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ý
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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¨
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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Delaware
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73-1493906
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(State or other jurisdiction of
incorporation or organization)
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(I.R.S. Employer
Identification No.)
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Large accelerated filer
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ý
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Accelerated filer
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¨
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Non-accelerated filer
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¨
(Do not check if a smaller reporting company)
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Smaller reporting company
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¨
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/d
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per day
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AmeriGas
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AmeriGas Partners, L.P.
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AOCI
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accumulated other comprehensive income (loss)
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Bbls
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barrels
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Btu
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British thermal unit, an energy measurement used by gas companies to convert the volume of gas used to its heat equivalent, and thus calculate the actual energy used
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Capacity
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capacity of a pipeline, processing plant or storage facility refers to the maximum capacity under normal operating conditions and, with respect to pipeline transportation capacity, is subject to multiple factors (including natural gas injections and withdrawals at various delivery points along the pipeline and the utilization of compression) which may reduce the throughput capacity from specified capacity levels
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Citrus
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Citrus, LLC
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CrossCountry
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CrossCountry Energy, LLC
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EPA
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Environmental Protection Agency
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ETC FEP
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ETC Fayetteville Express Pipeline, LLC
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ETC MEP
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ETC Midcontinent Express Pipeline, L.L.C.
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ETC OLP
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La Grange Acquisition, L.P., which conducts business under the assumed name of Energy Transfer Company
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ETC Tiger
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ETC Tiger Pipeline, LLC
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ETE
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Energy Transfer Equity, L.P., a publicly traded partnership and the owner of ETP LLC
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ET Interstate
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Energy Transfer Interstate Holdings, LLC
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ET Rover
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ET Rover Pipeline LLC
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ETP Credit Facility
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ETP’s $3.75 billion revolving credit facility
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ETP GP
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Energy Transfer Partners GP, L.P., the general partner of ETP
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ETP Holdco
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ETP Holdco Corporation
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ETP LLC
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Energy Transfer Partners, L.L.C., the general partner of ETP GP
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Exchange Act
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Securities Exchange Act of 1934
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FEP
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Fayetteville Express Pipeline LLC
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FERC
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Federal Energy Regulatory Commission
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FGT
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Florida Gas Transmission Company, LLC
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GAAP
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accounting principles generally accepted in the United States of America
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HPC
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RIGS Haynesville Partnership Co. and its wholly-owned subsidiary, Regency Intrastate Gas LP
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IDRs
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incentive distribution rights
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Lake Charles LNG
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Lake Charles LNG Company, LLC (previously named Trunkline LNG Company, LLC), a subsidiary of ETE
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LIBOR
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London Interbank Offered Rate
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LNG
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liquefied natural gas
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Lone Star
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Lone Star NGL LLC
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MEP
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Midcontinent Express Pipeline LLC
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MMBtu
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million British thermal units
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MTBE
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methyl tertiary butyl ether
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NGL
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natural gas liquid, such as propane, butane and natural gasoline
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NYMEX
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New York Mercantile Exchange
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OSHA
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federal Occupational Safety and Health Act
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OTC
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over-the-counter
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Panhandle
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Panhandle Eastern Pipe Line Company, LP and its subsidiaries
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PCBs
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polychlorinated biphenyls
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PennTex
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PennTex Midstream Partners, LP
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PES
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Philadelphia Energy Solutions, a refining joint venture
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PHMSA
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Pipeline Hazardous Materials Safety Administration
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Preferred Units
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ETP Series A cumulative convertible preferred units
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Regency
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Regency Energy Partners LP
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Retail Holdings
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ETP Retail Holdings, LLC, a joint venture between subsidiaries of ETC OLP and Sunoco, Inc.
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Sea Robin
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Sea Robin Pipeline Company, LLC, a subsidiary of Panhandle
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SEC
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Securities and Exchange Commission
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Southern Union
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Southern Union Company
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Sunoco Logistics
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Sunoco Logistics Partners L.P.
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Sunoco LP
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Sunoco LP (previously named Susser Petroleum Partners, LP)
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Transwestern
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Transwestern Pipeline Company, LLC
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Trunkline
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Trunkline Gas Company, LLC, a subsidiary of Panhandle
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September 30, 2016
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December 31, 2015
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||||
ASSETS
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Current assets:
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Cash and cash equivalents
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$
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377
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$
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527
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Accounts receivable, net
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2,668
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2,118
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Accounts receivable from related companies
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144
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268
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Inventories
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1,604
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1,213
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Derivative assets
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30
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40
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Other current assets
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658
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532
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Total current assets
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5,481
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4,698
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Property, plant and equipment
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55,948
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50,869
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Accumulated depreciation and depletion
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(6,866
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)
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(5,782
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49,082
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45,087
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Advances to and investments in unconsolidated affiliates
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4,648
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5,003
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Non-current derivative assets
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11
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—
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Other non-current assets, net
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581
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536
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Intangible assets, net
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3,985
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4,421
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Goodwill
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4,139
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5,428
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Total assets
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$
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67,927
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$
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65,173
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September 30, 2016
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December 31, 2015
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LIABILITIES AND EQUITY
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Current liabilities:
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Accounts payable
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$
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2,509
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$
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1,859
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Accounts payable to related companies
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19
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25
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Derivative liabilities
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259
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63
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Accrued and other current liabilities
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2,179
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2,048
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Current maturities of long-term debt
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1,216
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126
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Total current liabilities
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6,182
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4,121
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Long-term debt, less current maturities
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29,182
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28,553
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Long-term notes payable – related companies
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83
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233
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Non-current derivative liabilities
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160
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137
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Deferred income taxes
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4,438
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4,082
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Other non-current liabilities
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919
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968
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Commitments and contingencies
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Series A Preferred Units
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33
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33
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Redeemable noncontrolling interests
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15
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15
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Equity:
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General Partner
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223
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306
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Limited Partners:
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Common Unitholders
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15,665
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17,043
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Class H Unitholder
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3,478
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3,469
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Class I Unitholder
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2
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14
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Accumulated other comprehensive income (loss)
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(4
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4
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Total partners’ capital
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19,364
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20,836
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Noncontrolling interest
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7,551
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6,195
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Total equity
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26,915
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27,031
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Total liabilities and equity
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$
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67,927
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$
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65,173
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Three Months Ended
September 30, |
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Nine Months Ended
September 30, |
||||||||||||
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2016
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2015
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2016
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2015
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||||||||
REVENUES:
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Natural gas sales
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$
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1,069
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$
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960
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2,602
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2,893
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NGL sales
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1,249
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961
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3,339
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2,930
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||||
Crude sales
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1,649
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1,859
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4,572
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6,747
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||||
Gathering, transportation and other fees
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986
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1,026
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2,991
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2,999
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Refined product sales (see Note 2)
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177
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1,046
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656
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9,136
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Other (see Note 2)
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401
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749
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1,141
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3,762
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||||
Total revenues
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5,531
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6,601
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15,301
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28,467
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||||
COSTS AND EXPENSES:
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||||||||
Cost of products sold (see Note 2)
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3,931
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4,942
|
|
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10,529
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|
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22,792
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|
||||
Operating expenses (see Note 2)
|
388
|
|
|
518
|
|
|
1,110
|
|
|
1,763
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|
||||
Depreciation, depletion and amortization
|
503
|
|
|
471
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|
|
1,469
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|
|
1,451
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||||
Selling, general and administrative (see Note 2)
|
71
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|
|
94
|
|
|
226
|
|
|
389
|
|
||||
Total costs and expenses
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4,893
|
|
|
6,025
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|
|
13,334
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|
|
26,395
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|
||||
OPERATING INCOME
|
638
|
|
|
576
|
|
|
1,967
|
|
|
2,072
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|
||||
OTHER INCOME (EXPENSE):
|
|
|
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||||||||
Interest expense, net
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(345
|
)
|
|
(333
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)
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(981
|
)
|
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(979
|
)
|
||||
Equity in earnings of unconsolidated affiliates
|
65
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|
214
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|
|
260
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|
|
388
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|
||||
Impairment of investment in an unconsolidated affiliate
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(308
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)
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—
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(308
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)
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|
—
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||||
Losses on extinguishments of debt
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—
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(10
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)
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—
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(43
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)
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||||
Losses on interest rate derivatives
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(28
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)
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(64
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)
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(179
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)
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(14
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)
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||||
Other, net
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52
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32
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|
|
96
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56
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||||
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT)
|
74
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|
|
415
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|
855
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1,480
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||||
Income tax expense (benefit)
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(64
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)
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|
22
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|
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(131
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)
|
|
(20
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)
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||||
NET INCOME
|
138
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|
|
393
|
|
|
986
|
|
|
1,500
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|
||||
Less: Net income (loss) attributable to noncontrolling interest
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64
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|
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(24
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)
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|
231
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|
|
182
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|
||||
Less: Net loss attributable to predecessor
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—
|
|
|
—
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|
|
—
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|
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(34
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)
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||||
NET INCOME ATTRIBUTABLE TO PARTNERS
|
74
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|
|
417
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|
|
755
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1,352
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||||
General Partner’s interest in net income
|
220
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|
|
277
|
|
|
740
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|
|
779
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|
||||
Class H Unitholder’s interest in net income
|
93
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|
|
66
|
|
|
257
|
|
|
184
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|
||||
Class I Unitholder’s interest in net income
|
2
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|
|
15
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6
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|
80
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|
||||
Common Unitholders’ interest in net income (loss)
|
$
|
(241
|
)
|
|
$
|
59
|
|
|
$
|
(248
|
)
|
|
$
|
309
|
|
NET INCOME (LOSS) PER COMMON UNIT:
|
|
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|
|
|
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||||||||
Basic
|
$
|
(0.49
|
)
|
|
$
|
0.11
|
|
|
$
|
(0.54
|
)
|
|
$
|
0.70
|
|
Diluted
|
$
|
(0.49
|
)
|
|
$
|
0.10
|
|
|
$
|
(0.54
|
)
|
|
$
|
0.68
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Net income
|
$
|
138
|
|
|
$
|
393
|
|
|
986
|
|
|
1,500
|
|
||
Other comprehensive income, net of tax:
|
|
|
|
|
|
|
|
||||||||
Change in value of derivative instruments accounted for as cash flow hedges
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
||||
Change in value of available-for-sale securities
|
—
|
|
|
(1
|
)
|
|
5
|
|
|
(1
|
)
|
||||
Actuarial gain (loss) relating to pension and other postretirement benefit plans
|
—
|
|
|
—
|
|
|
(3
|
)
|
|
45
|
|
||||
Foreign currency translation adjustments
|
—
|
|
|
1
|
|
|
(1
|
)
|
|
(1
|
)
|
||||
Change in other comprehensive income from unconsolidated affiliates
|
2
|
|
|
—
|
|
|
(9
|
)
|
|
(2
|
)
|
||||
|
2
|
|
|
—
|
|
|
(8
|
)
|
|
42
|
|
||||
Comprehensive income
|
140
|
|
|
393
|
|
|
978
|
|
|
1,542
|
|
||||
Less: Comprehensive income (loss) attributable to noncontrolling interest
|
64
|
|
|
(24
|
)
|
|
231
|
|
|
182
|
|
||||
Less: Comprehensive loss attributable to predecessor
|
—
|
|
|
—
|
|
|
—
|
|
|
(34
|
)
|
||||
Comprehensive income attributable to partners
|
$
|
76
|
|
|
$
|
417
|
|
|
$
|
747
|
|
|
$
|
1,394
|
|
|
|
|
Limited Partners
|
|
|
|
|
|
|
||||||||||||||||||
|
General Partner
|
|
Common Units
|
|
Class H Units
|
|
Class I Units
|
|
Accumulated Other Comprehensive Income
|
|
Noncontrolling Interest
|
|
Total
|
||||||||||||||
Balance, December 31, 2015
|
$
|
306
|
|
|
$
|
17,043
|
|
|
$
|
3,469
|
|
|
$
|
14
|
|
|
$
|
4
|
|
|
$
|
6,195
|
|
|
$
|
27,031
|
|
Distributions to partners
|
(823
|
)
|
|
(1,580
|
)
|
|
(248
|
)
|
|
(18
|
)
|
|
—
|
|
|
—
|
|
|
(2,669
|
)
|
|||||||
Distributions to noncontrolling interest
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(334
|
)
|
|
(334
|
)
|
|||||||
Units issued for cash
|
—
|
|
|
794
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
794
|
|
|||||||
Subsidiary units issued
|
—
|
|
|
34
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,271
|
|
|
1,305
|
|
|||||||
Capital contributions from noncontrolling interest
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
187
|
|
|
187
|
|
|||||||
Sunoco, Inc. retail business to Sunoco LP transaction
|
—
|
|
|
(405
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(405
|
)
|
|||||||
Other comprehensive income, net of tax
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|
(8
|
)
|
|||||||
Other, net
|
—
|
|
|
27
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
28
|
|
|||||||
Net income (loss)
|
740
|
|
|
(248
|
)
|
|
257
|
|
|
6
|
|
|
—
|
|
|
231
|
|
|
986
|
|
|||||||
Balance, September 30, 2016
|
$
|
223
|
|
|
$
|
15,665
|
|
|
$
|
3,478
|
|
|
$
|
2
|
|
|
$
|
(4
|
)
|
|
$
|
7,551
|
|
|
$
|
26,915
|
|
|
Nine Months Ended
September 30, |
||||||
|
2016
|
|
2015
|
||||
OPERATING ACTIVITIES
|
|
|
|
||||
Net income
|
$
|
986
|
|
|
$
|
1,500
|
|
Reconciliation of net income to net cash provided by operating activities:
|
|
|
|
||||
Depreciation, depletion and amortization
|
1,469
|
|
|
1,451
|
|
||
Deferred income taxes
|
(154
|
)
|
|
22
|
|
||
Amortization included in interest expense
|
(16
|
)
|
|
(30
|
)
|
||
Inventory valuation adjustments
|
(143
|
)
|
|
(16
|
)
|
||
Unit-based compensation expense
|
60
|
|
|
59
|
|
||
Losses on extinguishments of debt
|
—
|
|
|
43
|
|
||
Impairment of investment in an unconsolidated affiliate
|
308
|
|
|
—
|
|
||
Distributions on unvested awards
|
(19
|
)
|
|
(12
|
)
|
||
Equity in earnings of unconsolidated affiliates
|
(260
|
)
|
|
(388
|
)
|
||
Distributions from unconsolidated affiliates
|
292
|
|
|
263
|
|
||
Other non-cash
|
(230
|
)
|
|
23
|
|
||
Net change in operating assets and liabilities, net of effects of acquisition
|
172
|
|
|
(922
|
)
|
||
Net cash provided by operating activities
|
2,465
|
|
|
1,993
|
|
||
INVESTING ACTIVITIES
|
|
|
|
||||
Proceeds from the Sunoco, Inc. retail business to Sunoco LP transaction
|
2,200
|
|
|
—
|
|
||
Proceeds from Bakken Pipeline Transaction
|
—
|
|
|
980
|
|
||
Cash proceeds from the Susser Exchange Transaction
|
—
|
|
|
967
|
|
||
Proceeds from sale of noncontrolling interest
|
—
|
|
|
64
|
|
||
Cash paid for acquisition of a noncontrolling interest
|
—
|
|
|
(129
|
)
|
||
Cash transferred to ETE in connection with the Sunoco LP Exchange
|
—
|
|
|
(114
|
)
|
||
Cash paid for all other acquisitions
|
(159
|
)
|
|
(475
|
)
|
||
Capital expenditures, excluding allowance for equity funds used during construction
|
(5,787
|
)
|
|
(6,531
|
)
|
||
Contributions in aid of construction costs
|
44
|
|
|
27
|
|
||
Contributions to unconsolidated affiliates
|
(47
|
)
|
|
(75
|
)
|
||
Distributions from unconsolidated affiliates in excess of cumulative earnings
|
112
|
|
|
119
|
|
||
Proceeds from the sale of assets
|
6
|
|
|
20
|
|
||
Change in restricted cash
|
(8
|
)
|
|
10
|
|
||
Other
|
(1
|
)
|
|
(14
|
)
|
||
Net cash used in investing activities
|
(3,640
|
)
|
|
(5,151
|
)
|
||
FINANCING ACTIVITIES
|
|
|
|
||||
Proceeds from borrowings
|
13,073
|
|
|
14,808
|
|
||
Repayments of long-term debt
|
(11,308
|
)
|
|
(11,620
|
)
|
||
Cash received from affiliate notes
|
1,606
|
|
|
—
|
|
||
Cash paid on affiliate notes
|
(1,607
|
)
|
|
—
|
|
||
Units issued for cash
|
794
|
|
|
1,030
|
|
||
Subsidiary units issued for cash
|
1,305
|
|
|
1,274
|
|
||
Predecessor units issued for cash
|
—
|
|
|
34
|
|
||
Capital contributions from noncontrolling interest
|
187
|
|
|
583
|
|
||
Distributions to partners
|
(2,669
|
)
|
|
(2,253
|
)
|
||
Predecessor distributions to partners
|
—
|
|
|
(202
|
)
|
||
Distributions to noncontrolling interest
|
(334
|
)
|
|
(247
|
)
|
||
Debt issuance costs
|
(22
|
)
|
|
(54
|
)
|
||
Net cash provided by financing activities
|
1,025
|
|
|
3,353
|
|
||
Increase in cash and cash equivalents
|
(150
|
)
|
|
195
|
|
||
Cash and cash equivalents, beginning of period
|
527
|
|
|
663
|
|
||
Cash and cash equivalents, end of period
|
$
|
377
|
|
|
$
|
858
|
|
1.
