulations, each corporation that was a member of the ConocoPhillips consolidated U.S. federal income tax reporting group during any taxable period or portion of any taxable period ending on or before the effective time of the Separation is jointly and severally liable for the U.S. federal income tax liability of the entire ConocoPhillips consolidated tax reporting group for that taxable period. In connection with the Separation, we entered into the Tax Sharing Agreement with ConocoPhillips that allocates the responsibility for prior period taxes of the ConocoPhillips consolidated tax reporting group between us and ConocoPhillips. ConocoPhillips may be unable to pay any prior period taxes for which it is responsible, and we could be required to pay the entire amount of such taxes. Other provisions of federal law establish similar liability for other matters, including laws governing tax-qualified pension plans as well as other contingent liabilities.

If the distribution in connection with the Separation, together with certain related transactions, does not qualify as a transaction that is generally tax-free for U.S. federal income tax purposes, our stockholders and ConocoPhillips could be subject to significant tax liability and, in certain circumstances, we could be required to indemnify ConocoPhillips for material taxes pursuant to indemnification obligations under the Tax Sharing Agreement.

ConocoPhillips received a private letter ruling from the Internal Revenue Service (IRS) substantially to the effect that, among other things, the distribution, together with certain related transactions, qualified as a transaction that is generally tax-free for U.S. federal income tax purposes under Sections 355 and 368(a)(1)(D) of the Code. The private letter ruling and the tax opinion that ConocoPhillips received relied on certain representations, assumptions and undertakings, including those relating to the past and future conduct of our business, and neither the private letter ruling nor the opinion would be valid if such representations, assumptions and undertakings were incorrect. Moreover, the private letter ruling does not address all the issues that are relevant to determining whether the distribution qualified for tax-free treatment. Notwithstanding the private letter ruling and the tax opinion, the IRS could determine the distribution should be treated as a taxable transaction for U.S. federal income tax purposes if it determines any of the representations, assumptions or undertakings that were included in the request for the private letter ruling are false or have been violated or if it disagrees with the conclusions in the opinion that are not covered by the IRS ruling.

If the IRS were to determine that the distribution failed to qualify for tax-free treatment, in general, ConocoPhillips would be subject to tax as if it had sold the Phillips 66 common stock in a taxable sale for its fair market value, and ConocoPhillips stockholders who received shares of Phillips 66 common stock in the distribution would be subject to tax as if they had received a taxable distribution equal to the fair market value of such shares.

Under the Tax Sharing Agreement, we would generally be required to indemnify ConocoPhillips against any tax resulting from the distribution to the extent that such tax resulted from (i) any of our representations or undertakings being incorrect or violated, or (ii) other actions or failures to act by us. Our indemnification obligations to ConocoPhillips and

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its subsidiaries, officers and directors are not limited by any maximum amount. If we are required to indemnify ConocoPhillips or such other persons under the circumstances set forth in the Tax Sharing Agreement, we may be subject to substantial liabilities.


Item 1B. UNRESOLVED STAFF COMMENTS

None.


Item 3. 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. 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 SEC regulations.

Our U.S. refineries are implementing two separate consent decrees, regarding alleged violations of the Federal Clean Air Act, with the U.S. Environmental Protection Agency (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.

New Matters
In November and December of 2015, the Bay Area Quality Management District (AQMD) issued demands to settle 17 Notices of Violation (NOVs) issued in 2013 and 2014 with respect to alleged violations of regulatory and/or permit requirements at the Rodeo refining facility. The settlement demands aggregate to approximately $180,000. We are working with the Bay Area AQMD to resolve these matters.

Matters Previously Reported
In October 2007, we received a Complaint from the EPA alleging violations of the Clean Water Act related to a 2006 oil spill at the Bayway Refinery and proposing a penalty of $156,000. We are working with the EPA and the U.S. Coast Guard to resolve this matter.

In May 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 in January 2016 an agreement was reached with LDEQ to resolve the remaining allegations.

