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þ
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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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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27‑4151603
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(State or other jurisdiction of
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(I.R.S. Employer
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incorporation or organization)
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Identification No.)
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19100 Ridgewood Pkwy, San Antonio, Texas 78259-1828
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(Address of principal executive offices) (Zip Code)
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210-626-6000
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(Registrant’s telephone number, including area code)
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Large accelerated filer
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þ
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Accelerated filer
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o
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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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o
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Emerging growth company
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o
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TABLE OF CONTENTS
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PART I
— FINANCIAL
INFORMATION
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2
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FINANCIAL STATEMENTS
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ITEM 1.
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FINANCIAL STATEMENTS
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Three Months Ended
June 30, |
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Six Months Ended
June 30, |
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2017
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2016 (a)
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2017
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2016 (a)
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(In millions, except per unit amounts)
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||||||||||||||
Revenues
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Affiliate
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$
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202
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$
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168
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$
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405
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$
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337
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Third-party
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211
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125
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428
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256
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Total Revenues
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413
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293
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833
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593
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Costs and Expenses
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Cost of sales
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55
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|
1
|
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114
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1
|
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Operating expenses
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132
|
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106
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258
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216
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||||
General and administrative expenses
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25
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22
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52
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46
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Depreciation and amortization expenses
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60
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46
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118
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92
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(Gain) loss on asset disposals and impairments
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(25
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)
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—
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(25
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)
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1
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Operating Income
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166
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118
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316
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237
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Interest and financing costs, net
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(59
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)
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(45
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)
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(119
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)
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(89
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)
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Equity in earnings of equity method investments
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3
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3
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5
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7
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Other income, net
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—
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—
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—
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6
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Net Earnings
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$
|
110
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$
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76
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$
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202
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$
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161
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|
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Loss attributable to Predecessors
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$
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—
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$
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7
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$
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—
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$
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14
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Net Earnings Attributable to Partners
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110
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83
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202
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175
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General partner’s interest in net earnings, including incentive distribution rights
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(40
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)
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(36
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)
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(77
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)
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(68
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)
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Limited Partners’ Interest in Net Earnings
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$
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70
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$
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47
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$
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125
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$
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107
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Net Earnings per Limited Partner Unit
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Common - basic
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$
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0.63
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$
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0.48
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$
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1.15
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$
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1.12
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Common - diluted
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$
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0.63
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$
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0.48
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$
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1.15
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$
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1.12
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Weighted Average Limited Partner Units Outstanding
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Common units - basic
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108.0
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95.2
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106.4
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94.4
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Common units - diluted
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108.1
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95.2
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106.5
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94.4
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Cash Distributions Paid Per Unit
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$
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0.94
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$
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0.81
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$
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1.85
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$
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1.59
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(a)
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Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
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June 30, 2017
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3
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FINANCIAL STATEMENTS
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June 30,
2017 |
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December 31,
2016 |
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(In millions, except unit amounts)
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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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20
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$
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688
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Receivables, net of allowance for doubtful accounts
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Trade
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110
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129
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Affiliate
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98
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101
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Other
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10
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—
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Prepayments and other current assets
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16
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20
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Total Current Assets
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254
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938
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Property, Plant and Equipment, Net
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4,011
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3,444
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Acquired Intangibles, Net
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1,048
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947
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Equity Method Investments
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327
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337
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Goodwill
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127
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117
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Other Noncurrent Assets, Net
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72
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77
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Total Assets
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$
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5,839
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$
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5,860
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LIABILITIES AND EQUITY
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Current Liabilities
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Accounts payable
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Trade
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$
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83
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$
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69
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Affiliate
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36
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56
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Accrued interest and financing costs
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61
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42
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Other current liabilities
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34
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45
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Total Current Liabilities
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214
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212
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Debt, Net of Unamortized Issuance Costs
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3,778
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4,053
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Other Noncurrent Liabilities
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60
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53
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Total Liabilities
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4,052
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4,318
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Commitments and Contingencies (Note 6)
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Equity
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Common unitholders;
108,002,273
units issued and outstanding (102,981,495 in 2016)
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1,848
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1,608
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General partner;
2,202,880
units issued and outstanding (2,100,900 in 2016)
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(61
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)
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(66
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)
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Total Equity
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1,787
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1,542
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Total Liabilities and Equity
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$
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5,839
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$
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5,860
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4
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FINANCIAL STATEMENTS
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Six Months Ended June 30,
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2017
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2016 (a)
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(In millions)
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Cash Flows From (Used In) Operating Activities:
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Net earnings
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$
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202
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$
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161
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Adjustments to reconcile net earnings to net cash from operating activities:
|
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Depreciation and amortization expenses
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118
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92
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(Gain) loss on asset disposals and impairments
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(25
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)
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1
|
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Other operating activities
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17
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19
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Changes in current assets and liabilities
|
18
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(31
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)
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Changes in noncurrent assets and liabilities
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(6
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)
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—
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Net cash from operating activities
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324
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|
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242
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Cash Flows From (Used In) Investing Activities:
|
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Capital expenditures
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(86
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)
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(144
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)
|
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Acquisitions
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(673
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)
|
|
(34
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)
|
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Proceeds from sale of assets
|
28
|
|
|
—
|
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Net cash used in investing activities
|
(731
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)
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|
(178
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)
|
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Cash Flows From (Used In) Financing Activities:
|
|
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|
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Borrowings under revolving credit agreements
|
189
|
|
|
600
|
|
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Repayments under revolving credit agreements
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(469
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)
|
|
(666
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)
|
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Proceeds from debt offering
|
—
|
|
|
701
|
|
||
Repayment of term loan facility
|
—
|
|
|
(250
|
)
|
||
Proceeds from issuance of common units, net of issuance costs
|
281
|
|
|
334
|
|
||
Proceeds from issuance of general partner units, net of issuance costs
|
6
|
|
|
—
|
|
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Quarterly distributions to common unitholders
|
(195
|
)
|
|
(149
|
)
|
||
Quarterly distributions to general partner
|
(85
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)
|
|
(57
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)
|
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Distributions in connection with acquisitions
|
(5
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)
|
|
—
|
|
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Financing costs
|
—
|
|
|
(17
|
)
|
||
Sponsor contributions of equity to the Predecessors
|
—
|
|
|
91
|
|
||
Capital contributions by affiliate
|
19
|
|
|
15
|
|
||
Other financing activities
|
(2
|
)
|
|
—
|
|
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Net cash from (used in) financing activities
|
(261
|
)
|
|
602
|
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Increase (Decrease) in Cash and Cash Equivalents
|
(668
|
)
|
|
666
|
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Cash and Cash Equivalents, Beginning of Period
|
688
|
|
|
16
|
|
||
Cash and Cash Equivalents, End of Period
|
$
|
20
|
|
|
$
|
682
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(a)
|
Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
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|
|
June 30, 2017
|
5
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
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•
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the short term duration of the instruments (less than
one
percent for our third-party receivables and approximately
three
percent of our trade payables have been outstanding for greater than
90 days
); and
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•
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the expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk.