|
ORGANIZATION AND BASIS OF PRESENTATION
|
•
|
ETC OLP, a Texas limited partnership primarily engaged in midstream and intrastate transportation and storage natural gas operations. ETC OLP owns and operates, through its wholly and majority-owned subsidiaries, natural gas gathering systems, intrastate natural gas pipeline systems and gas processing plants and is engaged in the business of purchasing, gathering, transporting, processing, and marketing natural gas and NGLs in the states of Texas, Louisiana, New Mexico and West Virginia.
|
•
|
ET Interstate, a Delaware limited liability company with revenues consisting primarily of fees earned from natural gas transportation services and operational gas sales. ET Interstate is the parent company of:
|
•
|
Transwestern, a Delaware limited liability company engaged in interstate transportation of natural gas. Transwestern’s revenues consist primarily of fees earned from natural gas transportation services and operational gas sales.
|
•
|
ETC FEP, a Delaware limited liability company that directly owns a
50%
interest in FEP, which owns
100%
of the Fayetteville Express interstate natural gas pipeline.
|
•
|
ETC Tiger, a Delaware limited liability company engaged in interstate transportation of natural gas.
|
•
|
CrossCountry, a Delaware limited liability company that indirectly owns a
50%
interest in Citrus, which owns
100%
of the FGT interstate natural gas pipeline.
|
•
|
ETC MEP, a Delaware limited liability company that directly owns a
50%
interest in MEP.
|
•
|
ETC Compression, LLC, a Delaware limited liability company engaged in natural gas compression services and related equipment sales.
|
•
|
ETP Holdco, a Delaware limited liability company that indirectly owns Panhandle and Sunoco, Inc. Panhandle owns and operates assets in the regulated and unregulated natural gas industry and is primarily engaged in the transportation and storage of natural gas in the United States. Sunoco, Inc. owned and operated retail marketing assets, which were contributed to Sunoco LP in March 2016, as discussed in Note 2. Subsequent to this transaction, Sunoco Inc.’s assets primarily consist of its ownership in Retail Holdings, which owns noncontrolling interests in Sunoco LP and PES.
|
•
|
Sunoco Logistics, a publicly traded Delaware limited partnership that owns and operates a logistics business, consisting of a geographically diverse portfolio of complementary pipeline, terminalling, and acquisition and marketing assets which are used to facilitate the purchase and sale of crude oil, NGLs and refined products.
|
•
|
Effective July 1, 2015, ETE acquired
100%
of the membership interests of Sunoco GP LLC, the general partner of Sunoco LP, and all of the IDRs of Sunoco LP from ETP, and in exchange, ETE transferred to ETP
21 million
ETP common units. These operations were reported within the retail marketing segment. In connection with this transaction, the Partnership deconsolidated Sunoco LP, and its remaining investment in Sunoco LP is accounted for under the equity method. Additionally, in March 2016 and as discussed in
Note 2
, ETP contributed to Sunoco LP its remaining
68.42%
interest in Sunoco, LLC and
100%
interest in the legacy Sunoco, Inc. retail business effective January 1, 2016.
|
2.
|
ACQUISITIONS AND CONTRIBUTION TRANSACTIONS
|
|
Three Months Ended September 30, 2015
|
|
Nine Months Ended September 30, 2015
|
||||
Revenues
|
$
|
1,363
|
|
|
$
|
11,705
|
|
Cost of products sold
|
1,149
|
|
|
10,519
|
|
||
Operating expenses
|
149
|
|
|
701
|
|
||
Selling, general and administrative expenses
|
8
|
|
|
101
|
|
3.
|
CASH AND CASH EQUIVALENTS
|
|
Nine Months Ended
September 30, |
||||||
|
2016
|
|
2015
|
||||
Accounts receivable
|
$
|
(595
|
)
|
|
$
|
523
|
|
Accounts receivable from related companies
|
80
|
|
|
(467
|
)
|
||
Inventories
|
(299
|
)
|
|
(239
|
)
|
||
Other current assets
|
(135
|
)
|
|
(96
|
)
|
||
Other non-current assets, net
|
(1
|
)
|
|
116
|
|
||
Accounts payable
|
635
|
|
|
(988
|
)
|
||
Accounts payable to related companies
|
24
|
|
|
75
|
|
||
Accrued and other current liabilities
|
213
|
|
|
25
|
|
||
Other non-current liabilities
|
31
|
|
|
47
|
|
||
Derivative assets and liabilities, net
|
219
|
|
|
82
|
|
||
Net change in operating assets and liabilities, net of effects of acquisition
|
$
|
172
|
|
|
$
|
(922
|
)
|
|
Nine Months Ended
September 30, |
||||||
|
2016
|
|
2015
|
||||
NON-CASH INVESTING ACTIVITIES:
|
|
|
|
||||
Accrued capital expenditures
|
$
|
991
|
|
|
$
|
963
|
|
Sunoco LP limited partner interest received in exchange for contribution of the Sunoco, Inc. retail business to Sunoco LP
|
194
|
|
|
—
|
|
||
Net gains from subsidiary common unit issuances
|
34
|
|
|
118
|
|
||
NON-CASH FINANCING ACTIVITIES:
|
|
|
|
||||
Contribution of property, plant and equipment from noncontrolling interest
|
$
|
—
|
|
|
$
|
34
|
|
Issuance of common units in connection with the Regency Merger
|
—
|
|
|
9,250
|
|
||
Issuance of Class H Units in connection with the Bakken Pipeline Transaction
|
—
|
|
|
1,946
|
|
||
Redemption of common units in connection with the Bakken Pipeline Transaction
|
—
|
|
|
999
|
|
||
Redemption of common units in connection with the Sunoco LP Exchange
|
—
|
|
|
52
|
|
4.
|
ADVANCES TO AND INVESTMENTS IN UNCONSOLIDATED AFFILIATES
|
5.
|
INVENTORIES
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Natural gas and NGLs
|
$
|
684
|
|
|
$
|
415
|
|
Crude oil
|
590
|
|
|
424
|
|
||
Refined products
|
114
|
|
|
104
|
|
||
Other
|
216
|
|
|
270
|
|
||
Total inventories
|
$
|
1,604
|
|
|
$
|
1,213
|
|
6.
|
FAIR VALUE MEASURES
|
|
|
|
Fair Value Measurements at
September 30, 2016 |
||||||||||||
|
Fair Value Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
||||||||
Assets:
|
|
|
|
|
|
|
|
||||||||
Interest rate derivatives
|
$
|
18
|
|
|
$
|
—
|
|
|
$
|
18
|
|
|
$
|
—
|
|
Commodity derivatives:
|
|
|
|
|
|
|
|
||||||||
Natural Gas:
|
|
|
|
|
|
|
|
||||||||
Basis Swaps IFERC/NYMEX
|
5
|
|
|
5
|
|
|
—
|
|
|
—
|
|
||||
Swing Swaps IFERC
|
3
|
|
|
—
|
|
|
3
|
|
|
—
|
|
||||
Fixed Swaps/Futures
|
24
|
|
|
24
|
|
|
—
|
|
|
—
|
|
||||
Forward Physical Swaps
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
||||
Power:
|
|
|
|
|
|
|
|
||||||||
Forwards
|
6
|
|
|
—
|
|
|
6
|
|
|
—
|
|
||||
Options – Puts
|
1
|
|
|
1
|
|
|
—
|
|
|
—
|
|
||||
Natural Gas Liquids – Forwards/Swaps
|
85
|
|
|
85
|
|
|
—
|
|
|
—
|
|
||||
Refined Products – Futures
|
7
|
|
|
7
|
|
|
—
|
|
|
—
|
|
||||
Crude – Futures
|
8
|
|
|
8
|
|
|
—
|
|
|
—
|
|
||||
Total commodity derivatives
|
141
|
|
|
130
|
|
|
11
|
|
|
—
|
|
||||
Total assets
|
$
|
159
|
|
|
$
|
130
|
|
|
$
|
29
|
|
|
$
|
—
|
|
Liabilities:
|
|
|
|
|
|
|
|
||||||||
Interest rate derivatives
|
$
|
(375
|
)
|
|
$
|
—
|
|
|
$
|
(375
|
)
|
|
$
|
—
|
|
Embedded derivatives in the Preferred Units
|
(1
|
)
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
||||
Commodity derivatives:
|
|
|
|
|
|
|
|
||||||||
Natural Gas:
|
|
|
|
|
|
|
|
||||||||
Basis Swaps IFERC/NYMEX
|
(5
|
)
|
|
(5
|
)
|
|
—
|
|
|
—
|
|
||||
Swing Swaps IFERC
|
(3
|
)
|
|
—
|
|
|
(3
|
)
|
|
—
|
|
||||
Fixed Swaps/Futures
|
(36
|
)
|
|
(36
|
)
|
|
—
|
|
|
—
|
|
||||
Forward Physical Swaps
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
|
—
|
|
||||
Power:
|
|
|
|
|
|
|
|
||||||||
Forwards
|
(4
|
)
|
|
—
|
|
|
(4
|
)
|
|
—
|
|
||||
Options – Calls
|
(2
|
)
|
|
(2
|
)
|
|
—
|
|
|
—
|
|
||||
Natural Gas Liquids – Forwards/Swaps
|
(114
|
)
|
|
(114
|
)
|
|
—
|
|
|
—
|
|
||||
Refined Products – Futures
|
(16
|
)
|
|
(16
|
)
|
|
—
|
|
|
—
|
|
||||
Crude – Futures
|
(8
|
)
|
|
(8
|
)
|
|
—
|
|
|
—
|
|
||||
Total commodity derivatives
|
(189
|
)
|
|
(181
|
)
|
|
(8
|
)
|
|
—
|
|
||||
Total liabilities
|
$
|
(565
|
)
|
|
$
|
(181
|
)
|
|
$
|
(383
|
)
|
|
$
|
(1
|
)
|
|
|
|
Fair Value Measurements at
December 31, 2015 |
||||||||||||
|
Fair Value Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
||||||||
Assets:
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives:
|
|
|
|
|
|
|
|
||||||||
Natural Gas:
|
|
|
|
|
|
|
|
||||||||
Basis Swaps IFERC/NYMEX
|
$
|
16
|
|
|
$
|
16
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Swing Swaps IFERC
|
10
|
|
|
2
|
|
|
8
|
|
|
—
|
|
||||
Fixed Swaps/Futures
|
274
|
|
|
274
|
|
|
—
|
|
|
—
|
|
||||
Forward Physical Swaps
|
4
|
|
|
—
|
|
|
4
|
|
|
—
|
|
||||
Power:
|
|
|
|
|
|
|
|
|
|||||||
Forwards
|
22
|
|
|
—
|
|
|
22
|
|
|
—
|
|
||||
Futures
|
3
|
|
|
3
|
|
|
—
|
|
|
—
|
|
||||
Options – Puts
|
1
|
|
|
1
|
|
|
—
|
|
|
—
|
|
||||
Options – Calls
|
1
|
|
|
1
|
|
|
—
|
|
|
—
|
|
||||
Natural Gas Liquids – Forwards/Swaps
|
99
|
|
|
99
|
|
|
—
|
|
|
—
|
|
||||
Refined Products – Futures
|
9
|
|
|
9
|
|
|
—
|
|
|
—
|
|
||||
Crude – Futures
|
9
|
|
|
9
|
|
|
—
|
|
|
—
|
|
||||
Total commodity derivatives
|
448
|
|
|
414
|
|
|
34
|
|
|
—
|
|
||||
Total assets
|
$
|
448
|
|
|
$
|
414
|
|
|
$
|
34
|
|
|
$
|
—
|
|
Liabilities:
|
|
|
|
|
|
|
|
||||||||
Interest rate derivatives
|
$
|
(171
|
)
|
|
$
|
—
|
|
|
$
|
(171
|
)
|
|
$
|
—
|
|
Embedded derivatives in the Preferred Units
|
(5
|
)
|
|
—
|
|
|
—
|
|
|
(5
|
)
|
||||
Commodity derivatives:
|
|
|
|
|
|
|
|
||||||||
Natural Gas:
|
|
|
|
|
|
|
|
||||||||
Basis Swaps IFERC/NYMEX
|
(16
|
)
|
|
(16
|
)
|
|
—
|
|
|
—
|
|
||||
Swing Swaps IFERC
|
(12
|
)
|
|
(2
|
)
|
|
(10
|
)
|
|
—
|
|
||||
Fixed Swaps/Futures
|
(203
|
)
|
|
(203
|
)
|
|
—
|
|
|
—
|
|
||||
Power:
|
|
|
|
|
|
|
|
|
|||||||
Forwards
|
(22
|
)
|
|
—
|
|
|
(22
|
)
|
|
—
|
|
||||
Futures
|
(2
|
)
|
|
(2
|
)
|
|
—
|
|
|
—
|
|
||||
Options – Puts
|
(1
|
)
|
|
(1
|
)
|
|
—
|
|
|
—
|
|
||||
Natural Gas Liquids – Forwards/Swaps
|
(89
|
)
|
|
(89
|
)
|
|
—
|
|
|
—
|
|
||||
Crude – Futures
|
(5
|
)
|
|
(5
|
)
|
|
—
|
|
|
—
|
|
||||
Total commodity derivatives
|
(350
|
)
|
|
(318
|
)
|
|
(32
|
)
|
|
—
|
|
||||
Total liabilities
|
$
|
(526
|
)
|
|
$
|
(318
|
)
|
|
$
|
(203
|
)
|
|
$
|
(5
|
)
|
Balance, December 31, 2015
|
$
|
(5
|
)
|
Net unrealized gains included in other income (expense)
|
4
|
|
|
Balance, September 30, 2016
|
$
|
(1
|
)
|
7.