In May 2012, the Illinois Attorney General’s office filed and notified us of a complaint with respect to operations at the Wood River Refinery alleging violations of the Illinois groundwater standards and a third-party’s hazardous waste permit. The complaint seeks as relief remediation of area groundwater; compliance with the hazardous waste permit; enhanced pipeline and tank integrity measures; additional spill reporting; and yet-to-be specified amounts for fines and penalties. We are working with the Illinois Environmental Protection Agency and Attorney General’s office to resolve these allegations.

In October 2012, July 2014 and May 2015, the Bay Area AQMD issued demands to settle 64 NOVs issued in 2010 through 2013 with respect to alleged violations of regulatory and/or permit requirements at the Rodeo Refinery. The settlement demands aggregate approximately $900,000. We are working with the Bay Area AQMD to resolve these matters.


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In July 2014, Phillips 66 received a NOV from the EPA alleging various flaring-related violations between 2009 and 2013 at the Wood River Refinery. We are working with the EPA to resolve these allegations.

In September 2014, the EPA issued an NOV alleging a violation of hazardous air pollution regulations at the Wood River Refinery during 2014. We are working with the EPA to resolve this NOV.

In January 2015, the Bay Area AQMD made a $262,000 demand to settle five NOVs issued in 2012 with respect to an incident involving the release of material from a sour water tank at the Rodeo facility in June 2012. We are working with the Bay Area AQMD to resolve this matter.


Item 4. MINE SAFETY DISCLOSURES

Not applicable.

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EXECUTIVE OFFICERS OF THE REGISTRANT
 
Name
Position Held
Age*

 
 
 
Greg C. Garland
Chairman and Chief Executive Officer
58

Tim G. Taylor
President
62

Robert A. Herman
Executive Vice President, Midstream
56

Paula A. Johnson
Executive Vice President, Legal, General Counsel and Corporate Secretary
52

Kevin J. Mitchell
Executive Vice President, Finance and Chief Financial Officer
49

Lawrence M. Ziemba
Executive Vice President, Refining
60

Chukwuemeka A. Oyolu
Vice President and Controller
46

*On February 12, 2016.
 
 


There are no family relationships among any of the officers named above. The Board of Directors annually elects the officers to serve until a successor is elected and qualified or as otherwise provided in our By-Laws. Set forth below is information about the executive officers identified above.

Greg C. Garland is the Chairman and Chief Executive Officer of Phillips 66, after serving as Phillips 66’s Chairman, President and Chief Executive Officer from April 2012 to June 2014. Mr. Garland previously served as ConocoPhillips’ Senior Vice President, Exploration and Production—Americas from October 2010 to April 2012, and as President and Chief Executive Officer of CPChem from 2008 to 2010.

Tim G. Taylor is the President of Phillips 66, after serving as Executive Vice President, Commercial, Marketing, Transportation and Business Development from April 2012 to June 2014. Mr. Taylor retired as Chief Operating Officer of CPChem in 2011. Prior to this, Mr. Taylor served at CPChem as Executive Vice President, Olefins and Polyolefins from 2008 to 2011.

Robert A. Herman is Executive Vice President, Midstream for Phillips 66, a position he has held since June 2014. Previously, Mr. Herman served Phillips 66 as Senior Vice President, HSE, Projects and Procurement from February 2014 to June 2014, and Senior Vice President, Health, Safety, and Environment from April 2012 to February 2014. Mr. Herman was Vice President, Health, Safety, and Environment for ConocoPhillips, from 2010 to 2012.

Paula A. Johnson is Executive Vice President, Legal, General Counsel and Corporate Secretary of Phillips 66, a position she has held since May 2013. Previously, Ms. Johnson served as Senior Vice President, Legal, General Counsel and Corporate Secretary of Phillips 66 since April 2012. Ms. Johnson served as Deputy General Counsel of ConocoPhillips from 2009 to 2012.

Kevin J. Mitchell is Executive Vice President, Finance and Chief Financial Officer of Phillips 66, a position he has held since January 2016. Previously, Mr. Mitchell served as Phillips 66’s Vice President, Investor Relations since joining the company in September 2014. Prior to joining the company, he served as the General Auditor of ConocoPhillips from May 2010 until September 2014.