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6
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|
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
|
|
June 30, 2017
|
7
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
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Inventory
|
$
|
2
|
|
Property, plant and equipment
|
571
|
|
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Intangibles (a)
|
122
|
|
|
Goodwill (b)
|
10
|
|
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Total purchase price
|
$
|
705
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(a)
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The intangibles consist of customer contracts with a weighted average amortization period of
10.6 years
. Amortization of intangible assets for the
three
and
six
months ended
June 30, 2017
was
$3 million
and
$7 million
, respectively.
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(b)
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We evaluated several factors that contributed to the amount of goodwill presented above. These factors include the geographic proximity of the acquired assets to existing assets owned by the Partnership along with the improved overall basin logistics efficiencies we can leverage.
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8
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
|
Three Months Ended
June 30, |
|
Six Months Ended
June 30, |
||||||||||||
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2017
|
|
2016
|
|
2017
|
|
2016
|
||||||||
Revenues (a)
|
$
|
202
|
|
|
$
|
168
|
|
|
$
|
405
|
|
|
$
|
337
|
|
Operating expenses (b)
|
38
|
|
|
34
|
|
|
77
|
|
|
69
|
|
||||
General and administrative expenses
|
18
|
|
|
16
|
|
|
38
|
|
|
33
|
|
(a)
|
Andeavor accounted for
49%
of our total revenues for both the
three
and
six
months ended
June 30, 2017
and
57%
for both the
three
and
six
months ended
June 30, 2016
.
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(b)
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Includes imbalance settlement gains of
$2 million
for both the
three
months ended
June 30, 2017
and
2016
, respectively, and
$5 million
and
$3 million
for the
six
months ended
June 30, 2017
and
2016
, respectively. Also includes reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of
$3 million
for both the
three
months ended
June 30, 2017
and
2016
, respectively, and
$5 million
and
$9 million
for the
six
months ended
June 30, 2017
and
2016
, respectively.
|
|
|
June 30, 2017
|
9
|
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
June 30,
2017 |
|
December 31, 2016
|
||||
Gathering and Processing
|
$
|
2,593
|
|
|
$
|
1,983
|
|
Terminalling and Transportation
|
2,120
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|
|
2,076
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|
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Property, Plant and Equipment, at Cost
|
4,713
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|
|
4,059
|
|
||
Accumulated depreciation
|
(702
|
)
|
|
(615
|
)
|
||
Property, Plant and Equipment, Net
|
$
|
4,011
|
|
|
$
|
3,444
|
|
|
June 30,
2017 |
|
December 31, 2016
|
||||
Total debt
|
$
|
3,829
|
|
|
$
|
4,109
|
|
Unamortized issuance costs
|
(50
|
)
|
|
(55
|
)
|
||
Current maturities
|
(1
|
)
|
|
(1
|
)
|
||
Debt, Net of Current Maturities and Unamortized Issuance Costs
|
$
|
3,778
|
|
|
$
|
4,053
|
|
|
Total
Capacity
|
|
Amount Borrowed as of June 30, 2017
|
|
Outstanding
Letters of Credit
|
|
Available Capacity
|
|
Expiration
|
||||||||
Andeavor Logistics Revolving Credit Facility (a)
|
$
|
600
|
|
|
$
|
50
|
|
|
$
|
—
|
|
|
$
|
550
|
|
|
January 29, 2021
|
Andeavor Logistics Dropdown Credit Facility
|
1,000
|
|
|
—
|
|
|
—
|
|
|
1,000
|
|
|
January 29, 2021
|
||||
Total Credit Facilities (b)
|
$
|
1,600
|
|
|
$
|
50
|
|
|
$
|
—
|
|
|
$
|
1,550
|
|
|
|
(a)
|
The weighted average interest rate for borrowings under our Revolving Credit Facility was
3.31%
at
June 30, 2017
.
|
(b)
|
We are allowed to request that the loan availability be increased up to an aggregate of
$2.1 billion
, subject to receiving increased commitments from the lenders.
|
10
|
|
|
|
|
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
|
Partnership
|
|
Total
|
||||||||
|
Common
|
|
General Partner
|
|
|||||||
Balance at December 31, 2016
|
$
|
1,608
|
|
|
$
|
(66
|
)
|
|
$
|
1,542
|
|
Proceeds from issuance of units, net of issuance costs
|
281
|
|
|
6
|
|
|
287
|
|
|||
Distributions to unitholders and general partner (a)
|
(195
|
)
|
|
(85
|
)
|
|
(280
|
)
|
|||
Net earnings attributable to partners
|
125
|
|
|
77
|
|
|
202
|
|
|||
Contributions (b)
|
31
|
|
|
2
|
|
|
33
|
|
|||
Other
|
(2
|
)
|
|
5
|
|
|
3
|
|
|||
Balance at June 30, 2017
|
$
|
1,848
|
|
|
$
|
(61
|
)
|
|
$
|
1,787
|
|
(a)
|
Represents cash distributions declared and paid during the
six
months ended
June 30, 2017
, relating to the first quarter of 2017 and the fourth quarter of 2016.