|
NET INCOME (LOSS) PER LIMITED PARTNER UNIT
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Net income
|
138
|
|
|
393
|
|
|
986
|
|
|
1,500
|
|
||||
Less: Income (loss) attributable to noncontrolling interest
|
64
|
|
|
(24
|
)
|
|
231
|
|
|
182
|
|
||||
Less: Loss attributable to predecessor
|
—
|
|
|
—
|
|
|
—
|
|
|
(34
|
)
|
||||
Net income, net of noncontrolling interest and predecessor income
|
74
|
|
|
417
|
|
|
755
|
|
|
1,352
|
|
||||
General Partner’s interest in net income
|
220
|
|
|
277
|
|
|
740
|
|
|
779
|
|
||||
Class H Unitholder’s interest in net income
|
93
|
|
|
66
|
|
|
257
|
|
|
184
|
|
||||
Class I Unitholder’s interest in net income
|
2
|
|
|
15
|
|
|
6
|
|
|
80
|
|
||||
Common Unitholders’ interest in net income (loss)
|
(241
|
)
|
|
59
|
|
|
(248
|
)
|
|
309
|
|
||||
Additional earnings allocated to General Partner
|
(3
|
)
|
|
(3
|
)
|
|
(9
|
)
|
|
(7
|
)
|
||||
Distributions on employee unit awards, net of allocation to General Partner
|
(5
|
)
|
|
(4
|
)
|
|
(15
|
)
|
|
(11
|
)
|
||||
Net income (loss) available to Common Unitholders
|
$
|
(249
|
)
|
|
$
|
52
|
|
|
$
|
(272
|
)
|
|
$
|
291
|
|
Weighted average Common Units – basic
(1)
|
507.4
|
|
|
485.0
|
|
|
499.8
|
|
|
415.1
|
|
||||
Basic net income (loss) per Common Unit
|
$
|
(0.49
|
)
|
|
$
|
0.11
|
|
|
$
|
(0.54
|
)
|
|
$
|
0.70
|
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) available to Common Unitholders
|
$
|
(249
|
)
|
|
$
|
52
|
|
|
$
|
(272
|
)
|
|
$
|
291
|
|
Income attributable to Preferred Units
|
—
|
|
|
(4
|
)
|
|
—
|
|
|
(5
|
)
|
||||
Diluted net income (loss) available to Common Unitholders
|
$
|
(249
|
)
|
|
$
|
48
|
|
|
$
|
(272
|
)
|
|
$
|
286
|
|
Weighted average Common Units – basic
(1)
|
507.4
|
|
|
485.0
|
|
|
499.8
|
|
|
415.1
|
|
||||
Dilutive effect of unvested employee unit awards
|
—
|
|
|
1.4
|
|
|
—
|
|
|
1.7
|
|
||||
Dilutive effect of Preferred Units
|
—
|
|
|
0.9
|
|
|
—
|
|
|
0.9
|
|
||||
Weighted average Common Units – diluted
(1)
|
507.4
|
|
|
487.3
|
|
|
499.8
|
|
|
417.7
|
|
||||
Diluted net income (loss) per Common Unit
|
$
|
(0.49
|
)
|
|
$
|
0.10
|
|
|
$
|
(0.54
|
)
|
|
$
|
0.68
|
|
8.
|
DEBT OBLIGATIONS
|
9.
|
EQUITY
|
|
|
Number of Units
|
|
Number of common units at December 31, 2015
|
|
505.6
|
|
Common units issued in connection with equity distribution agreements
|
|
19.5
|
|
Common units issued in connection with the distribution reinvestment plan
|
|
4.7
|
|
Number of common units at September 30, 2016
|
|
529.8
|
|
Quarter Ended
|
|
Record Date
|
|
Payment Date
|
|
Rate
|
||
December 31, 2015
|
|
February 8, 2016
|
|
February 16, 2016
|
|
$
|
1.0550
|
|
March 31, 2016
|
|
May 6, 2016
|
|
May 16, 2016
|
|
1.0550
|
|
|
June 30, 2016
|
|
August 8, 2016
|
|
August 15, 2016
|
|
1.0550
|
|
|
September 30, 2016
|
|
November 7, 2016
|
|
November 14, 2016
|
|
1.0550
|
|
|
|
Total Year
|
||
2016 (remainder)
|
|
$
|
138
|
|
2017
|
|
626
|
|
|
2018
|
|
138
|
|
|
2019
|
|
128
|
|
|
Each year beyond 2019
|
|
33
|
|
Quarter Ended
|
|
Record Date
|
|
Payment Date
|
|
Rate
|
||
December 31, 2015
|
|
February 8, 2016
|
|
February 12, 2016
|
|
$
|
0.4790
|
|
March 31, 2016
|
|
May 9, 2016
|
|
May 13, 2016
|
|
0.4890
|
|
|
June 30, 2016
|
|
August 8, 2016
|
|
August 12, 2016
|
|
0.5000
|
|
|
September 30, 2016
|
|
November 9, 2016
|
|
November 14, 2016
|
|
0.5100
|
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Available-for-sale securities
|
$
|
5
|
|
|
$
|
—
|
|
Foreign currency translation adjustment
|
(5
|
)
|
|
(4
|
)
|
||
Actuarial gain related to pensions and other postretirement benefits
|
5
|
|
|
8
|
|
||
Investments in unconsolidated affiliates, net
|
(9
|
)
|
|
—
|
|
||
Total AOCI, net of tax
|
$
|
(4
|
)
|
|
$
|
4
|
|
10.
|
REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Rental expense
(1)
|
$
|
19
|
|
|
$
|
35
|
|
|
$
|
58
|
|
|
$
|
141
|
|
Less: Sublease rental income
|
—
|
|
|
(3
|
)
|
|
—
|
|
|
(15
|
)
|
||||
Rental expense, net
|
$
|
19
|
|
|
$
|
32
|
|
|
$
|
58
|
|
|
$
|
126
|
|
(1)
|
Includes contingent rentals totaling
$9 million
and
$19 million
for the
three and nine months ended
September 30, 2015
, respectively.
|
•
|
Certain of our interstate pipelines conduct soil and groundwater remediation related to contamination from past uses of PCBs. PCB assessments are ongoing and, in some cases, our subsidiaries could potentially be held responsible for contamination caused by other parties.
|
•
|
Certain gathering and processing systems are responsible for soil and groundwater remediation related to releases of hydrocarbons.
|
•
|
Legacy sites related to Sunoco, Inc., that are subject to environmental assessments include formerly owned terminals and other logistics assets, retail sites that Sunoco, Inc. no longer operates, closed and/or sold refineries and other formerly owned sites.
|
•
|
Sunoco, Inc. is potentially subject to joint and several liability for the costs of remediation at sites at which it has been identified as a potentially responsible party (“PRP”). As of
September 30, 2016
, Sunoco, Inc. had been named as a PRP at approximately
50
identified or potentially identifiable “Superfund” sites under federal and/or comparable state law. Sunoco, Inc. is usually one of a number of companies identified as a PRP at a site. Sunoco, Inc. has reviewed the nature and extent of its involvement at each site and other relevant circumstances and, based upon Sunoco, Inc.’s purported nexus to the sites, believes that its potential liability associated with such sites will not be significant.
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Current
|
$
|
42
|
|
|
$
|
41
|
|
Non-current
|
279
|
|
|
326
|
|
||
Total environmental liabilities
|
$
|
321
|
|
|
$
|
367
|
|
11.
|
DERIVATIVE ASSETS AND LIABILITIES
|
|
September 30, 2016
|
|
December 31, 2015
|
||||||
|
Notional Volume
|
|
Maturity
|
|
Notional Volume
|
|
Maturity
|
||
Mark-to-Market Derivatives
|
|
|
|
|
|
|
|
||
(Trading)
|
|
|
|
|
|
|
|
||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
||
Fixed Swaps/Futures
|
1,262,500
|
|
|
2016-2017
|
|
(602,500
|
)
|
|
2016-2017
|
Basis Swaps IFERC/NYMEX
(1)
|
60,102,500
|
|
|
2016-2017
|
|
(31,240,000
|
)
|
|
2016-2017
|
Power (Megawatt):
|
|
|
|
|
|
|
|
||
Forwards
|
419,824
|
|
|
2016-2017
|
|
357,092
|
|
|
2016-2017
|
Futures
|
99,247
|
|
|
2016-2017
|
|
(109,791
|
)
|
|
2016
|
Options – Puts
|
(536,400
|
)
|
|
2016
|
|
260,534
|
|
|
2016
|
Options – Calls
|
1,080,400
|
|
|
2016-2017
|
|
1,300,647
|
|
|
2016
|
Crude (Bbls):
|
|
|
|
|
|
|
|
||
Futures
|
(656,000
|
)
|
|
2016-2017
|
|
(591,000
|
)
|
|
2016-2017
|
(Non-Trading)
|
|
|
|
|
|
|
|
||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
||
Basis Swaps IFERC/NYMEX
|
4,762,500
|
|
|
2016-2017
|
|
(6,522,500
|
)
|
|
2016-2017
|
Swing Swaps IFERC
|
13,072,500
|
|
|
2016-2017
|
|
71,340,000
|
|
|
2016-2017
|
Fixed Swaps/Futures
|
(35,962,500
|
)
|
|
2016-2018
|
|
(14,380,000
|
)
|
|
2016-2018
|
Forward Physical Contracts
|
(6,834,328
|
)
|
|
2016-2017
|
|
21,922,484
|
|
|
2016-2017
|
Natural Gas Liquid (Bbls) – Forwards/Swaps
|
(13,519,200
|
)
|
|
2016-2017
|
|
(8,146,800
|
)
|
|
2016-2018
|
Refined Products (Bbls) – Futures
|
(1,970,000
|
)
|
|
2016-2017
|
|
(993,000
|
)
|
|
2016-2017
|
Corn (Bushels) – Futures
|
—
|
|
|
—
|
|
1,185,000
|
|
|
2016
|
Fair Value Hedging Derivatives
|
|
|
|
|
|
|
|
||
(Non-Trading)
|
|
|
|
|
|
|
|
||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
||
Basis Swaps IFERC/NYMEX
|
(30,620,000
|
)
|
|
2016-2017
|
|
(37,555,000
|
)
|
|
2016
|
Fixed Swaps/Futures
|
(30,620,000
|
)
|
|
2016-2017
|
|
(37,555,000
|
)
|
|
2016
|
Hedged Item – Inventory
|
30,620,000
|
|
|
2016-2017
|
|
37,555,000
|
|
|
2016
|
(1)
|
Includes aggregate amounts for open positions related to Houston Ship Channel, Waha Hub, NGPL TexOk, West Louisiana Zone and Henry Hub locations.
|
Term
|
|
Type
(1)
|
|
Notional Amount Outstanding
|
||||||
September 30, 2016
|
|
December 31, 2015
|
||||||||
July 2016
(2)(4)
|
|
Forward-starting to pay a fixed rate of 3.80% and receive a floating rate
|
|
$
|
—
|
|
|
$
|
200
|
|
July 2017
(3)(4)
|
|
Forward-starting to pay a fixed rate of 3.90% and receive a floating rate
|
|
500
|
|
|
300
|
|
||
July 2018
(3)
|
|
Forward-starting to pay a fixed rate of 4.00% and receive a floating rate
|
|
200
|
|
|
200
|
|
||
December 2018
|
|
Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.53%
|
|
1,200
|
|
|
1,200
|
|
||
March 2019
|
|
Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.42%
|
|
300
|
|
|
300
|
|
||
July 2019
(3)
|
|
Forward-starting to pay a fixed rate of 3.25% and receive a floating rate
|
|
200
|
|
|
200
|
|
(1)
|
Floating rates are based on 3-month LIBOR.
|
(2)
|
Represents the effective date. These forward-starting swaps have terms of 10 and 30 years with a mandatory termination date the same as the effective date.