Lawrence M. Ziemba is Executive Vice President, Refining of Phillips 66, a position he has held since February 2014. Prior to this, Mr. Ziemba served Phillips 66 as Executive Vice President, Refining, Projects and Procurement since April 2012. Mr. Ziemba served as President, Global Refining, at ConocoPhillips from 2010 to 2012.

Chukwuemeka A. Oyolu is Vice President and Controller of Phillips 66, a position he has held since December 2014. Mr. Oyolu was Phillips 66’s General Manager, Finance for Refining, Marketing and Transportation from May 2012 until February 2014 when he became General Manager, Planning and Optimization. Prior to this, Mr. Oyolu worked for ConocoPhillips as Manager, Downstream Finance, from 2009 until April 2012.

28


PART II

Item 5.
MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Quarterly Common Stock Prices and Cash Dividends Per Share

Phillips 66’s common stock is traded on the New York Stock Exchange (NYSE) under the symbol “PSX.” The following table reflects intraday high and low sales prices of, and dividends declared on, our common stock for each quarter presented:

 
Stock Price
 
 
 
High
 
Low

 
Dividends

2015
 
 
 
 
First Quarter
$
80.59
 
57.33

 
.50

Second Quarter
82.19
 
76.43

 
.56

Third Quarter
84.85
 
69.79

 
.56

Fourth Quarter
94.12
 
76.45

 
.56

 
 
 
 
 
2014
 
 
 
 
First Quarter
$
80.39
 
68.78

 
.39

Second Quarter
87.05
 
76.18

 
.50

Third Quarter
87.98
 
78.53

 
.50

Fourth Quarter
82.00
 
64.02

 
.50


Closing Stock Price at December 31, 2015
 
 
 
$
81.80

Closing Stock Price at January 29, 2016
 
 
 
$
80.15

Number of Stockholders of Record at January 29, 2016
 
 
 
42,950



Performance Graph



29


In the 2014 annual report, the performance graph included a peer index (the “Old Peer Group”) composed of Dow, Marathon Petroleum, Tesoro and Valero. To better reflect our unique portfolio of assets, we revised our peer index for 2015 (the “New Peer Group”) to include an expanded representative population of companies with assets and operations in all four of our major businesses; Midstream, Chemicals, Refining, and Marketing and Specialties. The New Peer Index is composed of Celanese, Delek, Dow, Eastman Chemical, Energy Transfer, Enterprise Products, HollyFrontier, Huntsman, Marathon Petroleum, Oneok, PBF Energy, Targa Resources, Tesoro, Valero, Western Refining, and Westlake Chemical. We anticipate using the index identified as “New Peer Index” in future annual reports.

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

 
 
 
 
 
 
 
 
October 1-31, 2015
1,556,053

 
$
80.99

 
1,556,053

 
$
2,884

November 1-30, 2015
1,314,018

 
90.96

 
1,314,018

 
2,765

December 1-31, 2015
1,861,861

 
85.63

 
1,861,861

 
2,604

Total
4,731,932

 
$
85.59

 
4,731,932

 
 
*Includes repurchase of shares of common stock from company employees in connection with the company’s broad-based employee incentive plans, when applicable.
**Our Board of Directors has authorized repurchases totaling up to $9 billion of our outstanding common stock. The current authorization was announced in July 2014, in the amount of $2 billion, and increased to $4 billion as announced in October 2015. The authorization does not have an expiration date. 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.



30


Item 6. SELECTED FINANCIAL DATA

For periods prior to the Separation, the following selected financial data consisted of the combined operations of the downstream businesses of ConocoPhillips. All financial information presented for periods after the Separation represents the consolidated results of operations, financial position and cash flows of Phillips 66. Accordingly:

The selected income statement data for the years ended December 31, 2015, 2014 and 2013, consist entirely of the consolidated results of Phillips 66. The selected income statement data for the year ended December 31, 2012, consists of the consolidated results of Phillips 66 for the eight months ended December 31, 2012, and the combined results of the downstream businesses for the four months ended April 30, 2012. The selected income statement data for the year ended December 31, 2011, consists entirely of the combined results of the downstream businesses.