|
(b)
|
Includes Andeavor and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.
|
|
|
June 30, 2017
|
11
|
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
Three Months Ended
June 30, |
|
Six Months Ended
June 30, |
||||||||||||
|
2017
|
|
2016
|
|
2017
|
|
2016
|
||||||||
Net earnings
|
$
|
110
|
|
|
$
|
76
|
|
|
$
|
202
|
|
|
$
|
161
|
|
Special allocations of net earnings (“Special Allocations”) (a)
|
—
|
|
|
—
|
|
|
1
|
|
|
—
|
|
||||
Net earnings, including Special Allocations
|
110
|
|
|
76
|
|
|
203
|
|
|
161
|
|
||||
General partner’s distributions
|
(3
|
)
|
|
(2
|
)
|
|
(6
|
)
|
|
(4
|
)
|
||||
General partner’s IDRs (b)
|
(39
|
)
|
|
(36
|
)
|
|
(75
|
)
|
|
(66
|
)
|
||||
Limited partners’ distributions on common units
|
(105
|
)
|
|
(85
|
)
|
|
(206
|
)
|
|
(161
|
)
|
||||
Distributions greater than earnings
|
$
|
(37
|
)
|
|
$
|
(47
|
)
|
|
$
|
(84
|
)
|
|
$
|
(70
|
)
|
General partner’s earnings:
|
|
|
|
|
|
|
|
||||||||
Distributions
|
$
|
3
|
|
|
$
|
2
|
|
|
$
|
6
|
|
|
$
|
4
|
|
General partner’s IDRs (b)
|
39
|
|
|
36
|
|
|
75
|
|
|
66
|
|
||||
Allocation of distributions greater than earnings (c)
|
—
|
|
|
(8
|
)
|
|
(1
|
)
|
|
(15
|
)
|
||||
Total general partner’s earnings
|
$
|
42
|
|
|
$
|
30
|
|
|
$
|
80
|
|
|
$
|
55
|
|
Limited partners’ earnings on common units:
|
|
|
|
|
|
|
|
||||||||
Distributions
|
$
|
105
|
|
|
$
|
85
|
|
|
$
|
206
|
|
|
$
|
161
|
|
Special Allocations (a)
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
—
|
|
||||
Allocation of distributions greater than earnings
|
(37
|
)
|
|
(39
|
)
|
|
(83
|
)
|
|
(55
|
)
|
||||
Total limited partners’ earnings on common units
|
$
|
68
|
|
|
$
|
46
|
|
|
$
|
122
|
|
|
$
|
106
|
|
Weighted average limited partner units outstanding:
|
|
|
|
|
|
|
|
||||||||
Common units - basic
|
108.0
|
|
|
95.2
|
|
|
106.4
|
|
|
94.4
|
|
||||
Common units - diluted
|
108.1
|
|
|
95.2
|
|
|
106.5
|
|
|
94.4
|
|
||||
Net earnings per limited partner unit:
|
|
|
|
|
|
|
|
||||||||
Common - basic
|
$
|
0.63
|
|
|
$
|
0.48
|
|
|
$
|
1.15
|
|
|
$
|
1.12
|
|
Common - diluted
|
$
|
0.63
|
|
|
$
|
0.48
|
|
|
$
|
1.15
|
|
|
$
|
1.12
|
|
(a)
|
Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using all cash on hand to fund the Alaska Storage and Terminalling Assets acquisition.
|
(b)
|
IDRs entitle the general partner to receive increasing percentages, up to
50%
, of quarterly distributions in excess of
$0.3881
per unit per quarter. The amount above reflects earnings distributed to our general partner net of
$12.5 million
and
$25 million
of IDRs waived by TLGP for the
three and six
months ended
June 30, 2017
, respectively. See Note 11 of our Annual Report on Form 10-K for the year ended
December 31, 2016
for further discussion related to IDRs.
|
(c)
|
We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of
$7 million
and
$14 million
for the
three and six
months ended
June 30, 2016
, respectively. There were
no
Predecessor losses for the
three and six
months ended
June 30, 2017
.
|
12
|
|
|
|
|
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
Quarter Ended
|
Quarterly Distribution Per Unit
|
|
Total Cash Distribution including general partner IDRs (in millions)
|
|
Date of Distribution
|
|
Unitholders Record Date
|
||||
December 31, 2016
|
$
|
0.910
|
|
|
$
|
140
|
|
|
February 14, 2017
|
|
February 3, 2017
|
March 31, 2017 (a)
|
0.940
|
|
|
140
|
|
|
May 15, 2017
|
|
May 5, 2017
|
||
June 30, 2017 (a)(b)
|
0.971
|
|
|
147
|
|
|
August 14, 2017
|
|
August 4, 2017
|
(a)
|
This distribution is net of
$12.5 million
of IDRs waived by TLGP for each of the
three
months ended
June 30, 2017
and March 31, 2017.
|
(b)
|
This distribution was declared on
July 19, 2017
and will be paid on the date of distribution.