|
(3)
|
Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.
|
(4)
|
ETP previously had outstanding forward starting interest rate swaps, which were scheduled to expire in July 2016, with a total notional value of
$200 million
. In June 2016, ETP extended the expiration of those swaps to July 2017.
|
|
|
Fair Value of Derivative Instruments
|
||||||||||||||
|
|
Asset Derivatives
|
|
Liability Derivatives
|
||||||||||||
|
|
September 30, 2016
|
|
December 31, 2015
|
|
September 30, 2016
|
|
December 31, 2015
|
||||||||
Derivatives designated as hedging instruments:
|
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives (margin deposits)
|
|
$
|
—
|
|
|
$
|
38
|
|
|
$
|
(2
|
)
|
|
$
|
(3
|
)
|
|
|
—
|
|
|
38
|
|
|
(2
|
)
|
|
(3
|
)
|
||||
Derivatives not designated as hedging instruments:
|
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives (margin deposits)
|
|
115
|
|
|
353
|
|
|
(141
|
)
|
|
(306
|
)
|
||||
Commodity derivatives
|
|
26
|
|
|
57
|
|
|
(46
|
)
|
|
(41
|
)
|
||||
Interest rate derivatives
|
|
18
|
|
|
—
|
|
|
(375
|
)
|
|
(171
|
)
|
||||
Embedded derivatives in ETP Preferred Units
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
(5
|
)
|
||||
|
|
159
|
|
|
410
|
|
|
(563
|
)
|
|
(523
|
)
|
||||
Total derivatives
|
|
$
|
159
|
|
|
$
|
448
|
|
|
$
|
(565
|
)
|
|
$
|
(526
|
)
|
|
|
Change in Value Recognized in OCI on Derivatives
(Effective Portion)
|
||||||||||||||
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Derivatives in cash flow hedging relationships:
|
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1
|
|
Total
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1
|
|
|
Location of Gain/(Loss) Recognized in Income on Derivatives
|
|
Amount of Gain/(Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness
|
||||||||||||||
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Derivatives in fair value hedging relationships (including hedged item):
|
|
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives
|
Cost of products sold
|
|
$
|
(9
|
)
|
|
$
|
(1
|
)
|
|
$
|
8
|
|
|
$
|
7
|
|
Total
|
|
|
$
|
(9
|
)
|
|
$
|
(1
|
)
|
|
$
|
8
|
|
|
$
|
7
|
|
|
Location of Gain/(Loss) Recognized in Income on Derivatives
|
|
Amount of Gain/(Loss) Recognized in Income on Derivatives
|
||||||||||||||
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Derivatives not designated as hedging instruments:
|
|
|
|
|
|
|
|
|
|
||||||||
Commodity derivatives – Trading
|
Cost of products sold
|
|
$
|
(8
|
)
|
|
$
|
(2
|
)
|
|
$
|
(24
|
)
|
|
$
|
(10
|
)
|
Commodity derivatives – Non-trading
|
Cost of products sold
|
|
(14
|
)
|
|
48
|
|
|
(57
|
)
|
|
—
|
|
||||
Interest rate derivatives
|
Losses on interest rate derivatives
|
|
(28
|
)
|
|
(64
|
)
|
|
(179
|
)
|
|
(14
|
)
|
||||
Embedded derivatives
|
Other, net
|
|
8
|
|
|
6
|
|
|
4
|
|
|
10
|
|
||||
Total
|
|
|
$
|
(42
|
)
|
|
$
|
(12
|
)
|
|
$
|
(256
|
)
|
|
$
|
(14
|
)
|
12.
|
RELATED PARTY TRANSACTIONS
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Accounts receivable from related companies:
|
|
|
|
||||
ETE
|
$
|
31
|
|
|
$
|
110
|
|
Sunoco LP
|
26
|
|
|
3
|
|
||
PES
|
8
|
|
|
10
|
|
||
FGT
|
13
|
|
|
13
|
|
||
Lake Charles LNG
|
41
|
|
|
36
|
|
||
Trans-Pecos Pipeline, LLC
|
1
|
|
|
29
|
|
||
Comanche Trail Pipeline, LLC
|
—
|
|
|
22
|
|
||
Other
|
24
|
|
|
45
|
|
||
Total accounts receivable from related companies:
|
$
|
144
|
|
|
$
|
268
|
|
|
|
|
|
||||
Accounts payable to related companies:
|
|
|
|
||||
ETE
|
$
|
6
|
|
|
$
|
1
|
|
Sunoco LP
|
10
|
|
|
5
|
|
||
FGT
|
1
|
|
|
1
|
|
||
Lake Charles LNG
|
2
|
|
|
3
|
|
||
Other
|
—
|
|
|
15
|
|
||
Total accounts payable to related companies:
|
$
|
19
|
|
|
$
|
25
|
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Long-term notes receivable (payable) – related companies:
|
|
|
|
||||
Sunoco LP
|
$
|
49
|
|
|
$
|
(233
|
)
|
Phillips 66
|
(83
|
)
|
|
—
|
|
||
Net long-term notes receivable (payable) – related companies
|
$
|
(34
|
)
|
|
$
|
(233
|
)
|
13.
|
REPORTABLE SEGMENTS
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Revenues:
|
|
|
|
|
|
|
|
||||||||
Intrastate transportation and storage:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
$
|
583
|
|
|
$
|
477
|
|
|
$
|
1,457
|
|
|
$
|
1,504
|
|
Intersegment revenues
|
175
|
|
|
115
|
|
|
400
|
|
|
243
|
|
||||
|
758
|
|
|
592
|
|
|
1,857
|
|
|
1,747
|
|
||||
Interstate transportation and storage:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
231
|
|
|
245
|
|
|
714
|
|
|
755
|
|
||||
Intersegment revenues
|
5
|
|
|
3
|
|
|
15
|
|
|
12
|
|
||||
|
236
|
|
|
248
|
|
|
729
|
|
|
767
|
|
||||
Midstream:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
587
|
|
|
539
|
|
|
1,804
|
|
|
2,055
|
|
||||
Intersegment revenues
|
756
|
|
|
840
|
|
|
1,961
|
|
|
1,715
|
|
||||
|
1,343
|
|
|
1,379
|
|
|
3,765
|
|
|
3,770
|
|
||||
Liquids transportation and services:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
1,094
|
|
|
783
|
|
|
3,022
|
|
|
2,378
|
|
||||
Intersegment revenues
|
113
|
|
|
75
|
|
|
214
|
|
|
143
|
|
||||
|
1,207
|
|
|
858
|
|
|
3,236
|
|
|
2,521
|
|
||||
Investment in Sunoco Logistics:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
2,154
|
|
|
2,379
|
|
|
6,133
|
|
|
8,026
|
|
||||
Intersegment revenues
|
35
|
|
|
27
|
|
|
101
|
|
|
155
|
|
||||
|
2,189
|
|
|
2,406
|
|
|
6,234
|
|
|
8,181
|
|
||||
Retail marketing:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
—
|
|
|
1,362
|
|
|
—
|
|
|
11,701
|
|
||||
Intersegment revenues
|
—
|
|
|
1
|
|
|
—
|
|
|
4
|
|
||||
|
—
|
|
|
1,363
|
|
|
—
|
|
|
11,705
|
|
||||
All other:
|
|
|
|
|
|
|
|
||||||||
Revenues from external customers
|
882
|
|
|
816
|
|
|
2,171
|
|
|
2,048
|
|
||||
Intersegment revenues
|
74
|
|
|
160
|
|
|
350
|
|
|
391
|
|
||||
|
956
|
|
|
976
|
|
|
2,521
|
|
|
2,439
|
|
||||
Eliminations
|
(1,158
|
)
|
|
(1,221
|
)
|
|
(3,041
|
)
|
|
(2,663
|
)
|
||||
Total revenues
|
$
|
5,531
|
|
|
$
|
6,601
|
|
|
$
|
15,301
|
|
|
$
|
28,467
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
Segment Adjusted EBITDA:
|
|
|
|
|
|
|
|
||||||||
Intrastate transportation and storage
|
$
|
133
|
|
|
$
|
127
|
|
|
$
|
461
|
|
|
$
|
421
|
|
Interstate transportation and storage
|
278
|
|
|
286
|
|
|
848
|
|
|
872
|
|
||||
Midstream
|
314
|
|
|
315
|
|
|
875
|
|
|
977
|
|
||||
Liquids transportation and services
|
240
|
|
|
195
|
|
|
687
|
|
|
518
|
|
||||
Investment in Sunoco Logistics
|
312
|
|
|
289
|
|
|
906
|
|
|
836
|
|
||||
Retail marketing
|
83
|
|
|
195
|
|
|
208
|
|
|
464
|
|
||||
All other
|
30
|
|
|
93
|
|
|
187
|
|
|
266
|
|
||||
Total
|
1,390
|
|
|
1,500
|
|
|
4,172
|
|
|
4,354
|
|
||||
Depreciation, depletion and amortization
|
(503
|
)
|
|
(471
|
)
|
|
(1,469
|
)
|
|
(1,451
|
)
|
||||
Interest expense, net
|
(345
|
)
|
|
(333
|
)
|
|
(981
|
)
|
|
(979
|
)
|
||||
Losses on interest rate derivatives
|
(28
|
)
|
|
(64
|
)
|
|
(179
|
)
|
|
(14
|
)
|
||||
Non-cash unit-based compensation expense
|
(22
|
)
|
|
(16
|
)
|
|
(60
|
)
|
|
(59
|
)
|
||||
Unrealized gains (losses) on commodity risk management activities
|
(15
|
)
|
|
47
|
|
|
(96
|
)
|
|
(72
|
)
|
||||
Inventory valuation adjustments
|
37
|
|
|
(134
|
)
|
|
143
|
|
|
16
|
|
||||
Losses on extinguishments of debt
|
—
|
|
|
(10
|
)
|
|
—
|
|
|
(43
|
)
|
||||
Adjusted EBITDA related to unconsolidated affiliates
|
(240
|
)
|
|
(350
|
)
|
|
(711
|
)
|
|
(711
|
)
|
||||
Equity in earnings of unconsolidated affiliates
|
65
|
|
|
214
|
|
|
260
|
|
|
388
|
|
||||
Impairment of investment in an unconsolidated affiliate
|
(308
|
)
|
|
—
|
|
|
(308
|
)
|
|
—
|
|
||||
Other, net
|
43
|
|
|
32
|
|
|
84
|
|
|
51
|
|
||||
Income before income tax benefit
|
$
|
74
|
|
|
$
|
415
|
|
|
$
|
855
|
|
|
$
|
1,480
|
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
Assets:
|
|
|
|
||||
Intrastate transportation and storage
|
$
|
5,072
|
|
|
$
|
4,882
|
|
Interstate transportation and storage
|
11,379
|
|
|
11,345
|
|
||
Midstream
|
17,740
|
|
|
17,111
|
|
||
Liquids transportation and services
|
10,159
|
|
|
7,235
|
|
||
Investment in Sunoco Logistics
|
17,255
|
|
|
15,423
|
|
||
Retail marketing
|
1,568
|
|
|
3,218
|
|
||
All other
|
4,754
|
|
|
5,959
|
|
||
Total assets
|
$
|
67,927
|
|
|
$
|
65,173
|
|
•
|
Natural gas operations, including the following:
|
•
|
natural gas midstream and intrastate transportation and storage; and
|
•
|
interstate natural gas transportation and storage through ET Interstate and Panhandle. ET Interstate is the parent company of Transwestern, ETC FEP, ETC Tiger, CrossCountry, ETC MEP and ET Rover. Panhandle is the parent company of the Trunkline and Sea Robin transmission systems.
|
•
|
Liquids operations, including NGL transportation, storage and fractionation services.