The selected balance sheet data at December 31, 2015, 2014, 2013 and 2012, consist of the consolidated balances of Phillips 66, while the selected balance sheet data at December 31, 2011, consists of the combined balances of the downstream businesses.


 
Millions of Dollars Except Per Share Amounts
 
2015

 
2014

 
2013

 
2012

 
2011

 
 
 
 
 
 
 
 
 
 
Sales and other operating revenues
$
98,975

 
161,212

 
171,596

 
179,290

 
195,931

Income from continuing operations
4,280

 
4,091

 
3,682

 
4,083

 
4,737

Income from continuing operations attributable to Phillips 66
4,227

 
4,056

 
3,665

 
4,076

 
4,732

Per common share
 
 
 
 
 
 
 
 
 
Basic
7.78

 
7.15

 
5.97

 
6.47

 
7.54

Diluted
7.73

 
7.10

 
5.92

 
6.40

 
7.45

Net income
4,280

 
4,797

 
3,743

 
4,131

 
4,780

Net income attributable to Phillips 66
4,227

 
4,762

 
3,726

 
4,124

 
4,775

Per common share
 
 
 
 
 
 
 
 
 
Basic
7.78

 
8.40

 
6.07

 
6.55

 
7.61

Diluted
7.73

 
8.33

 
6.02

 
6.48

 
7.52

Total assets*
48,580

 
48,692

 
49,769

 
48,035

 
43,211

Long-term debt*
8,843

 
7,793

 
6,101

 
6,924

 
361

Cash dividends declared per common share
2.1800

 
1.8900

 
1.3275

 
0.4500

 

*Prior period amounts have been retrospectively adjusted for Accounting Standards Update No. 2015-03.


To ensure full understanding, you should read the selected financial data presented above in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and accompanying notes included elsewhere in this Annual Report on Form 10-K.



31


Item 7. 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 thereto included elsewhere in this Annual Report on Form 10-K. 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.”

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 December 31, 2015, we had total assets of $48.6 billion.

Executive Overview
We reported earnings of $4.2 billion in 2015 and generated $5.7 billion in cash from operating activities. Phillips 66 Partners LP issued $1.1 billion of debt and $384 million of its common units to the public. We used available cash primarily to fund capital expenditures and investments of $5.8 billion, pay dividends of $1.2 billion, repurchase $1.5 billion of our common stock, and repay $800 million of senior notes that came due in 2015. We ended 2015 with $3.1 billion of cash and cash equivalents and approximately $4.9 billion of total capacity under our available liquidity facilities.

Our financial performance in 2015 demonstrated the benefit of a diversified portfolio of businesses in a low commodity price environment. We continue to focus on the following strategic priorities:

Operating Excellence. Our commitment to operating excellence guides everything we do. We are committed to protecting the health and safety of everyone who has a role in our operations and the communities in which we operate. Continuous improvement in safety, environmental stewardship, reliability and cost efficiency is a fundamental requirement for our company and employees. We employ rigorous training and audit programs to drive ongoing improvement in both personal and process safety as we strive for zero incidents. Since we cannot control commodity prices, controlling operating expenses and overhead costs, within the context of our commitment to safety and environmental stewardship, is a high priority.  We actively monitor these costs using various methodologies that are reported to senior management. We are committed to protecting the environment and strive to reduce our environmental footprint throughout our operations. Optimizing utilization rates at our refineries through reliable and safe operations enables us to capture the value available in the market in terms of prices and margins. During 2015, our worldwide refining crude oil capacity utilization rate was 91 percent.

Growth. We have budgeted $3.9 billion in capital expenditures and investments in 2016, including $0.3 billion for Phillips 66 Partners. Including our share of expected capital spending by joint ventures DCP Midstream, LLC (DCP Midstream), Chevron Phillips Chemical Company LLC (CPChem) and WRB Refining LP (WRB), our total 2016 capital program is expected to be $5.3 billion. This program is designed primarily to grow our Midstream and Chemicals segments, which have planned expansions for manufacturing and logistics capacity. The need for additional new gathering and processing, pipeline, storage and distribution infrastructure–driven by domestic unconventional crude oil, natural gas liquids (NGL) and natural gas production–is creating capital investment opportunities in our Midstream business. Over the next few years, CPChem plans significant

32


reinvestment of its earnings to build additional manufacturing capacity benefiting from cost-advantaged NGL feedstocks. We continue to focus on funding the most attractive growth opportunities across our portfolio.