|
|
|
June 30, 2017
|
13
|
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
|
|
Three Months Ended
June 30, |
|
Six Months Ended
June 30, |
||||||||||||
|
2017
|
|
2016
|
|
2017
|
|
2016
|
||||||||
Revenues
|
|
|
|
|
|
|
|
||||||||
Gathering and Processing:
|
|
|
|
|
|
|
|
||||||||
NGL sales
|
$
|
81
|
|
|
$
|
27
|
|
|
$
|
164
|
|
|
$
|
54
|
|
Gas gathering and processing
|
87
|
|
|
63
|
|
|
167
|
|
|
131
|
|
||||
Crude oil and water gathering
|
34
|
|
|
32
|
|
|
73
|
|
|
67
|
|
||||
Pass-thru and other
|
31
|
|
|
28
|
|
|
74
|
|
|
60
|
|
||||
Total Gathering and Processing
|
233
|
|
|
150
|
|
|
478
|
|
|
312
|
|
||||
Terminalling and Transportation:
|
|
|
|
|
|
|
|
||||||||
Terminalling
|
147
|
|
|
112
|
|
|
292
|
|
|
220
|
|
||||
Pipeline transportation
|
33
|
|
|
31
|
|
|
63
|
|
|
61
|
|
||||
Total Terminalling and Transportation
|
180
|
|
|
143
|
|
|
355
|
|
|
281
|
|
||||
Total Segment Revenues
|
$
|
413
|
|
|
$
|
293
|
|
|
$
|
833
|
|
|
$
|
593
|
|
|
|
|
|
|
|
|
|
||||||||
Segment Operating Income
|
|
|
|
|
|
|
|
||||||||
Gathering and Processing
|
$
|
51
|
|
|
$
|
55
|
|
|
$
|
113
|
|
|
$
|
119
|
|
Terminalling and Transportation
|
121
|
|
|
68
|
|
|
219
|
|
|
131
|
|
||||
Total Segment Operating Income
|
172
|
|
|
123
|
|
|
332
|
|
|
250
|
|
||||
Unallocated general and administrative expenses
|
(6
|
)
|
|
(5
|
)
|
|
(16
|
)
|
|
(13
|
)
|
||||
Interest and financing costs, net
|
(59
|
)
|
|
(45
|
)
|
|
(119
|
)
|
|
(89
|
)
|
||||
Equity in earnings of equity method investments
|
3
|
|
|
3
|
|
|
5
|
|
|
7
|
|
||||
Other income, net
|
—
|
|
|
—
|
|
|
—
|
|
|
6
|
|
||||
Net Earnings
|
$
|
110
|
|
|
$
|
76
|
|
|
$
|
202
|
|
|
$
|
161
|
|
|
|
|
|
|
|
|
|
||||||||
Capital Expenditures
|
|
|
|
|
|
|
|
||||||||
Gathering and Processing
|
$
|
21
|
|
|
$
|
29
|
|
|
$
|
39
|
|
|
$
|
59
|
|
Terminalling and Transportation
|
24
|
|
|
31
|
|
|
51
|
|
|
61
|
|
||||
Total Capital Expenditures
|
$
|
45
|
|
|
$
|
60
|
|
|
$
|
90
|
|
|
$
|
120
|
|
|
June 30,
2017 |
|
December 31,
2016 |
||||
Identifiable Assets
|
|
|
|
||||
Gathering and Processing
|
$
|
4,035
|
|
|
$
|
3,392
|
|
Terminalling and Transportation
|
1,778
|
|
|
1,768
|
|
||
Other (a)
|
26
|
|
|
700
|
|
||
Total Identifiable Assets
|
$
|
5,839
|
|
|
$
|
5,860
|
|
(a)
|
Other consists mainly of
$688 million
in cash and cash equivalents as of
December 31, 2016
, of which
$673 million
was used to fund the acquisition of the North Dakota Gathering and Processing Assets on January 1, 2017, increasing the Gathering and Processing segment’s identifiable assets as of
June 30, 2017
.
|
14
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
ITEM 2.
|
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
|
|
|
June 30, 2017
|
15
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
•
|
further expanding capacity and capabilities as well as adding new origin and destination points for our common carrier pipelines in North Dakota and Montana;
|
•
|
expanding our crude oil, natural gas and water gathering and associated gas processing footprint in the Bakken Shale/Williston Basin area of North Dakota and Montana (the “Bakken Region”) to enhance and improve overall basin logistics efficiencies;
|
•
|
increasing compression on our natural gas gathering systems in the Green River and Vermillion basins to enhance natural gas volumes recovered from existing wells and support potential new drilling activity;
|
•
|
expanding our gathering footprint and increase compression capabilities in the Uinta basin to increase volumes on our gathering systems and through our processing assets; and
|
•
|
pursuing strategic assets across the western U.S. including potential acquisitions from Andeavor.
|
•
|
increasing our terminalling volumes by expanding capacity and growing our third-party services at certain of our terminals;
|
•
|
optimizing Andeavor volumes and growing third-party throughput at our Terminalling and Transportation assets; and
|
•
|
pursuing strategic assets in the western U.S.
|
16
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
|
|
•
|
Average margin on NGL sales per barrel—calculated as the difference between the NGL sales and the costs associated with the NGL sales divided by total NGL sales volumes;
|
•
|
Average gas gathering and processing revenue per Million British thermal units (“MMBtu”)—calculated as total gathering and processing fee-based revenue divided by total gas gathering throughput;
|
•
|
Average crude oil and water gathering revenue per barrel—calculated as total crude oil and water gathering fee-based revenue divided by total crude oil and water gathering throughput;
|
•
|
Average terminalling revenue per barrel—calculated as total terminalling revenue divided by total terminalling throughput; and
|
•
|
Average pipeline transportation revenue per barrel—calculated as total pipeline transportation revenue divided by total pipeline transportation throughput.
|
•
|
Financial non-GAAP measure of earnings before interest, income taxes, and depreciation and amortization expenses (“EBITDA”); and
|
•
|
Liquidity non-GAAP measure of distributable cash flow, which is calculated as U.S. GAAP-based net cash flow from operating activities plus or minus changes in working capital, amounts spent on maintenance capital net of reimbursements and other adjustments not expected to settle in cash.
|
•
|
our operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard to historical cost basis or financing methods;
|
•
|
the ability of our assets to generate sufficient cash flow to make distributions to our unitholders;
|
•
|
our ability to incur and service debt and fund capital expenditures; and
|
•
|
the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.