|
•
|
Product and crude oil transportation, terminalling services and acquisition and marketing activities through Sunoco Logistics.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Segment Adjusted EBITDA:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Intrastate transportation and storage
|
$
|
133
|
|
|
$
|
127
|
|
|
$
|
6
|
|
|
$
|
461
|
|
|
$
|
421
|
|
|
$
|
40
|
|
Interstate transportation and storage
|
278
|
|
|
286
|
|
|
(8
|
)
|
|
848
|
|
|
872
|
|
|
(24
|
)
|
||||||
Midstream
|
314
|
|
|
315
|
|
|
(1
|
)
|
|
875
|
|
|
977
|
|
|
(102
|
)
|
||||||
Liquids transportation and services
|
240
|
|
|
195
|
|
|
45
|
|
|
687
|
|
|
518
|
|
|
169
|
|
||||||
Investment in Sunoco Logistics
|
312
|
|
|
289
|
|
|
23
|
|
|
906
|
|
|
836
|
|
|
70
|
|
||||||
Retail marketing
|
83
|
|
|
195
|
|
|
(112
|
)
|
|
208
|
|
|
464
|
|
|
(256
|
)
|
||||||
All other
|
30
|
|
|
93
|
|
|
(63
|
)
|
|
187
|
|
|
266
|
|
|
(79
|
)
|
||||||
Total
|
1,390
|
|
|
1,500
|
|
|
(110
|
)
|
|
4,172
|
|
|
4,354
|
|
|
(182
|
)
|
||||||
Depreciation, depletion and amortization
|
(503
|
)
|
|
(471
|
)
|
|
(32
|
)
|
|
(1,469
|
)
|
|
(1,451
|
)
|
|
(18
|
)
|
||||||
Interest expense, net
|
(345
|
)
|
|
(333
|
)
|
|
(12
|
)
|
|
(981
|
)
|
|
(979
|
)
|
|
(2
|
)
|
||||||
Losses on extinguishments of debt
|
—
|
|
|
(10
|
)
|
|
10
|
|
|
—
|
|
|
(43
|
)
|
|
43
|
|
||||||
Losses on interest rate derivatives
|
(28
|
)
|
|
(64
|
)
|
|
36
|
|
|
(179
|
)
|
|
(14
|
)
|
|
(165
|
)
|
||||||
Non-cash unit-based compensation expense
|
(22
|
)
|
|
(16
|
)
|
|
(6
|
)
|
|
(60
|
)
|
|
(59
|
)
|
|
(1
|
)
|
||||||
Unrealized gains (losses) on commodity risk management activities
|
(15
|
)
|
|
47
|
|
|
(62
|
)
|
|
(96
|
)
|
|
(72
|
)
|
|
(24
|
)
|
||||||
Inventory valuation adjustments
|
37
|
|
|
(134
|
)
|
|
171
|
|
|
143
|
|
|
16
|
|
|
127
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
(240
|
)
|
|
(350
|
)
|
|
110
|
|
|
(711
|
)
|
|
(711
|
)
|
|
—
|
|
||||||
Equity in earnings of unconsolidated affiliates
|
65
|
|
|
214
|
|
|
(149
|
)
|
|
260
|
|
|
388
|
|
|
(128
|
)
|
||||||
Impairment of investment in an unconsolidated affiliate
|
(308
|
)
|
|
—
|
|
|
(308
|
)
|
|
(308
|
)
|
|
—
|
|
|
(308
|
)
|
||||||
Other, net
|
43
|
|
|
32
|
|
|
11
|
|
|
84
|
|
|
51
|
|
|
33
|
|
||||||
Income before income tax (expense) benefit
|
74
|
|
|
415
|
|
|
(341
|
)
|
|
855
|
|
|
1,480
|
|
|
(625
|
)
|
||||||
Income tax (expense) benefit
|
64
|
|
|
(22
|
)
|
|
86
|
|
|
131
|
|
|
20
|
|
|
111
|
|
||||||
Net income
|
$
|
138
|
|
|
$
|
393
|
|
|
$
|
(255
|
)
|
|
$
|
986
|
|
|
$
|
1,500
|
|
|
$
|
(514
|
)
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Equity in earnings (losses) of unconsolidated affiliates:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Citrus
|
$
|
31
|
|
|
$
|
29
|
|
|
$
|
2
|
|
|
$
|
80
|
|
|
$
|
77
|
|
|
$
|
3
|
|
FEP
|
12
|
|
|
14
|
|
|
(2
|
)
|
|
38
|
|
|
41
|
|
|
(3
|
)
|
||||||
PES
|
(26
|
)
|
|
39
|
|
|
(65
|
)
|
|
(25
|
)
|
|
77
|
|
|
(102
|
)
|
||||||
MEP
|
9
|
|
|
10
|
|
|
(1
|
)
|
|
31
|
|
|
33
|
|
|
(2
|
)
|
||||||
HPC
|
8
|
|
|
9
|
|
|
(1
|
)
|
|
23
|
|
|
24
|
|
|
(1
|
)
|
||||||
AmeriGas
|
(2
|
)
|
|
(2
|
)
|
|
—
|
|
|
15
|
|
|
2
|
|
|
13
|
|
||||||
Sunoco, LLC
|
—
|
|
|
(13
|
)
|
|
13
|
|
|
—
|
|
|
(13
|
)
|
|
13
|
|
||||||
Sunoco LP
|
16
|
|
|
117
|
|
|
(101
|
)
|
|
54
|
|
|
117
|
|
|
(63
|
)
|
||||||
Other
|
17
|
|
|
11
|
|
|
6
|
|
|
44
|
|
|
30
|
|
|
14
|
|
||||||
Total equity in earnings of unconsolidated affiliates
|
$
|
65
|
|
|
$
|
214
|
|
|
$
|
(149
|
)
|
|
$
|
260
|
|
|
$
|
388
|
|
|
$
|
(128
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Adjusted EBITDA related to unconsolidated affiliates
(1)
:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Citrus
|
$
|
90
|
|
|
$
|
88
|
|
|
$
|
2
|
|
|
$
|
251
|
|
|
$
|
242
|
|
|
$
|
9
|
|
FEP
|
19
|
|
|
19
|
|
|
—
|
|
|
56
|
|
|
56
|
|
|
—
|
|
||||||
PES
|
(19
|
)
|
|
46
|
|
|
(65
|
)
|
|
2
|
|
|
102
|
|
|
(100
|
)
|
||||||
MEP
|
22
|
|
|
23
|
|
|
(1
|
)
|
|
69
|
|
|
71
|
|
|
(2
|
)
|
||||||
HPC
|
15
|
|
|
16
|
|
|
(1
|
)
|
|
45
|
|
|
46
|
|
|
(1
|
)
|
||||||
Sunoco, LLC
|
—
|
|
|
53
|
|
|
(53
|
)
|
|
—
|
|
|
53
|
|
|
(53
|
)
|
||||||
Sunoco LP
|
83
|
|
|
81
|
|
|
2
|
|
|
208
|
|
|
81
|
|
|
127
|
|
||||||
Other
|
30
|
|
|
24
|
|
|
6
|
|
|
80
|
|
|
60
|
|
|
20
|
|
||||||
Total Adjusted EBITDA related to unconsolidated affiliates
|
$
|
240
|
|
|
$
|
350
|
|
|
$
|
(110
|
)
|
|
$
|
711
|
|
|
$
|
711
|
|
|
$
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Distributions received from unconsolidated affiliates:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Citrus
|
$
|
50
|
|
|
$
|
65
|
|
|
$
|
(15
|
)
|
|
$
|
112
|
|
|
$
|
145
|
|
|
$
|
(33
|
)
|
FEP
|
17
|
|
|
19
|
|
|
(2
|
)
|
|
47
|
|
|
51
|
|
|
(4
|
)
|
||||||
AmeriGas
|
3
|
|
|
2
|
|
|
1
|
|
|
9
|
|
|
8
|
|
|
1
|
|
||||||
PES
|
—
|
|
|
15
|
|
|
(15
|
)
|
|
—
|
|
|
36
|
|
|
(36
|
)
|
||||||
MEP
|
17
|
|
|
20
|
|
|
(3
|
)
|
|
56
|
|
|
60
|
|
|
(4
|
)
|
||||||
HPC
|
13
|
|
|
14
|
|
|
(1
|
)
|
|
38
|
|
|
41
|
|
|
(3
|
)
|
||||||
Sunoco LP
|
36
|
|
|
—
|
|
|
36
|
|
|
102
|
|
|
—
|
|
|
102
|
|
||||||
Other
|
13
|
|
|
21
|
|
|
(8
|
)
|
|
40
|
|
|
41
|
|
|
(1
|
)
|
||||||
Total distributions received from unconsolidated affiliates
|
$
|
149
|
|
|
$
|
156
|
|
|
$
|
(7
|
)
|
|
$
|
404
|
|
|
$
|
382
|
|
|
$
|
22
|
|
(1)
|
These amounts represent our proportionate share of the Adjusted EBITDA of our unconsolidated affiliates and are based on our equity in earnings or losses of our unconsolidated affiliates adjusted for our proportionate share of the unconsolidated affiliates’ interest, depreciation, depletion, amortization, non-cash items and taxes.
|
•
|
Gross margin, operating expenses,
and
selling, general and administrative expenses
. These amounts represent the amounts included in our consolidated financial statements that are attributable to each segment.
|
•
|
Unrealized gains or losses on commodity risk management activities
and
inventory valuation adjustments
. These are the unrealized amounts that are included in cost of products sold to calculate gross margin. These amounts are not included in Segment Adjusted EBITDA; therefore, the unrealized losses are added back and the unrealized gains are subtracted to calculate the segment measure.
|
•
|
Non-cash compensation expense
. These amounts represent the total non-cash compensation recorded in operating expenses and selling, general and administrative expenses. This expense is not included in Segment Adjusted EBITDA and therefore is added back to calculate the segment measure.
|
•
|
Adjusted EBITDA related to unconsolidated affiliates
. These amounts represent our proportionate share of the Adjusted EBITDA of our unconsolidated affiliates. Amounts reflected are calculated consistently with our definition of Adjusted EBITDA.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Natural gas transported (MMBtu/d)
|
8,088,132
|
|
|
8,308,105
|
|
|
(219,973
|
)
|
|
8,171,539
|
|
|
8,594,960
|
|
|
(423,421
|
)
|
||||||
Revenues
|
$
|
758
|
|
|
$
|
592
|
|
|
$
|
166
|
|
|
$
|
1,857
|
|
|
$
|
1,747
|
|
|
$
|
110
|
|
Cost of products sold
|
586
|
|
|
428
|
|
|
158
|
|
|
1,332
|
|
|
1,227
|
|
|
105
|
|
||||||
Gross margin
|
172
|
|
|
164
|
|
|
8
|
|
|
525
|
|
|
520
|
|
|
5
|
|
||||||
Unrealized (gains) losses on commodity risk management activities
|
(7
|
)
|
|
(4
|
)
|
|
(3
|
)
|
|
24
|
|
|
(3
|
)
|
|
27
|
|
||||||
Operating expenses, excluding non-cash compensation expense
|
(43
|
)
|
|
(43
|
)
|
|
—
|
|
|
(117
|
)
|
|
(121
|
)
|
|
4
|
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
(5
|
)
|
|
(6
|
)
|
|
1
|
|
|
(17
|
)
|
|
(21
|
)
|
|
4
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
15
|
|
|
16
|
|
|
(1
|
)
|
|
45
|
|
|
46
|
|
|
(1
|
)
|
||||||
Other
|
1
|
|
|
—
|
|
|
1
|
|
|
1
|
|
|
—
|
|
|
1
|
|
||||||
Segment Adjusted EBITDA
|
$
|
133
|
|
|
$
|
127
|
|
|
$
|
6
|
|
|
$
|
461
|
|
|
$
|
421
|
|
|
$
|
40
|
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Transportation fees
|
$
|
122
|
|
|
$
|
123
|
|
|
$
|
(1
|
)
|
|
$
|
381
|
|
|
$
|
378
|
|
|
$
|
3
|
|
Natural gas sales and other
|
26
|
|
|
21
|
|
|
5
|
|
|
81
|
|
|
72
|
|
|
9
|
|
||||||
Retained fuel revenues
|
14
|
|
|
16
|
|
|
(2
|
)
|
|
34
|
|
|
46
|
|
|
(12
|
)
|
||||||
Storage margin, including fees
|
10
|
|
|
4
|
|
|
6
|
|
|
29
|
|
|
24
|
|
|
5
|
|
||||||
Total gross margin
|
$
|
172
|
|
|
$
|
164
|
|
|
$
|
8
|
|
|
$
|
525
|
|
|
$
|
520
|
|
|
$
|
5
|
|
•
|
a decrease of
$1 million
in transportation fees due to lower throughput volumes;
|
•
|
an increase of
$6 million
in natural gas sales (excluding changes in unrealized losses of
$1 million
) and other primarily due to higher realized gains from the buying and selling of gas along our system;
|
•
|
a decrease of
$2 million
from the sale of retained fuel primarily due to lower throughput volumes;
|
•
|
an increase of
$2 million
in storage margin (excluding net changes in unrealized amounts of
$4 million
related to fair value inventory adjustments and unrealized gains and losses on derivatives), as discussed below; and
|
•
|
a decrease of
$1 million
in general and administrative expenses due to lower insurance costs, as well as lower allocated overhead costs due to shared services cost savings.
|
•
|
an increase of
$3 million
in transportation fees despite lower throughput volumes, due to fees from renegotiated and newly initiated fixed fee contracts primarily on our Houston Pipeline system;
|
•
|
an increase of
$14 million
in natural gas sales (excluding changes in unrealized loss of
$5 million
) primarily due to higher realized gains from the buying and selling gas along our system;
|
•
|
a decrease of
$9 million
from the sale of retained fuel (excluding changes in unrealized losses of
$3 million
) primarily due to significantly lower market prices. The average spot price at the Houston Ship Channel location decreased 18% for the nine months ended September 30, 2016 compared to the same period last year;
|
•
|
an increase of
$24 million
in storage margin (excluding net changes in unrealized amounts of
$19 million
related to fair value inventory adjustments and unrealized gains and losses on derivatives), as discussed below;
|
•
|
a decrease of
$4 million
in operating expenses due to decreases in project related and office expenses; and
|
•
|
a decrease of
$4 million
in general and administrative expenses due to lower legal fees and insurance costs.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Withdrawals from storage natural gas inventory (MMBtu)
|
11,547,500
|
|
|
—
|
|
|
11,547,500
|
|
|
33,205,000
|
|
|
15,782,500
|
|
|
17,422,500
|
|
||||||
Realized margin on natural gas inventory transactions
|
$
|
(3
|
)
|
|
$
|
(4
|
)
|
|
$
|
1
|
|
|
$
|
33
|
|
|
$
|
8
|
|
|
$
|
25
|
|
Fair value inventory adjustments
|
(4
|
)
|
|
(16
|
)
|
|
12
|
|
|
52
|
|
|
7
|
|
|
45
|
|
||||||
Unrealized gains (losses) on derivatives
|
12
|
|
|
19
|
|
|
(7
|
)
|
|
(74
|
)
|
|
(10
|
)
|
|
(64
|
)
|
||||||
Margin recognized on natural gas inventory, including related derivatives
|
5
|
|
|
(1
|
)
|
|
6
|
|
|
11
|
|
|
5
|
|
|
6
|
|
||||||
Revenues from fee-based storage
|
5
|
|
|
5
|
|
|
—
|
|
|
18
|
|
|
19
|
|
|
(1
|
)
|
||||||
Total storage margin
|
$
|
10
|
|
|
$
|
4
|
|
|
$
|
6
|
|
|
$
|
29
|
|
|
$
|
24
|
|
|
$
|
5
|
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Natural gas transported (MMBtu/d)
|
5,385,679
|
|
|
5,903,285
|
|
|
(517,606
|
)
|
|
5,527,607
|
|
|
6,187,218
|
|
|
(659,611
|
)
|
||||||
Natural gas sold (MMBtu/d)
|
19,478
|
|
|
19,171
|
|
|
307
|
|
|
19,398
|
|
|
16,894
|
|
|
2,504
|
|
||||||
Revenues
|
$
|
236
|
|
|
$
|
248
|
|
|
$
|
(12
|
)
|
|
$
|
729
|
|
|
$
|
767
|
|
|
$
|
(38
|
)
|
Operating expenses, excluding non-cash compensation, amortization and accretion expenses
|
(76
|
)
|
|
(78
|
)
|
|
2
|
|
|
(223
|
)
|
|
(221
|
)
|
|
(2
|
)
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses
|
(13
|
)
|
|
(14
|
)
|
|
1
|
|
|
(36
|
)
|
|
(43
|
)
|
|
7
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
131
|
|
|
130
|
|
|
1
|
|
|
376
|
|
|
369
|
|
|
7
|
|
||||||
Other
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
||||||
Segment Adjusted EBITDA
|
$
|
278
|
|
|
$
|
286
|
|
|
$
|
(8
|
)
|
|
$
|
848
|
|
|
$
|
872
|
|
|
$
|
(24
|
)
|
•
|
a decrease of
$9 million
in revenues due to contract restructuring on the Tiger pipeline, a decrease of
$6 million
due to lower rates on the Panhandle, Trunkline and Transwestern pipelines due to weak spreads, and a decrease of
$3 million
on the Sea
|
•
|
a decrease of
$2 million
in operating expenses primarily due to lower maintenance projects and lower allocated costs; and
|
•
|
a decrease of
$1 million
in selling, general and administrative expenses primarily due to insurance proceeds received in 2016 and lower allocated costs.