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.  Phillips 66 Partners provides a cost-efficient vehicle to fund Midstream growth.

Returns. We plan to improve refining returns by increasing throughput of advantaged feedstocks, disciplined capital allocation and portfolio optimization. A disciplined capital allocation process ensures that we focus investments in projects that generate competitive returns throughout the business cycle. During 2015, 93 percent of the company's U.S. crude slate was advantaged.

Distributions. We believe shareholder value is enhanced through, among other things, consistent and ongoing growth of regular dividends, supplemented by share repurchases. We increased our quarterly dividend rate by 12 percent during 2015, and have increased it 180 percent since our separation from ConocoPhillips in 2012 (the Separation). Regular dividends demonstrate the confidence our management has in our capital structure and operation’s capability to generate free cash flow throughout the business cycle. Through December 31, 2015, we have cumulatively repurchased $6.4 billion, or approximately 92.5 million shares, of our common stock. At the discretion of our Board of Directors, we plan to increase dividends annually and fund our share repurchase program while continuing to invest in the growth of our business. In October 2015, our Board of Directors increased our current share repurchase authorization by $2 billion resulting in a total authorization of $4 billion. Since July 2012, our Board of Directors has authorized repurchases of our outstanding common stock totaling up to $9 billion.

High-Performing Organization. We strive to attract, train, develop and retain individuals with the knowledge and skills to implement our business strategy and who support our values and culture. Throughout the company, we focus on getting results in the right way and believe success is both what we do and how we do it. We encourage collaboration throughout our company, while valuing differences, respecting diversity of thought, and creating a great place to work. We foster an environment of learning and development through structured programs focused on enhancing functional and technical skills where employees are engaged in our business and committed to their own, as well as the company’s, success.


33


Business Environment
The dramatic fall in commodity prices, which started during the second half of 2014, continued throughout 2015. The U.S. oil rig count declined over 60 percent and crude oil production declined well below its peak which was set during the second quarter of 2015. Additionally, the discount for U.S. benchmark West Texas Intermediate (WTI) vs. the international benchmark Brent narrowed over the course of 2015 as logistical constraints between oil producing areas and major refining centers were incrementally removed during the year. Falling commodity prices have had a variety of impacts, both favorable and unfavorable, on our downstream businesses that vary by segment.

Earnings in the Midstream segment, which includes our 50 percent equity investment in DCP Midstream, are closely linked to NGL prices, natural gas prices and crude oil prices. NGL prices weakened throughout 2015 as NGL production growth from liquids-rich shale plays outpaced domestic demand growth from the petrochemical industry while export capacity remained constrained—driving prices lower and pushing inventories higher. Natural gas prices weakened throughout 2015 as well, as natural gas production growth continued and unseasonably warm weather limited demand.
 
During 2015, our Chemicals segment, which consists of our 50 percent equity investment in CPChem, continued to benefit from feedstock cost advantages associated with manufacturing ethylene in regions of the world with significant NGL production. The chemicals and plastics industry is mainly a commodity-based industry where the margins for key products are based on supply and demand, as well as cost factors. The petrochemicals industry continues to experience lower ethylene cash costs in regions of the world where ethylene manufacturing is based upon NGL rather than crude oil-derived feedstocks. In particular, companies with North American light NGL-based crackers have benefited from lower-priced feedstocks; however, the ethylene-to-polyethylene chain margins were compressed in 2015 because of the significant decline in crude oil prices that began in 2014.