|
|
|
June 30, 2017
|
17
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
18
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
Three Months Ended June 30,
|
||||||
|
2017
|
|
2016 (a)
|
||||
Net cash from operating activities
|
$
|
117
|
|
|
$
|
86
|
|
Changes in assets and liabilities
|
37
|
|
|
42
|
|
||
Predecessors impact
|
—
|
|
|
5
|
|
||
Maintenance capital expenditures (b)
|
(19
|
)
|
|
(14
|
)
|
||
Reimbursement for maintenance capital expenditures (b)
|
7
|
|
|
10
|
|
||
Proceeds from sale of assets
|
28
|
|
|
—
|
|
||
Other
|
7
|
|
|
(3
|
)
|
||
Distributable Cash Flow
|
$
|
177
|
|
|
$
|
126
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
We adjust our reconciliation of distributable cash flows for maintenance capital expenditures, tank restoration costs and expenditures required to ensure the safety, reliability, integrity and regulatory compliance of our assets with an offset for any reimbursements received for such expenditures.
|
|
|
June 30, 2017
|
19
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
20
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
Six Months Ended June 30,
|
||||||
|
2017
|
|
2016 (a)
|
||||
Net cash from operating activities
|
$
|
324
|
|
|
$
|
242
|
|
Changes in assets and liabilities
|
(12
|
)
|
|
31
|
|
||
Predecessors impact
|
—
|
|
|
10
|
|
||
Maintenance capital expenditures (b)
|
(36
|
)
|
|
(24
|
)
|
||
Reimbursement for maintenance capital expenditures (b)
|
15
|
|
|
14
|
|
||
Proceeds from sale of assets
|
28
|
|
|
—
|
|
||
Other
|
10
|
|
|
(5
|
)
|
||
Distributable Cash Flow
|
$
|
329
|
|
|
$
|
268
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
We adjust our reconciliation of distributable cash flows for maintenance capital expenditures, tank restoration costs and expenditures required to ensure the safety, reliability, integrity and regulatory compliance of our assets with an offset for any reimbursements received for such expenditures.
|
|
|
|
|
|
June 30, 2017
|
21
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
(a)
|
Volumes represent barrels sold in keep-whole arrangements, net barrels retained in POP arrangements and other associated products.
|
22
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
Three Months Ended June 30,
|
||||||
|
2017
|
|
2016
|
||||
Revenues
|
|
|
|
||||
NGL sales (a)
|
$
|
81
|
|
|
$
|
27
|
|
Gas gathering and processing
|
87
|
|
|
63
|
|
||
Crude oil and water gathering
|
34
|
|
|
32
|
|
||
Pass-thru and other
|
31
|
|
|
28
|
|
||
Total Revenues
|
233
|
|
|
150
|
|
||
Costs and Expenses
|
|
|
|
||||
Cost of NGL sales (a)
|
56
|
|
|
1
|
|
||
Operating expenses (b)
|
79
|
|
|
59
|
|
||
General and administrative expenses
|
10
|
|
|
9
|
|
||
Depreciation and amortization expenses
|
37
|
|
|
26
|
|
||
Gathering and Processing Segment Operating Income
|
$
|
51
|
|
|
$
|
55
|
|
Rates
|
|
|
|
||||
Average margin on NGL sales per barrel (a)
|
$
|
37.45
|
|
|
$
|
36.69
|
|
Average gas gathering and processing revenue per MMBtu
|
$
|
1.00
|
|
|
$
|
0.81
|
|
Average crude oil and water gathering revenue per barrel
|
$
|
1.55
|
|
|
$
|
1.72
|
|
(a)
|
For the
2017
Quarter, we had
20.9
Mbpd of gross NGL sales under POP and keep-whole arrangements. We retained
7.3
Mbpd under these arrangements. The difference between gross sales barrels and barrels retained is reflected in costs of NGL sales resulting from the gross presentation required for the POP arrangements associated with the North Dakota Gathering and Processing Assets.
|
(b)
|
Operating expenses include an imbalance settlement gain of
$1 million
for both the
2017
Quarter and
2016
Quarter, respectively.
|
|
|
June 30, 2017
|
23
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
(a)
|
Volumes represent barrels sold in keep-whole arrangements, net barrels retained in POP arrangements and other associated products.
|
|
Six Months Ended June 30,
|
||||||
|
2017
|
|
2016
|
||||
Revenues
|
|
|
|
||||
NGL sales (a)
|
$
|
164
|
|
|
$
|
54
|
|
Gas gathering and processing
|
167
|
|
|
131
|
|
||
Crude oil and water gathering
|
73
|
|
|
67
|
|
||
Pass-thru and other (b)
|
74
|
|
|
60
|
|
||
Total Revenues
|
478
|
|
|
312
|
|
||
Costs and Expenses
|
|
|
|
||||
Cost of NGL sales (a)(b)
|
115
|
|
|
1
|
|
||
Operating expenses (c)
|
156
|
|
|
122
|
|
||
General and administrative expenses
|
20
|
|
|
17
|
|
||
Depreciation and amortization expenses
|
74
|
|
|
52
|
|
||
Loss on asset disposals and impairments
|
—
|
|
|
1
|
|
||
Gathering and Processing Segment Operating Income
|
$
|
113
|
|
|
$
|
119
|
|
Rates
|
|
|
|
||||
Average margin on NGL sales per barrel (a)(b)
|
$
|
38.30
|
|
|
$
|
35.54
|
|
Average gas gathering and processing revenue per MMBtu
|
$
|
0.97
|
|
|
$
|
0.82
|
|
Average crude oil and water gathering revenue per barrel
|
$
|
1.64
|
|
|
$
|
1.74
|
|
(a)
|
For the
2017
Period, we had
21.0
Mbpd of gross NGL sales under POP and keep-whole arrangements. We retained
7.4
Mbpd under these arrangements. The difference between gross sales barrels and barrels retained is reflected in costs of NGL sales resulting from the gross presentation required for the POP arrangements associated with the North Dakota Gathering and Processing Assets.
|
(b)
|
Included in cost of NGL sales for the
2017
Period were approximately $2 million of cost of sales related to crude oil volumes obtained in connection with the North Dakota Gathering and Processing Assets acquisition. The corresponding revenues were recognized in pass-thru and other revenue. As such, the calculation of the average margin on NGL sales per barrel excludes this amount.
|
(c)
|
Operating expenses include an imbalance settlement gain of
$3 million
and
$1 million
for the
2017
Period and
2016
Period, respectively.