|
•
|
a decrease of
$17 million
in revenues due to contract restructuring on the Tiger pipeline, a decrease of
$14 million
due to the transfer of one of the Trunkline pipelines which was repurposed from natural gas service to crude oil service, a decrease of
$11 million
due to the expiration of a transportation rate schedule on the Transwestern pipeline, a decrease of
$10 million
due to lower reservation revenues on the Panhandle and Trunkline pipelines from capacity sold at lower rates and lower sales of capacity in the Phoenix area on the Transwestern pipeline, and a decrease of
$8 million
on the Sea Robin pipeline due to declines in production and third party maintenance. These decreases were partially offset by higher reservation revenues on the Transwestern pipeline of
$16 million
from sales of capacity in the East and West, primarily associated with a growth project, and higher parking revenues of
$8 million
, primarily on the Panhandle and Trunkline pipelines; partially offset by
|
•
|
an increase of
$2 million
in overall operating expenses primarily due to the prior period credit and settlement of ad valorem taxes in 2015 of
$5 million
, partially offset by lower maintenance project costs of
$2 million
due to scope and level of activity; and
|
•
|
a decrease of
$7 million
in overall selling, general and administrative expenses primarily due to
$4 million
in lower allocated costs and
$3 million
associated with insurance proceeds and a refund of franchise taxes.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Gathered volumes (MMBtu/d)
|
9,675,003
|
|
|
10,384,106
|
|
|
(709,103
|
)
|
|
9,853,502
|
|
|
9,957,494
|
|
|
(103,992
|
)
|
||||||
NGLs produced (Bbls/d)
|
420,877
|
|
|
413,426
|
|
|
7,451
|
|
|
440,124
|
|
|
393,480
|
|
|
46,644
|
|
||||||
Equity NGLs (Bbls/d)
|
34,341
|
|
|
26,296
|
|
|
8,045
|
|
|
31,847
|
|
|
28,175
|
|
|
3,672
|
|
||||||
Revenues
|
$
|
1,343
|
|
|
$
|
1,379
|
|
|
$
|
(36
|
)
|
|
$
|
3,765
|
|
|
$
|
3,770
|
|
|
$
|
(5
|
)
|
Cost of products sold
|
867
|
|
|
915
|
|
|
(48
|
)
|
|
2,415
|
|
|
2,423
|
|
|
(8
|
)
|
||||||
Gross margin
|
476
|
|
|
464
|
|
|
12
|
|
|
1,350
|
|
|
1,347
|
|
|
3
|
|
||||||
Unrealized losses on commodity risk management activities
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
82
|
|
|
(82
|
)
|
||||||
Operating expenses, excluding non-cash compensation expense
|
(153
|
)
|
|
(148
|
)
|
|
(5
|
)
|
|
(453
|
)
|
|
(433
|
)
|
|
(20
|
)
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
(17
|
)
|
|
(9
|
)
|
|
(8
|
)
|
|
(42
|
)
|
|
(36
|
)
|
|
(6
|
)
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
7
|
|
|
6
|
|
|
1
|
|
|
19
|
|
|
14
|
|
|
5
|
|
||||||
Other
|
1
|
|
|
2
|
|
|
(1
|
)
|
|
1
|
|
|
3
|
|
|
(2
|
)
|
||||||
Segment Adjusted EBITDA
|
$
|
314
|
|
|
$
|
315
|
|
|
$
|
(1
|
)
|
|
$
|
875
|
|
|
$
|
977
|
|
|
$
|
(102
|
)
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Gathering and processing fee-based revenues
|
$
|
393
|
|
|
$
|
418
|
|
|
$
|
(25
|
)
|
|
$
|
1,177
|
|
|
$
|
1,182
|
|
|
$
|
(5
|
)
|
Non fee-based contracts and processing
|
83
|
|
|
46
|
|
|
37
|
|
|
173
|
|
|
165
|
|
|
8
|
|
||||||
Total gross margin
|
$
|
476
|
|
|
$
|
464
|
|
|
$
|
12
|
|
|
$
|
1,350
|
|
|
$
|
1,347
|
|
|
$
|
3
|
|
•
|
an increase of
$27 million
in non-fee based margin due to volume increases in the Permian region, partially offset by volume declines in the South Texas, North Texas, and Mid-Continent/Panhandle regions; and
|
•
|
an increase of
$10 million
in non-fee based margins due to higher crude oil and NGL prices; offset by
|
•
|
a decrease of
$25 million
in fee-based margin due to volume declines in the South Texas, North Texas, and Mid-Continent/Panhandle regions, partially offset by increased gathering and processing volumes in the Permian and Cotton Valley regions; and
|
•
|
an increase in general and administrative expenses of
$8 million
primarily due to an increase of
$3 million
in insurance allocation from corporate, a decrease of
$3 million
in capitalized overhead, and an increase of
$2 million
in legal expenses.
|
•
|
a decrease of
$14 million
in non-fee based margins due to lower natural gas prices and a
$18 million
decrease in non-fee based margins due to lower crude oil and NGL prices;
|
•
|
a decrease of
$5 million
in fee-based margin due to volume declines in the South Texas, North Texas, and Mid-Continent/Panhandle regions, partially offset by increased gathering and processing volumes in the Permian and Cotton Valley regions;
|
•
|
a decrease in gross margin of
$85 million
due to lower benefit from settled derivatives used to hedge commodity margins; and
|
•
|
an increase in operating expenses of
$20 million
primarily due to the King Ranch acquisition in the second quarter of 2015 and assets recently placed in service in the Permian and Eagle Ford regions; partially offset by
|
•
|
an increase of
$39 million
in non-fee based margin due to volume increases in the Permian region, partially offset by volume declines in the South Texas, North Texas, and Mid-Continent/Panhandle regions.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Liquids transportation volumes (Bbls/d)
|
647,018
|
|
|
509,894
|
|
|
137,124
|
|
|
612,815
|
|
|
486,041
|
|
|
126,774
|
|
||||||
NGL fractionation volumes (Bbls/d)
|
338,237
|
|
|
228,695
|
|
|
109,542
|
|
|
349,986
|
|
|
231,161
|
|
|
118,825
|
|
||||||
Revenues
|
$
|
1,207
|
|
|
$
|
858
|
|
|
$
|
349
|
|
|
$
|
3,236
|
|
|
$
|
2,521
|
|
|
$
|
715
|
|
Cost of products sold
|
927
|
|
|
615
|
|
|
312
|
|
|
2,438
|
|
|
1,882
|
|
|
556
|
|
||||||
Gross margin
|
280
|
|
|
243
|
|
|
37
|
|
|
798
|
|
|
639
|
|
|
159
|
|
||||||
Unrealized (gains) losses on commodity risk management activities
|
5
|
|
|
(4
|
)
|
|
9
|
|
|
20
|
|
|
—
|
|
|
20
|
|
||||||
Operating expenses, excluding non-cash compensation expense
|
(43
|
)
|
|
(40
|
)
|
|
(3
|
)
|
|
(121
|
)
|
|
(114
|
)
|
|
(7
|
)
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
(2
|
)
|
|
(4
|
)
|
|
2
|
|
|
(12
|
)
|
|
(12
|
)
|
|
—
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
5
|
|
|
(3
|
)
|
||||||
Segment Adjusted EBITDA
|
$
|
240
|
|
|
$
|
195
|
|
|
$
|
45
|
|
|
$
|
687
|
|
|
$
|
518
|
|
|
$
|
169
|
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Transportation margin
|
$
|
124
|
|
|
$
|
109
|
|
|
$
|
15
|
|
|
$
|
355
|
|
|
$
|
289
|
|
|
$
|
66
|
|
Processing and fractionation margin
|
103
|
|
|
76
|
|
|
27
|
|
|
296
|
|
|
217
|
|
|
79
|
|
||||||
Storage margin
|
50
|
|
|
41
|
|
|
9
|
|
|
148
|
|
|
124
|
|
|
24
|
|
||||||
Other margin
|
3
|
|
|
17
|
|
|
(14
|
)
|
|
(1
|
)
|
|
9
|
|
|
(10
|
)
|
||||||
Total gross margin
|
$
|
280
|
|
|
$
|
243
|
|
|
$
|
37
|
|
|
$
|
798
|
|
|
$
|
639
|
|
|
$
|
159
|
|
•
|
increases in transportation fees of
$15 million
and
$66 million
, respectively, primarily due to higher volumes transported out of the Permian and North Texas regions;
|
•
|
increases of
$27 million
and
$79 million
, respectively, in processing and fractionation margin (excluding changes in unrealized gains of
$1 million
for the three month period and unrealized losses of $2 million for the nine month period) primarily due to the ramp-up of our third
100,000
Bbls/d fractionator at Mont Belvieu, Texas, along with higher producer volumes, primarily from West Texas. Additionally, the three and nine months ended September 30, 2016 also reflect additional increases of $1 million and $19 million, respectively, from the commissioning of the Mariner South LPG export project during February 2015. Margin associated with our off-gas fractionator in Geismar, Louisiana decreased by $5 million for the nine months ended September 30, 2016 as NGL and olefin market prices decreased significantly for the comparable periods;
|
•
|
increases in storage margin of
$9 million
and
$24 million
, respectively, partially due to an increase in demand for leased storage capacity as a result of favorable market conditions, which increased fee-based storage revenues by
$2 million
and $7 million, respectively. The remainder of the storage margin increases were primarily due to increases in throughput fees, as shuttle volumes increased for the three and nine months ended September 30, 2016 by
9%
and 24%, respectively;
|
•
|
a decrease of
$6 million
and an increase of $8 million, respectively, in other margin (excluding increases in unrealized losses of
$9 million
and $18 million, respectively) primarily due to fluctuating optimization opportunities at our Mont Belvieu facility; and
|
•
|
increases in operating expenses of
$3 million
and
$7 million
, respectively, primarily due to increased costs associated with our third fractionator at Mont Belvieu.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Revenues
|
$
|
2,189
|
|
|
$
|
2,406
|
|
|
$
|
(217
|
)
|
|
$
|
6,234
|
|
|
$
|
8,181
|
|
|
$
|
(1,947
|
)
|
Cost of products sold
|
1,818
|
|
|
2,144
|
|
|
(326
|
)
|
|
5,116
|
|
|
7,240
|
|
|
(2,124
|
)
|
||||||
Gross margin
|
371
|
|
|
262
|
|
|
109
|
|
|
1,118
|
|
|
941
|
|
|
177
|
|
||||||
Unrealized (gains) losses on commodity risk management activities
|
16
|
|
|
(31
|
)
|
|
47
|
|
|
33
|
|
|
(9
|
)
|
|
42
|
|
||||||
Operating expenses, excluding non-cash compensation expense
|
(38
|
)
|
|
(40
|
)
|
|
2
|
|
|
(90
|
)
|
|
(116
|
)
|
|
26
|
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
(25
|
)
|
|
(23
|
)
|
|
(2
|
)
|
|
(72
|
)
|
|
(68
|
)
|
|
(4
|
)
|
||||||
Inventory valuation adjustments
|
(37
|
)
|
|
103
|
|
|
(140
|
)
|
|
(143
|
)
|
|
44
|
|
|
(187
|
)
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
25
|
|
|
18
|
|
|
7
|
|
|
60
|
|
|
44
|
|
|
16
|
|
||||||
Segment Adjusted EBITDA
|
$
|
312
|
|
|
$
|
289
|
|
|
$
|
23
|
|
|
$
|
906
|
|
|
$
|
836
|
|
|
$
|
70
|
|
•
|
an increase of
$11 million
from Sunoco Logistics’ NGLs operations, primarily attributable to increased volumes and fees from Sunoco Logistics’ Mariner NGLs projects of
$23 million
, which includes Sunoco Logistics’ NGLs pipelines and Marcus Hook and Nederland facilities; and
|
•
|
an increase of
$26 million
from Sunoco Logistics’ refined products operations, primarily due to improved operating results from Sunoco Logistics’ refined products pipelines of
$11 million
, which benefited from higher volumes on Sunoco Logistics’ Allegheny Access pipeline, and higher results from Sunoco Logistics’ refined products acquisition and marketing activities of
$10 million
. Improved contributions from joint venture interests of
$3 million
and Sunoco Logistics’ refined products terminals of
$2 million
also contributed to the increase; offset by
|
•
|
a decrease of
$14 million
from Sunoco Logistics’ crude oil operations, primarily due to lower operating results from Sunoco Logistics’ crude oil acquisition and marketing activities of
$38 million
, which includes transportation and storage fees related to Sunoco Logistics’ crude oil pipelines and terminal facilities, resulting from lower crude oil differentials compared to the prior year period. This decrease was partially offset by improved results from Sunoco Logistics’ crude oil pipelines of
$21 million
which benefited from the Delaware Basin Extension and Permian Longview and Louisiana Extension pipelines that commenced operations in the third quarter 2016. Higher contributions from joint venture interests of
$4 million
also contributed to the offset.
|
•
|
an increase of
$63 million
from Sunoco Logistics’ refined products operations, primarily due to improved operating results from Sunoco Logistics’ refined products pipelines of
$29 million
, which benefited from higher volumes on Sunoco Logistics’ Allegheny Access pipeline, and higher results from Sunoco Logistics’ refined products acquisition and marketing activities
|
•
|
an increase of
$6 million
from Sunoco Logistics’ NGLs operations, primarily due to increased volumes and fees from Sunoco Logistics’ Mariner NGLs projects of
$73 million
, which includes Sunoco Logistics’ NGLs pipelines and Marcus Hook and Nederland facilities. These factors were largely offset by lower operating results from Sunoco Logistics’ NGLs acquisition and marketing activities of
$66 million
; and
|
•
|
an increase of
$1 million
from Sunoco Logistics’ crude oil operations, primarily due to improved results from Sunoco Logistics’ crude oil pipelines of
$116 million
which benefited from the Permian Express 2 pipeline that commenced operations in third quarter 2015 and the Delaware Basin Extension and Permian Longview and Louisiana Extension pipelines that commenced operations in the third quarter 2016. Higher results from Sunoco Logistics’ crude oil terminals of
$20 million
, largely related to Sunoco Logistics’ Nederland facility, and improved contributions from joint venture interests of
$9 million
also contributed to the increase. These positive factors were largely offset by a decrease in operating results from Sunoco Logistics’ crude oil acquisition and marketing activities of
$140 million
, which includes transportation and storage fees related to Sunoco Logistics’ crude oil pipelines and terminal facilities, due to lower crude oil differentials and decreased volumes.