Our Refining segment is driven by several factors including refining margins, cost control, refinery throughput and product yields. Refinery margins, often referred to as crack spreads, are measured as the difference between market prices for refined petroleum products and crude oil. During 2015, the U.S. 3:2:1 crack spread (three barrels of crude oil producing two barrels of gasoline and one barrel of diesel) improved over 2014 across all quarters, largely attributable to strong gasoline crack spreads which were driven by robust demand growth both in the U.S. and globally. The diesel crack spread weakened throughout 2015, driven by growing product inventories as a result of high refinery utilization to capture robust gasoline cracks and an unseasonably warm fourth quarter. The U.S. West Coast crack spread increased year over year as a result of significant refinery planned/unplanned maintenance in the region.

European refineries benefited during 2015 as domestic and export gasoline demand expanded considerably. Northwest European crack spreads on average increased in the first three quarters of the year and declined in the fourth quarter resulting in an average increase in 2015 compared to 2014. Strong margins were driven by the strength in gasoline margins which offset subdued diesel cracks during much of the year as large volumes of imported diesel from the United States, India, Asia Pacific and Russia kept diesel margins under pressure throughout the second half of the year.

Results for our Marketing and Specialties (M&S) segment depend largely on marketing fuel margins, lubricant margins and other specialty product margins. While M&S margins are primarily based on market factors, largely determined by the relationship between supply and demand, marketing fuel margins, in particular, are primarily determined by the trend of spot prices for refined products. Generally speaking, a downward trend of spot prices has a favorable impact on marketing fuel margins, while an upward trend of spot prices has an unfavorable impact on marketing fuel margins.


34


RESULTS OF OPERATIONS

Consolidated Results

A summary of the company’s earnings follows:
 
 
Millions of Dollars
 
Year Ended December 31
 
2015

 
2014

 
2013

 
 
 
 
 
 
Midstream
$
13

 
507

 
469

Chemicals
962

 
1,137

 
986

Refining
2,555

 
1,771

 
1,747

Marketing and Specialties
1,187

 
1,034

 
894

Corporate and Other
(490
)
 
(393
)
 
(431
)
Income from continuing operations attributable to Phillips 66
4,227

 
4,056

 
3,665

Discontinued Operations

 
706

 
61

Net income attributable to Phillips 66
$
4,227

 
4,762

 
3,726



2015 vs. 2014

Our earnings from continuing operations increased $171 million, or 4 percent, in 2015, primarily resulting from:

Improved realized refining margins as a result of increased gasoline crack spreads and improved secondary product margins.
Recognition of $242 million after-tax in 2015, compared with $126 million after-tax in 2014, of the deferred gain related to the sale in 2013 of the Immingham Combined Heat and Power Plant (ICHP).
These increases were partially offset by:

Lower equity earnings from DCP Midstream, primarily as a result of goodwill and other asset impairments and lower commodity prices.
Lower ethylene margins in our Chemicals segment.

2014 vs. 2013

Our earnings from continuing operations increased $391 million, or 11 percent, in 2014, primarily resulting from:

A gain on disposition and related deferred tax adjustment associated with the sale of Malaysian Refining Company Sdn. Bdh. (MRC), together totaling $369 million after-tax.
Improved ethylene and polyethylene margins in our Chemicals segment.
Improved worldwide marketing margins.
Recognition in 2014 of $126 million, after-tax, of the previously deferred gain related to the sale in 2013 of the ICHP.
Improved secondary products margins in our Refining segment.

35


These increases were partially offset by:

A $131 million after-tax impairment related to the Whitegate Refinery in Cork, Ireland.
Lower realized gasoline and distillate margins as a result of decreased market crack spreads and lower feedstock advantage.
Lower equity earnings from DCP Midstream, reflecting the sharp drop in NGL and crude oil prices in the second half of 2014.

Discontinued operations in 2014 included the recognition of a noncash $696 million after-tax gain related to the Phillips Specialty Products Inc. (PSPI) share exchange.

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


Income Statement Analysis

2015 vs. 2014

Sales and other operating revenues decreased 39 percent in 2015, while purchased crude oil and products decreased 46 percent. The decreases were primarily due to lower average prices for petroleum products, crude oil and NGL.

Equity in earnings of affiliates decreased 36 percent in 2015, primarily resulting from decreased earnings from DCP Midstream, CPChem and WRB.