|
24
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
|
June 30, 2017
|
25
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
Three Months Ended June 30,
|
||||||
|
2017
|
|
2016 (a)
|
||||
Revenues
|
|
|
|
||||
Terminalling
|
$
|
147
|
|
|
$
|
112
|
|
Pipeline transportation
|
33
|
|
|
31
|
|
||
Total Revenues
|
180
|
|
|
143
|
|
||
Costs and Expenses
|
|
|
|
||||
Operating expenses (b)
|
53
|
|
|
48
|
|
||
General and administrative expenses
|
8
|
|
|
7
|
|
||
Depreciation and amortization expenses
|
23
|
|
|
20
|
|
||
Gain on asset disposals and impairments
|
(25
|
)
|
|
—
|
|
||
Terminalling and Transportation Segment Operating Income
|
$
|
121
|
|
|
$
|
68
|
|
Rates
|
|
|
|
||||
Average terminalling revenue per barrel
|
$
|
1.53
|
|
|
$
|
1.21
|
|
Average pipeline transportation revenue per barrel
|
$
|
0.40
|
|
|
$
|
0.40
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. Our Predecessors did not record revenue for transactions with Andeavor in the Terminalling and Transportation segment prior to the effective date of the acquisition of the Alaska Storage and Terminalling Assets and the Northern California Terminalling and Storage Assets.
|
(b)
|
Operating expenses include imbalance settlement gains of
$1 million
for both the
2017
Quarter and
2016
Quarter, respectively.
|
26
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
Six Months Ended June 30,
|
||||||
|
2017
|
|
2016 (a)
|
||||
Revenues
|
|
|
|
||||
Terminalling
|
$
|
292
|
|
|
$
|
220
|
|
Pipeline transportation
|
63
|
|
|
61
|
|
||
Total Revenues
|
355
|
|
|
281
|
|
||
Costs and Expenses
|
|
|
|
||||
Operating expenses (b)
|
102
|
|
|
95
|
|
||
General and administrative expenses
|
15
|
|
|
15
|
|
||
Depreciation and amortization expenses
|
44
|
|
|
40
|
|
||
Gain on asset disposals and impairments
|
(25
|
)
|
|
—
|
|
||
Terminalling and Transportation Segment Operating Income
|
$
|
219
|
|
|
$
|
131
|
|
Rates
|
|
|
|
||||
Average terminalling revenue per barrel
|
$
|
1.55
|
|
|
$
|
1.26
|
|
Average pipeline transportation revenue per barrel
|
$
|
0.40
|
|
|
$
|
0.40
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. Our Predecessors did not record revenue for transactions with Andeavor in the Terminalling and Transportation segment prior to the effective date of the acquisition of the Alaska Storage and Terminalling Assets and the Northern California Terminalling and Storage Assets.
|
(b)
|
Operating expenses include imbalance settlement gains of
$2 million
for both the
2017
Period and
2016
Period, respectively.
|
|
|
June 30, 2017
|
27
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
Debt, including current maturities:
|
June 30, 2017
|
|
December 31, 2016
|
||||
Credit facilities
|
$
|
50
|
|
|
$
|
330
|
|
Senior notes
|
3,770
|
|
|
3,770
|
|
||
Capital lease obligations
|
9
|
|
|
9
|
|
||
Total Debt
|
3,829
|
|
|
4,109
|
|
||
Unamortized Issuance Costs
|
(50
|
)
|
|
(55
|
)
|
||
Debt, Net of Unamortized Issuance Costs
|
3,779
|
|
|
4,054
|
|
||
Total Equity
|
1,787
|
|
|
1,542
|
|
||
Total Capitalization
|
$
|
5,566
|
|
|
$
|
5,596
|
|
|
Total
Capacity
|
|
Amount Borrowed as of June 30, 2017
|
|
Available Capacity
|
|
Weighted Average Interest Rate
|
|
Expiration
|
|||||||
Revolving Credit Facility
|
$
|
600
|
|
|
$
|
50
|
|
|
$
|
550
|
|
|
3.31
|
%
|
|
January 29, 2021
|
Dropdown Credit Facility
|
1,000
|
|
|
—
|
|
|
1,000
|
|
|
—
|
%
|
|
January 29, 2021
|
|||
Total Credit Facilities
|
$
|
1,600
|
|
|
$
|
50
|
|
|
$
|
1,550
|
|
|
|
|
|
Credit Facility
|
30 day Eurodollar (LIBOR) Rate at June 30, 2017
|
|
Eurodollar Margin
|
|
Base Rate
|
|
Base Rate Margin
|
|
Commitment Fee
(unused portion)
|
Revolving Credit Facility (a)
|
1.74%
|
|
2.25%
|
|
4.25%
|
|
1.25%
|
|
0.375%
|
Dropdown Credit Facility (a)
|
1.74%
|
|
2.26%
|
|
4.25%
|
|
1.26%
|
|
0.375%
|
(a)
|
We have the option to elect if the borrowings will bear interest at a base rate plus the base rate margin, or a Eurodollar rate, for the applicable period, plus the Eurodollar margin at the time of the borrowing. The applicable margin varies based upon a certain leverage ratio, as defined by the Revolving Credit Facility. We also incur commitment fees for the unused portion of the Revolving Credit Facility at an annual rate. Letters of credit outstanding under the Revolving Credit Facility incur fees at the Eurodollar margin rate.