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Revenues
|
$
|
—
|
|
|
$
|
1,363
|
|
|
$
|
(1,363
|
)
|
|
$
|
—
|
|
|
$
|
11,705
|
|
|
$
|
(11,705
|
)
|
Cost of products sold
|
—
|
|
|
1,149
|
|
|
(1,149
|
)
|
|
—
|
|
|
10,519
|
|
|
(10,519
|
)
|
||||||
Gross margin
|
—
|
|
|
214
|
|
|
(214
|
)
|
|
—
|
|
|
1,186
|
|
|
(1,186
|
)
|
||||||
Unrealized (gains) losses on commodity risk management activities
|
—
|
|
|
(1
|
)
|
|
1
|
|
|
—
|
|
|
2
|
|
|
(2
|
)
|
||||||
Operating expenses, excluding non-cash compensation expense
|
—
|
|
|
(149
|
)
|
|
149
|
|
|
—
|
|
|
(701
|
)
|
|
701
|
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
—
|
|
|
(8
|
)
|
|
8
|
|
|
—
|
|
|
(99
|
)
|
|
99
|
|
||||||
Inventory valuation adjustments
|
—
|
|
|
4
|
|
|
(4
|
)
|
|
—
|
|
|
(60
|
)
|
|
60
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
83
|
|
|
135
|
|
|
(52
|
)
|
|
208
|
|
|
136
|
|
|
72
|
|
||||||
Segment Adjusted EBITDA
|
$
|
83
|
|
|
$
|
195
|
|
|
$
|
(112
|
)
|
|
$
|
208
|
|
|
$
|
464
|
|
|
$
|
(256
|
)
|
|
Three Months Ended
September 30, |
|
|
|
Nine Months Ended
September 30, |
|
|
||||||||||||||||
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
||||||||||||
Revenues
|
$
|
956
|
|
|
$
|
976
|
|
|
$
|
(20
|
)
|
|
$
|
2,521
|
|
|
$
|
2,439
|
|
|
$
|
82
|
|
Cost of products sold
|
877
|
|
|
855
|
|
|
22
|
|
|
2,263
|
|
|
2,107
|
|
|
156
|
|
||||||
Gross margin
|
79
|
|
|
121
|
|
|
(42
|
)
|
|
258
|
|
|
332
|
|
|
(74
|
)
|
||||||
Unrealized (gains) losses on commodity risk management activities
|
1
|
|
|
(7
|
)
|
|
8
|
|
|
19
|
|
|
—
|
|
|
19
|
|
||||||
Operating expenses, excluding non-cash compensation expense
|
(20
|
)
|
|
(33
|
)
|
|
13
|
|
|
(57
|
)
|
|
(79
|
)
|
|
22
|
|
||||||
Selling, general and administrative expenses, excluding non-cash compensation expense
|
(14
|
)
|
|
(33
|
)
|
|
19
|
|
|
(60
|
)
|
|
(112
|
)
|
|
52
|
|
||||||
Adjusted EBITDA related to unconsolidated affiliates
|
(20
|
)
|
|
47
|
|
|
(67
|
)
|
|
1
|
|
|
103
|
|
|
(102
|
)
|
||||||
Other
|
23
|
|
|
23
|
|
|
—
|
|
|
71
|
|
|
71
|
|
|
—
|
|
||||||
Eliminations
|
(19
|
)
|
|
(25
|
)
|
|
6
|
|
|
(45
|
)
|
|
(49
|
)
|
|
4
|
|
||||||
Segment Adjusted EBITDA
|
$
|
30
|
|
|
$
|
93
|
|
|
$
|
(63
|
)
|
|
$
|
187
|
|
|
$
|
266
|
|
|
$
|
(79
|
)
|
•
|
our natural gas marketing and compression operations;
|
•
|
a non-controlling interest in PES, comprising 33% of PES’ outstanding common units; and
|
•
|
our investment in Coal Handling, an entity that owns and operates end-user coal handling facilities.
|
|
Growth
|
|
Maintenance
|
||||||||||||
|
Low
|
|
High
|
|
Low
|
|
High
|
||||||||
Direct
(1)
:
|
|
|
|
|
|
|
|
||||||||
Intrastate transportation and storage
(2)
|
$
|
40
|
|
|
$
|
50
|
|
|
$
|
20
|
|
|
$
|
25
|
|
Interstate transportation and storage
(2)(3)
|
210
|
|
|
250
|
|
|
95
|
|
|
105
|
|
||||
Midstream
|
1,225
|
|
|
1,275
|
|
|
100
|
|
|
110
|
|
||||
Liquids transportation and services
|
|
|
|
|
|
|
|
||||||||
NGL
|
875
|
|
|
900
|
|
|
20
|
|
|
25
|
|
||||
Crude
(2)(3)
|
300
|
|
|
325
|
|
|
—
|
|
|
—
|
|
||||
All other (including eliminations)
|
90
|
|
|
100
|
|
|
40
|
|
|
45
|
|
||||
Total direct capital expenditures
|
$
|
2,740
|
|
|
$
|
2,900
|
|
|
$
|
275
|
|
|
$
|
310
|
|
(1)
|
Direct capital expenditures exclude those funded by our publicly traded subsidiary.
|
(2)
|
Net of amounts forecasted to be financed at the asset level with non-recourse debt of approximately
$1.17 billion
.
|
(3)
|
Includes capital expenditures related to our proportionate ownership of the Bakken, Rover and Bayou Bridge pipeline projects.
|
|
Capital Expenditures Recorded During Period
|
||||||||||
|
Growth
|
|
Maintenance
|
|
Total
|
||||||
Direct
(1)
:
|
|
|
|
|
|
||||||
Intrastate transportation and storage
|
$
|
34
|
|
|
$
|
11
|
|
|
$
|
45
|
|
Interstate transportation and storage
(2)
|
138
|
|
|
55
|
|
|
193
|
|
|||
Midstream
|
868
|
|
|
82
|
|
|
950
|
|
|||
Liquids transportation and services
(2)
|
1,460
|
|
|
14
|
|
|
1,474
|
|
|||
All other (including eliminations)
|
66
|
|
|
32
|
|
|
98
|
|
|||
Total direct capital expenditures
|
2,566
|
|
|
194
|
|
|
2,760
|
|
|||
Indirect
(1)
:
|
|
|
|
|
|
||||||
Investment in Sunoco Logistics
|
1,237
|
|
|
40
|
|
|
1,277
|
|
|||
Total capital expenditures
|
$
|
3,803
|
|
|
$
|
234
|
|
|
$
|
4,037
|
|
(1)
|
Indirect capital expenditures comprise those funded by our publicly traded subsidiary; all other capital expenditures are reflected as direct capital expenditures.
|
(2)
|
Includes capital expenditures related to the Bakken, Rover and Bayou Bridge pipeline projects, which includes $268 million related to Sunoco Logistics’ proportionate ownership in the Bakken and Bayou Bridge pipeline projects.
|
|
September 30, 2016
|
|
December 31, 2015
|
||||
ETP Senior Notes
|
$
|
19,439
|
|
|
$
|
19,439
|
|
Transwestern Senior Notes
|
782
|
|
|
782
|
|
||
Panhandle Senior Notes
|
1,085
|
|
|
1,085
|
|
||
Sunoco, Inc. Senior Notes
|
465
|
|
|
465
|
|
||
Sunoco Logistics Senior Notes
|
5,350
|
|
|
4,975
|
|
||
Bakken Term Note
|
1,100
|
|
|
—
|
|
||
Revolving credit facilities and commercial paper:
|
|
|
|
||||
ETP $3.75 billion Revolving Credit Facility due November 2019
(1)
|
1,584
|
|
|
1,362
|
|
||
Sunoco Logistics $2.50 billion Revolving Credit Facility due March 2020
(2)
|
622
|
|
|
562
|
|
||
Other long-term debt
|
32
|
|
|
32
|
|
||
Unamortized premiums, net of discounts and fair value adjustments
|
126
|
|
|
158
|
|
||
Deferred debt issuance costs
|
(187
|
)
|
|
(181
|
)
|
||
Total debt
|
30,398
|
|
|
28,679
|
|
||
Less: Current maturities of long-term debt
|
1,216
|
|
|
126
|
|
||
Long-term debt, less current maturities
|
$
|
29,182
|
|
|
$
|
28,553
|
|
Quarter Ended
|
|
Record Date
|
|
Payment Date
|
|
Rate
|
||
December 31, 2015
|
|
February 8, 2016
|
|
February 16, 2016
|
|
$
|
1.0550
|
|
March 31, 2016
|
|
May 6, 2016
|
|
May 16, 2016
|
|
1.0550
|
|
|
June 30, 2016
|
|
August 8, 2016
|
|
August 15, 2016
|
|
1.0550
|
|
|
September 30, 2016
|
|
November 7, 2016
|
|
November 14, 2016
|
|
1.0550
|
|
|
Nine Months Ended
September 30, |
||||||
|
2016
|
|
2015
|
||||
Common Units held by public
(1)
|
$
|
1,607
|
|
|
$
|
1,458
|
|
Common Units held by ETE
|
8
|
|
|
51
|
|
||
Class H Units held by ETE
|
263
|
|
|
186
|
|
||
General Partner interest held by ETE
|
24
|
|
|
23
|
|
||
Incentive distributions held by ETE
|
1,012
|
|
|
937
|
|
||
IDR relinquishments net of Class I Unit distributions
|
(271
|
)
|
|
(83
|
)
|
||
Total distributions declared to the partners of ETP
|
$
|
2,643
|
|
|
$
|
2,572
|
|
(1)
|
Reflects the impact from Common Units issued in the Regency Merger.
|
|
|
Total Year
|
||
2016 (remainder)
|
|
$
|
138
|
|
2017
|
|
626
|
|
|
2018
|
|
138
|
|
|
2019
|
|
128
|
|
|
Each year beyond 2019
|
|
33
|
|
Quarter Ended
|
|
Record Date
|
|
Payment Date
|
|
Rate
|
||
December 31, 2015
|
|
February 8, 2016
|
|
February 12, 2016
|
|
$
|
0.4790
|
|
March 31, 2016
|
|
May 9, 2016
|
|
May 13, 2016
|
|
0.4890
|
|
|
June 30, 2016
|
|
August 8, 2016
|
|
August 12, 2016
|
|
0.5000
|
|
|
September 30, 2016
|
|
November 9, 2016
|
|
November 14, 2016
|
|
0.5100
|
|
|
Nine Months Ended
September 30, |
||||||
|
2016
|
|
2015
|
||||
Limited Partners:
|
|
|
|
||||
Common units held by public
|
$
|
353
|
|
|
$
|
245
|
|
Common units held by ETP
|
100
|
|
|
88
|
|
||
General Partner interest held by ETP
|
11
|
|
|
9
|
|
||
Incentive distributions held by ETP
|
289
|
|
|
198
|
|
||
IDR reduction
|
(8
|
)
|
|
—
|
|
||
Total distributions declared
|
$
|
745
|
|
|
$
|
540
|
|
|
September 30, 2016
|
|
December 31, 2015
|
||||||||||||||||||
|
Notional Volume
|
|
Fair Value Asset (Liability)
|
|
Effect of Hypothetical 10% Change
|
|
Notional Volume
|
|
Fair Value Asset (Liability)
|
|
Effect of Hypothetical 10% Change
|
||||||||||
Mark-to-Market Derivatives
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
(Trading)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed Swaps/Futures
|
1,262,500
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
(602,500
|
)
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
Basis Swaps IFERC/NYMEX
(1)
|
60,102,500
|
|
|
—
|
|
|
—
|
|
|
(31,240,000
|
)
|
|
(1
|
)
|
|
—
|
|
||||
Power (Megawatt):
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Forwards
|
419,824
|
|
|
2
|
|
|
1
|
|
|
357,092
|
|
|
—
|
|
|
2
|
|
||||
Futures
|
99,247
|
|
|
—
|
|
|
—
|
|
|
(109,791
|
)
|
|
2
|
|
|
—
|
|
||||
Options – Puts
|
(536,400
|
)
|
|
1
|
|
|
—
|
|
|
260,534
|
|
|
—
|
|
|
—
|
|
||||
Options – Calls
|
1,080,400
|
|
|
(2
|
)
|
|
2
|
|
|
1,300,647
|
|
|
—
|
|
|
3
|
|
||||
Crude (Bbls):
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Futures
|
(656,000
|
)
|
|
—
|
|
|
5
|
|
|
(591,000
|
)
|
|
4
|
|
|
3
|
|
||||
(Non-Trading)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Basis Swaps IFERC/NYMEX
|
4,762,500
|
|
|
1
|
|
|
—
|
|
|
(6,522,500
|
)
|
|
—
|
|
|
—
|
|
||||
Swing Swaps IFERC
|
13,072,500
|
|
|
—
|
|
|
2
|
|
|
71,340,000
|
|
|
(1
|
)
|
|
—
|
|
||||
Fixed Swaps/Futures
|
(35,962,500
|
)
|
|
—
|
|
|
11
|
|
|
(14,380,000
|
)
|
|
(1
|
)
|
|
5
|
|
||||
Forward Physical Contracts
|
(6,834,328
|
)
|
|
1
|
|
|
2
|
|
|
21,922,484
|
|
|
4
|
|
|
5
|
|
||||
Natural Gas Liquid (Bbls) – Forwards/Swaps
|
(13,519,200
|
)
|
|
(29
|
)
|
|
42
|
|
|
(8,146,800
|
)
|
|
10
|
|
|
13
|
|
||||
Refined Products (Bbls) – Futures
|
(1,970,000
|
)
|
|
(9
|
)
|
|
20
|
|
|
(993,000
|
)
|
|
9
|
|
|
5
|
|
||||
Corn (Bushels) – Futures
|
—
|
|
|
—
|
|
|
—
|
|
|
1,185,000
|
|
|
—
|
|
|
1
|
|
||||
Fair Value Hedging Derivatives
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
(Non-Trading)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Natural Gas (MMBtu):
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Basis Swaps IFERC/NYMEX
|
(30,620,000
|
)
|
|
(1
|
)
|
|
—
|
|
|
(37,555,000
|
)
|
|
—
|
|
|
—
|
|
||||
Fixed Swaps/Futures
|
(30,620,000
|
)
|
|
(12
|
)
|
|
10
|
|
|
(37,555,000
|
)
|
|
73
|
|
|
9
|
|
(1)
|
Includes aggregate amounts for open positions related to Houston Ship Channel, Waha Hub, NGPL TexOk, West Louisiana Zone and Henry Hub locations.