Equity in earnings of DCP Midstream decreased $676 million in 2015. The decrease was primarily due to lower NGL, crude oil and natural gas prices. In addition, DCP Midstream recorded goodwill and other asset impairments in 2015 due to the significant downturn in commodity prices since mid-2014.
Equity in earnings of CPChem decreased 19 percent, primarily due to lower ethylene margins and lower equity earnings from CPChem’s equity affiliates, partially offset by lower utility costs.
Equity in earnings of WRB decreased 13 percent, primarily driven by its lower realized refining margins, resulting from lower feedstock advantage partially offset by higher secondary product margins.
  
Impairments in 2015 were $7 million, compared with $150 million in 2014. There were no significant impairments in 2015, compared with a $131 million impairment of the Whitegate Refinery recorded in 2014. For additional information, see Note 10—Impairments, in the Notes to Consolidated Financial Statements.

Interest and debt expense increased 16 percent in 2015. The increase was mainly due to a higher average debt principal balance in 2015, partially offset by increased capitalized interest.

See Note 21—Income Taxes, in the Notes to Consolidated Financial Statements, for information regarding our provision for income taxes and effective tax rates.

2014 vs. 2013

Sales and other operating revenues decreased 6 percent in 2014, while purchased crude oil and products decreased 8 percent. The decreases were primarily due to lower average prices for crude oil and petroleum products.


36


Equity in earnings of affiliates decreased 20 percent in 2014, primarily resulting from decreased earnings from WRB and DCP Midstream, partially offset by increased equity earnings from CPChem.

Equity in earnings of WRB decreased 69 percent, mainly due to lower refining margins in the Central Corridor as a result of lower market crack spreads and a lower feedstock advantage, as well as lower interest income received from equity affiliates.
Equity in earnings of DCP Midstream decreased 36 percent, primarily due to a decrease in most commodity prices, as well as increased costs associated with planned asset growth.
Equity in earnings of CPChem increased 20 percent, primarily driven by improved ethylene and polyethylene realized margins related to increased sales prices.

Net gain on dispositions in 2014 was $295 million, compared with $55 million in 2013, primarily resulting from net gains associated with the sale of our interest in MRC in the amount of $145 million, as well as the partial recognition of the previously deferred gain related to the sale of ICHP in the amount of $126 million. In 2013, net gain on dispositions primarily resulted from a $48 million gain on the sale of our E-GasTM Technology business. For additional information, see Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements.

Selling, general and administrative expenses increased 13 percent in 2014, primarily due to additional fees under marketing consignment fuels agreements, as well as costs associated with acquisitions.

Impairments in 2014 were $150 million, compared with $29 million in 2013. In 2014, we recorded a $131 million impairment of the Whitegate Refinery. For additional information, see Note 10—Impairments, in the Notes to Consolidated Financial Statements.

Income from discontinued operations increased $645 million in 2014, compared to 2013, due to the completion of the PSPI share exchange in 2014. See Note 6—Assets Held for Sale or Sold, in the Notes to Consolidated Financial Statements, for additional information on this transaction.

See Note 21—Income Taxes, in the Notes to Consolidated Financial Statements, for information regarding our provision for income taxes and effective tax rates.


37


Segment Results

Midstream
 
 
Year Ended December 31
 
2015

 
2014

 
2013

 
Millions of Dollars
Net Income (Loss) Attributable to Phillips 66
 
 
 
 
 
Transportation
$
288

 
233

 
199

DCP Midstream
(324
)
 
135

 
210

NGL
49

 
139

 
60

Total Midstream
$
13

 
507

 
469

 
 
 
 
 
 
 
Dollars Per Unit
Weighted Average NGL Price*
 
 
 
 
 
DCP Midstream (per gallon)
$
0.45

 
0.89

 
0.90

*Based on index prices from the Mont Belvieu and Conway market hubs that are weighted by NGL component and location mix.

 
Thousands of Barrels Daily
Transportation Volumes
 
 
 
 
 
Pipelines*
3,264

 
3,206

 
3,144

Terminals
1,981

 
1,683

 
1,274

Operating Statistics
 
 
 
 
 
NGL extracted**
410


454

 
426

NGL fractionated***
112

 
109