|
28
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
Six Months Ended June 30,
|
||||||
|
2017
|
|
2016
|
||||
Cash Flows From (Used in):
|
|
|
|
||||
Operating activities
|
$
|
324
|
|
|
$
|
242
|
|
Investing activities
|
(731
|
)
|
|
(178
|
)
|
||
Financing activities
|
(261
|
)
|
|
602
|
|
||
Increase (Decrease) in Cash and Cash Equivalents
|
$
|
(668
|
)
|
|
$
|
666
|
|
|
|
June 30, 2017
|
29
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
|
|
•
|
changes in global economic conditions on our business, on the business of our key customers, including Andeavor, and on our customers’ suppliers, business partners and credit lenders;
|
•
|
a material change in the crude oil and natural gas produced in the Bakken Shale/Williston Basin area of North Dakota and Montana or the Green River Basin, Uinta Basin and Vermillion Basin in the states of Utah, Colorado and Wyoming;
|
•
|
the ability of our key customers, including Andeavor, to remain in compliance with the terms of their outstanding indebtedness;
|
•
|
changes in insurance markets impacting costs and the level and types of coverage available;
|
•
|
changes in the cost or availability of third-party vessels, pipelines and other means of delivering and transporting crude oil, feedstocks, natural gas, NGLs and refined products;
|
•
|
the coverage and ability to recover claims under our insurance policies;
|
•
|
the availability and costs of crude oil, other refinery feedstocks and refined products;
|
•
|
the timing and extent of changes in commodity prices and demand for refined products, natural gas and NGLs;
|
•
|
changes in our cash flow from operations;
|
•
|
impact of QEP Resources’ and Questar Gas Company’s ability to perform under the terms of our gathering agreements as they are the largest customers in our natural gas business.
|
•
|
the risk of contract cancellation, non-renewal or failure to perform by those in our supply and distribution chains, including Andeavor and Andeavor’s customers, and the ability to replace such contracts and/or customers;
|
•
|
the suspension, reduction or termination of Andeavor’s obligations under our commercial agreements and our secondment agreement;
|
•
|
a material change in profitability among our customers, including Andeavor;
|
•
|
direct or indirect effects on our business resulting from actual or threatened terrorist or activist incidents, cyber-security breaches or acts of war;
|
•
|
weather conditions, earthquakes or other natural disasters affecting operations by us or our key customers, including Andeavor, or the areas in which our customers operate;
|
•
|
disruptions due to equipment interruption or failure at our facilities, Andeavor’s facilities or third-party facilities on which our key customers, including Andeavor, are dependent;
|
•
|
our inability to complete acquisitions on economically acceptable terms or within anticipated timeframes;
|
•
|
changes in the expected value of and benefits derived from acquisitions;
|
•
|
actions of customers and competitors;
|
•
|
changes in our credit profile;
|
•
|
state and federal environmental, economic, health and safety, energy and other policies and regulations, including those related to climate change and any changes therein and any legal or regulatory investigations, delays in obtaining necessary approvals and permits, compliance costs or other factors beyond our control;
|
•
|
operational hazards inherent in refining and natural gas processing operations and in transporting and storing crude oil, natural gas, NGLs and refined products;
|
•
|
changes in capital requirements or in execution and benefits of planned capital projects;
|
•
|
seasonal variations in demand for natural gas and refined products;
|
•
|
adverse rulings, judgments, or settlements in litigation or other legal or tax matters, including unexpected environmental remediation costs in excess of any accruals, which affect us or Andeavor;
|
•
|
risks related to labor relations and workplace safety;
|
30
|
|
|
|
|
MANAGEMENT’S DISCUSSION AND ANALYSIS
|
|
•
|
political developments; and
|
•
|
the factors described in greater detail under “Competition” and “Risk Factors” in Items 1 and 1A of our Annual Report
|
ITEM 3.
|
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
|
ITEM 4.
|
CONTROLS AND PROCEDURES
|
|
|
June 30, 2017
|
31
|
LEGAL PROCEEDINGS, RISK FACTORS AND UNREGISTERED SHARES OF EQUITY SECURITIES
|
ITEM 1.
|
LEGAL PROCEEDINGS
|
ITEM 1A.
|
RISK FACTORS
|
ITEM 2.
|
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
|
32
|
|
|
|
|
EXHIBITS
|
ITEM 6.
|
EXHIBITS
|
|
|
|
|
Incorporated by Reference (File No. 1-35143, unless otherwise indicated)
|
||||
Exhibit Number
|
|
Description of Exhibit
|
|
Form
|
|
Exhibit
|
|
Filing Date
|
3.1
|
|
|
8-K
|
|
3.1
|
|
8/1/2017
|
|
|
|
|
|
|
|
|
|
|
3.2
|
|
|
S-1
(File No. 333-171525)
|
|
3.3
|
|
1/4/2011
|
|
|
|
|
|
|
|
|
|
|
3.3
|
|
|
8-K
|
|
3.2
|
|
8/1/2017
|
|
|
|
|
|
|
|
|
|
|
3.4
|
|
|
10-Q
|
|
3.4
|
|
5/9/2017
|
|
|
|
|
|
|
|
|
|
|
*10.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*31.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*31.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*32.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*32.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
**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
|
**
|
Submitted electronically herewith
|
|
|
June 30, 2017
|
33
|
|
|
ANDEAVOR LOGISTICS LP
|
|
|
|
|
|
|
|
By:
|
Tesoro Logistics GP, LLC
|
|
|
|
Its general partner
|
|
|
|
|
Date:
|
August 9, 2017
|
By:
|
/s/ STEVEN M. STERIN
|
|
|
|
Steven M. Sterin
|
|
|
|
President and Chief Financial Officer
|
|
|
|
(Principal Financial Officer and Duly Authorized Officer)
|
34
|
|
|
|
|
(i)
|
a Monthly per mile adjustment to the mileage rate components of the Trucking Rate to cover any increase in fuel prices (as determined by reference to the U.S. Energy Information Administration’s On-Highway Diesel Prices for the Rocky Mountain Region against a baseline of January 2017) incurred or experienced by TLO in connection with providing Truck Gathering Services under this Agreement; and
|
(ii)
|
a Monthly surcharge on the services provided hereunder to cover TRMC's proportionate share of the increased costs of complying with any new laws or regulations that affect the services provided to TRMC, if after TLO has made commercially reasonable efforts to mitigate the effect of such laws or regulations, such new laws or regulations require TLO to make substantial and unanticipated capital expenditures. Any such Monthly surcharge shall be set forth in a Trucking Service Order. If the Monthly surcharge increases rates on deliveries of crude oil by over 15% from the
|
(i)
|
Actual costs of any capital expenditures TLO or THPP agrees to make at TRMC’s request pursuant to a Trucking Service Order to provide additional Truck Gathering Services hereunder, other than capital expenditures required for TLO (A) to continue to provide those Truck Gathering Services specified hereunder or (B) to handle the Minimum Volume Commitment increases specified herein; and
|
(ii)
|
All taxes (other than income taxes, gross receipt taxes and similar taxes) that TLO incurs on TRMC’s behalf for the services TLO provides to TRMC under this Agreement or any Trucking Service Order, if such reimbursement is not prohibited by law.