|
Term
|
|
Type
(1)
|
|
Notional Amount Outstanding
|
||||||
September 30, 2016
|
|
December 31, 2015
|
||||||||
July 2016
(2)(4)
|
|
Forward-starting to pay a fixed rate of 3.80% and receive a floating rate
|
|
$
|
—
|
|
|
$
|
200
|
|
July 2017
(3)(4)
|
|
Forward-starting to pay a fixed rate of 3.90% and receive a floating rate
|
|
500
|
|
|
300
|
|
||
July 2018
(3)
|
|
Forward-starting to pay a fixed rate of 4.00% and receive a floating rate
|
|
200
|
|
|
200
|
|
||
December 2018
|
|
Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.53%
|
|
1,200
|
|
|
1,200
|
|
||
March 2019
|
|
Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.42%
|
|
300
|
|
|
300
|
|
||
July 2019
(3)
|
|
Forward-starting to pay a fixed rate of 3.25% and receive a floating rate
|
|
200
|
|
|
200
|
|
(1)
|
Floating rates are based on 3-month LIBOR.
|
(2)
|
Represents the effective date. These forward-starting swaps have terms of 10 and 30 years with a mandatory termination date the same as the effective date.
|
(3)
|
Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.
|
(4)
|
ETP previously had outstanding forward starting interest rate swaps, which were scheduled to expire in July 2016, with a total notional value of
$200 million
. In June 2016, ETP extended the expiration of those swaps to July 2017.
|
Exhibit Number
|
|
Description
|
2.1
|
|
Contribution Agreement, dated October 24, 2016 by and among Energy Transfer Partners, L.P. and NGP X US Holdings, LP, PennTex Midstream Partners, LLC, MRD Midstream LLC, WHR Midstream LLC and certain individual investors and managers named therein (incorporated by reference to Exhibit 2.1 to the Registrant’s Form 8-K filed October 25, 2016).
|
2.2*
|
|
Membership Interest Purchase Agreement, dated as of August 2, 2016, by and between Bakken Holdings Company LLC and MarEn Bakken Company LLC.
|
3.1
|
|
Amendment No. 13 to the Second Amended and Restated Agreement of Limited Partnership of Energy Transfer Partners, L.P., dated July 27, 2016 (incorporated by reference to Exhibit 3.1 to the Registrant’s Form 8-K filed August 2, 2016).
|
10.1
|
|
Form of Commercial Paper Dealer Agreement between Energy Transfer Partners, L.P., as Issuer, and the Dealer party thereto (incorporated by reference to Exhibit 99.1 to the Registrant’s Form 8-K filed August 22, 2016).
|
31.1*
|
|
Certification of Chief Executive Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934 pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.2*
|
|
Certification of Chief Financial Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934 pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.1**
|
|
Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.2**
|
|
Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
101.INS*
|
|
XBRL Instance Document
|
101.SCH*
|
|
XBRL Taxonomy Extension Schema Document
|
101.CAL*
|
|
XBRL Taxonomy Extension Calculation Linkbase Document
|
101.DEF*
|
|
XBRL Taxonomy Extension Definition Linkbase Document
|
101.LAB*
|
|
XBRL Taxonomy Extension Label Linkbase Document
|
101.PRE*
|
|
XBRL Taxonomy Extension Presentation Linkbase Document
|
*
|
|
Filed herewith.
|
**
|
|
Furnished herewith.
|
|
|
ENERGY TRANSFER PARTNERS, L.P.
|
|
|
|
|
|
|
|
By:
|
Energy Transfer Partners GP, L.P.,
|
|
|
|
its General Partner
|
|
|
|
|
|
|
By:
|
Energy Transfer Partners, L.L.C.,
|
|
|
|
its General Partner
|
|
|
|
|
Date:
|
November 9, 2016
|
By:
|
/s/ A. Troy Sturrock
|
|
|
|
A. Troy Sturrock
|
|
|
|
Senior Vice President, Controller and Principal Accounting Officer
(duly authorized to sign on behalf of the registrant)
|
|
|
Page
|
|
ARTICLE I DEFINITIONS AND RULES OF CONSTRUCTION
|
2
|
|
|
Section 1.1
|
Definitions
|
2
|
|
Section 1.2
|
Rules of Construction
|
2
|
|
|
|
|
|
ARTICLE II TRANSFER OF TRANSFERRED INTERESTS
|
2
|
|
|
Section 2.1
|
Transfer of Transferred Interests
|
2
|
|
|
|
|
|
ARTICLE III CONSIDERATION
|
3
|
|
|
Section 3.1
|
Consideration
|
3
|
|
Section 3.2
|
Guaranties
|
3
|
|
|
|
|
|
ARTICLE IV REPRESENTATIONS AND WARRANTIES OF SELLER
|
3
|
|
|
Section 4.1
|
Organization of Seller
|
3
|
|
Section 4.2
|
Authorization; Enforceability
|
3
|
|
Section 4.3
|
No Conflict
|
3
|
|
Section 4.4
|
Consents; Transfer Restrictions
|
4
|
|
Section 4.5
|
Title to Transferred Interests
|
4
|
|
Section 4.6
|
Brokers’ Fees
|
4
|
|
Section 4.7
|
Litigation
|
4
|
|
Section 4.8
|
No Bankruptcy
|
5
|
|
|
|
|
|
ARTICLE V REPRESENTATIONS AND WARRANTIES REGARDING THE COMPANY AND ITS SUBSIDIARIES
|
5
|
|
|
Section 5.1
|
Organization
|
5
|
|
Section 5.2
|
No Conflict
|
5
|
|
Section 5.3
|
Consents; Transfer Restrictions
|
6
|
|
Section 5.4
|
Contracts.
|
6
|
|
Section 5.5
|
Litigation
|
7
|
|
Section 5.6
|
Taxes
|
7
|
|
Section 5.7
|
Compliance with Laws
|
8
|
|
Section 5.8
|
Environmental Matters
|
9
|
|
Section 5.9
|
Membership Interests
|
10
|
|
Section 5.10
|
Title Matters; Real Property Interests
|
11
|
|
Section 5.11
|
Balance Sheet
|
11
|
|
Section 5.12
|
Indebtedness
|
12
|
|
Section 5.13
|
Credit Support
|
12
|
|
Section 5.14
|
Employees; Benefit Plan Matters
|
12
|
|
Section 5.15
|
Insurance
|
12
|
|
Section 5.16
|
Brokers Fees
|
12
|
|
Section 5.17
|
No Bankruptcy
|
12
|
|
ARTICLE VI REPRESENTATIONS AND WARRANTIES OF BUYER
|
12
|
|
|
Section 6.1
|
Organization of Buyer
|
12
|
|
Section 6.2
|
Authorization; Enforceability
|
12
|
|
Section 6.3
|
No Conflict; Consents
|
13
|
|
Section 6.4
|
Consents and Approvals
|
13
|
|
Section 6.5
|
Litigation
|
13
|
|
Section 6.6
|
Brokers’ Fees
|
14
|
|
Section 6.7
|
Financial Ability
|
14
|
|
Section 6.8
|
Regulatory
|
14
|
|
Section 6.9
|
Independent Evaluation
|
14
|
|
Section 6.10
|
Accredited Investor
|
14
|
|
|
|
|
|
ARTICLE VII COVENANTS
|
15
|
|
|
Section 7.1
|
Conduct of Business, Operation of Assets
|
15
|
|
Section 7.2
|
Access and Information
|
16
|
|
Section 7.3
|
Regulatory Filings
|
17
|
|
Section 7.4
|
Consents
|
17
|
|
Section 7.5
|
Amendment of Schedules
|
18
|
|
Section 7.6
|
Further Assurances
|
18
|
|
Section 7.7
|
Exclusivity
|
18
|
|
Section 7.8
|
Senior Secured Credit Facility
|
19
|
|
|
|
|
|
ARTICLE VIII CONDITIONS TO CLOSING
|
19
|
|
|
Section 8.1
|
Buyer’s Conditions to Closing
|
19
|
|
Section 8.2
|
Conditions to the Obligations of Seller
|
20
|
|
|
|
|
|
ARTICLE IX CLOSING
|
21
|
|
|
Section 9.1
|
Closing
|
21
|
|
Section 9.2
|
Seller Deliverables
|
21
|
|
Section 9.3
|
Buyer Deliverables
|
21
|
|
|
|
|
|
ARTICLE X INDEMNIFICATION
|
22
|
|
|
Section 10.1
|
Survival
|
22
|
|
Section 10.2
|
Indemnification Provisions for Benefit of Buyer
|
22
|
|
Section 10.3
|
Indemnification Provisions for Benefit of Seller
|
23
|
|
Section 10.4
|
Limitation on Liability
|
23
|
|
Section 10.5
|
Procedures
|
24
|
|
Section 10.6
|
Express Negligence
|
25
|
|
Section 10.7
|
Waiver of Right to Rescission
|
26
|
|
Section 10.8
|
Exclusive Remedy
|
26
|
|
Section 10.9
|
Non-Compensatory Damages
|
26
|
|
Section 10.10
|
Tax Treatment of Payments
|
27
|
|
|
|
|
ARTICLE XI TERMINATION
|
27
|
|
|
Section 11.1
|
Termination
|
27
|
|
Section 11.2
|
Effect of Termination
|
28
|
|
Section 11.3
|
Return of Documentation and Confidentiality
|
28
|
|
|
|
|
|
ARTICLE XII DISCLAIMERS
|
28
|
|
|
Section 12.1
|
Disclaimer - Representations and Warranties
|
28
|
|
Section 12.2
|
Disclaimer - Statements and Information
|
29
|
|
|
|
|
|
ARTICLE XIII TAX MATTERS
|
30
|
|
|
Section 13.1
|
Liability for Transfer Taxes
|
30
|
|
Section 13.2
|
Company Tax Returns
|
30
|
|
Section 13.3
|
Cooperation on Tax Matters
|
31
|
|
Section 13.4
|
Straddle Period
|
31
|
|
Section 13.5
|
Tax Classification Elections
|
31
|
|
Section 13.6
|
754 Election
|
31
|
|
Section 13.7
|
Intended Tax Treatment
|
31
|
|
Section 13.8
|
Allocation of Purchase Price
|
32
|
|
|
|
|
|
ARTICLE XIV MISCELLANEOUS
|
32
|
|
|
Section 14.1
|
Notices
|
32
|
|
Section 14.2
|
Succession and Assignment
|
33
|
|
Section 14.3
|
Rights of Third Parties
|
33
|
|
Section 14.4
|
Expenses
|
34
|
|
Section 14.5
|
Counterparts
|
34
|
|
Section 14.6
|
Entire Agreement
|
34
|
|
Section 14.7
|
No Partnership
|
34
|
|
Section 14.8
|
Amendments
|
34
|
|
Section 14.9
|
Publicity
|
34
|
|
Section 14.10
|
Non-Waiver
|
35
|
|
Section 14.11
|
Severability
|
35
|
|
Section 14.12
|
Governing Law; Jurisdiction
|
35
|
|
Section 14.13
|
Schedules
|
36
|
|
Appendix I
|
Definitions
|
Exhibit A
|
Form of Assignment
|
Exhibit B
|
Form of Company Agreement
|
Exhibit C
|
Form of Seller Parent Guaranties
|
Exhibit D
|
Form of Buyer Parent Guaranties
|
Schedule 1.1(a)
|
Seller Persons with Knowledge
|
Schedule 1.1(b)
|
Buyer Persons with Knowledge
|
Schedule 1.1(c)
|
Certain Permitted Liens
|
Schedule 4.3
|
Seller’s No Conflicts
|
Schedule 5.1(d)
|
Managers, Directors and Officers
|
Schedule 5.2
|
No Conflicts
|
Schedule 5.3
|
Company Consents and Approvals
|
Schedule 5.4(a)
|
Material Contracts
|
Schedule 5.5
|
Litigation
|
Schedule 5.6
|
Taxes
|
Schedule 5.7(a)
|
Compliance with Laws
|
Schedule 5.7(b)
|
Material Permits
|
Schedule 5.7(c)
|
Certain Material Permits
|
Schedule 5.8(b)
|
Environmental Matters
|
Schedule 5.8(c)
|
Material Environmental Permits
|
Schedule 5.9
|
Membership Interests
|
Schedule 5.11(a)
|
Balance Sheet
|
Schedule 5.12
|
Indebtedness
|
Schedule 5.13
|
Credit Support
|
Schedule 5.15(a)
|
Insurance
|
Schedule 5.15(b)
|
Certain Insurance Claims
|
Schedule 6.3
|
Buyer’s No Conflicts
|
1.
|
I have reviewed this quarterly report on Form 10-Q of Energy Transfer Partners, L.P.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
a.
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
b.
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
c.
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
d.
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
a.
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
b.
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
/s/ Kelcy L. Warren
|
Kelcy L. Warren
|
Chief Executive Officer
|
1.
|
I have reviewed this quarterly report on Form 10-Q of Energy Transfer Partners, L.P.;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
a.
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
b.
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
c.
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
d.
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
a.
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
b.
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
/s/ Thomas E. Long
|
Thomas E. Long
|
Chief Financial Officer
|
(1)
|
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and
|
(2)
|
The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
|
/s/ Kelcy L. Warren
|
Kelcy L. Warren
|
Chief Executive Officer
|
(1)
|
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and
|
(2)
|
The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
|
/s/ Thomas E. Long
|
Thomas E. Long
|
Chief Financial Officer
|