|
|
For legal notices
:
|
|
|
|
|
|
Attention: General Counsel
fax: (210) 745-4649
with a copy to:
logisticslegal@tsocorp.com
|
|
|
|
|
|
|
|
|
TESORO REFINING & MARKETING COMPANY LLC
|
|
|
|
|
|
By:
|
|
|
|
|
|
|
|
|
TESORO LOGISTICS OPERATIONS LLC
|
|
|
|
|
|
By:
|
|
Location
|
Storage Tanks
|
Putnam
|
Three 400 bbl tanks
|
Sidney
|
Two 400 bbl tanks
|
Alexander
|
Two 400 bbl tanks
|
Cartwright
|
One 5,000 bbl tank
|
Treetop
|
Three 400 bbl tanks
|
Little Knife
|
One 10,000 bbl tank
|
Connolly
|
Four 400 bbl tanks
|
Keene
|
Two Lane unloading facility
|
Blue Buttes
|
Three 400 bbl tanks
|
Tioga
|
Three 400 bbl tanks
|
Lignite
|
Three 400 bbl tanks
|
Charlson
|
Three 400 bbl tank
|
TESORO REFINING & MARKETING COMPANY LLC
|
||
|
|
|
|
|
|
By:
|
|
|
|
Name
|
|
|
Title
|
|
|
|
|
TESORO LOGISTICS OPERATIONS LLC
|
||
|
|
|
|
|
|
By:
|
|
|
|
Name
|
|
|
Title
|
|
(i)
|
Workers Compensation and Occupational Disease Insurance which fully complies with Applicable Law of the state where the gathering operations are located, in limits not less than statutory requirements;
|
(ii)
|
Employers Liability Insurance with a minimum limit of $1,000,000 for each accident, covering injury or death to any employee which may be outside the scope of the worker’s compensation statute of the jurisdiction in which the worker’s service is performed, and in the aggregate as respects occupational disease;
|
(iii)
|
Commercial General Liability Insurance, including contractual liability insurance covering Carrier’s indemnity obligations under this Agreement, with minimum limits of $1,000,000 combined single limit per occurrence for bodily injury and property damage liability, or such higher limits as may be required by TRMC or by Applicable Law from time to time. This policy shall include Broad Form Contractual Liability insurance coverage which shall specifically apply to the obligations assumed in this Agreement by TLO;
|
(iv)
|
Automobile Liability Insurance covering all owned, non-owned and hired vehicles, with minimum limits of $1,000,000 combined single limit per occurrence for bodily injury and property damage liability, or such higher limit(s) as may be required by TLO or by Applicable Law from time to time. Coverage must assure compliance with Sections 29 and 30 of the Motor Carrier Act of 1980 and all applicable rules and regulations of the Federal Highway Administration’s Bureau of Motor Carrier Safety and Interstate Commerce Commissioner (Form MCS 90 Endorsement). Limits of liability for this insurance must be in accordance with the financial responsibility requirement of the Motor Carrier Act, but not less than $1,000,000 per occurrence;
|
(v)
|
Excess (Umbrella) Liability Insurance with limits not less than $4,000,000 per occurrence. Additional excess limits may be utilized to supplement inadequate limits in the primary policies required in items (ii), (iii), and (iv) above;
|
(vii)
|
Property Insurance, with a limit of no less than $1,000,000, which property insurance shall be first-party property insurance to adequately cover TLO’s owned property; including personal property of others.
|
1.
|
I have reviewed this
quarterly
Report on Form
10-Q
of Andeavor Logistics LP;
|
2.
|
Based on my knowledge, this
quarterly
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
quarterly
report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this
quarterly
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
quarterly
report;
|
4.
|
The registrant’s other certifying officer 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 15(d)-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
quarterly
report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal controls 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
quarterly
report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this
quarterly
report based on such evaluation; and
|
(d)
|
Disclosed in this
quarterly
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 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 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.
|
Date:
|
August 9, 2017
|
/s/ GREGORY J. GOFF
|
|
|
Gregory J. Goff
|
|
|
Chief Executive Officer of Tesoro Logistics GP, LLC
|
|
|
(the general partner of Andeavor Logistics LP)
|
1.
|
I have reviewed this
quarterly
Report on Form
10-Q
of Andeavor Logistics LP;
|
2.
|
Based on my knowledge, this
quarterly
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
quarterly
report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this
quarterly
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
quarterly
report;
|
4.
|
The registrant’s other certifying officer 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 15(d)-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
quarterly
report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal controls 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
quarterly
report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this
quarterly
report based on such evaluation; and
|
(d)
|
Disclosed in this
quarterly
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 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 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
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(b)
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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.
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Date:
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August 9, 2017
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/s/ STEVEN M. STERIN
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Steven M. Sterin
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Chief Financial Officer of Tesoro Logistics GP, LLC
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(the general partner of Andeavor Logistics LP)
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(1)
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The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
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(2)
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The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
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/s/ GREGORY J. GOFF
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Gregory J. Goff
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Chief Executive Officer of Tesoro Logistics GP, LLC
(the general partner of Andeavor Logistics LP)
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|||
August 9, 2017
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(1)
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The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
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(2)
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The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
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/s/ STEVEN M. STERIN
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|||
Steven M. Sterin
|
|||
Chief Financial Officer of Tesoro Logistics GP, LLC
(the general partner of Andeavor Logistics LP)
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|||
August 9, 2017
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