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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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o
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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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200 East Hardin Street, Findlay, Ohio 45840
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(Address of principal executive offices) (Zip Code)
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419-421-2414
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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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o
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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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Note 2 - Acquisitions
and Divestitures
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2
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Financial Statements
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Three Months Ended
September 30, |
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Nine Months Ended
September 30, |
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2018 (a)
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2017 (a)
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2018 (a)
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2017 (a)
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(In millions, except per unit amounts)
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Revenues: (b)
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Affiliate
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$
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415
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$
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468
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$
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1,131
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$
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951
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Third-party
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227
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626
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626
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1,184
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Total Revenues
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642
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1,094
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1,757
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2,135
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Costs and Expenses:
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Cost of fuel and other (excluding items shown separately below) (b)
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—
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554
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—
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716
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NGL expense (excluding items shown separately below)
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73
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64
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166
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179
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Operating expenses (excluding depreciation and amortization)
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236
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199
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658
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512
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Depreciation and amortization expenses
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86
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85
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268
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222
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General and administrative expenses
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31
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44
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91
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107
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Loss (gain) on asset disposals and impairments
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1
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1
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2
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(25
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)
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Operating Income
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215
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147
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572
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424
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Interest and financing costs, net
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(57
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)
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(68
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)
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(172
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)
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(193
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)
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Equity in earnings of equity method investments
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7
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6
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25
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13
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Other income, net
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1
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5
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4
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9
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Net Earnings
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$
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166
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$
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90
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$
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429
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$
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253
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Loss attributable to Predecessors
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$
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4
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$
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7
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$
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28
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$
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46
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Net Earnings Attributable to Partners
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170
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97
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457
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299
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Preferred unitholders’ interest in net earnings
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(10
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)
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—
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(34
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)
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—
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General partner’s interest in net earnings, including incentive distribution rights
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—
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—
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—
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(79
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)
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Limited Partners’ Interest in Net Earnings
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$
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160
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$
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97
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$
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423
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$
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220
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Net earnings per limited partner unit
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Common - basic
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$
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0.68
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$
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0.90
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$
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1.91
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$
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2.05
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Common - diluted
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$
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0.68
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$
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0.90
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$
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1.91
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$
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2.05
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Weighted average limited partner units outstanding
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Common units - basic
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234.4
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108.0
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223.0
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107.0
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Common units - diluted
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234.6
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108.1
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223.2
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107.1
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Cash distributions paid per unit
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$
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1.030
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$
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0.971
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$
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3.045
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$
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2.821
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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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(b)
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Due to the adoption of the revenue recognition standard effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the three and nine months ended September 30, 2018 were netted. See Note 1 for further discussion.
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September 30, 2018
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3
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Financial Statements
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September 30,
2018 |
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December 31, 2017 (a)
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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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30
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$
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75
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Receivables, net of allowance for doubtful accounts
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Trade and other
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250
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219
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Affiliate
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251
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264
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Prepayments and other current assets
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81
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27
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Total Current Assets
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612
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585
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Property, Plant and Equipment, Net
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Property, plant and equipment, at cost
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7,965
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7,243
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Accumulated depreciation
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(1,215
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)
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(994
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)
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Property, Plant and Equipment, Net
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6,750
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6,249
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Acquired Intangibles, Net
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1,116
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1,154
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Goodwill
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988
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956
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Equity Method Investments
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607
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440
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Other Noncurrent Assets, Net
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124
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121
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Total Assets
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$
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10,197
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$
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9,505
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Liabilities and Equity
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Current Liabilities
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Accounts payable
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Trade and other
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$
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201
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$
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186
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Affiliate
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254
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207
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Accrued interest and financing costs
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68
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40
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Other current liabilities
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81
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85
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Total Current Liabilities
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604
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518
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Debt, Net of Unamortized Issuance Costs
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4,829
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4,127
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Other Noncurrent Liabilities
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77
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54
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Total Liabilities
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5,510
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4,699
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Commitments and Contingencies (Note 8)
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Equity
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Equity of Predecessors
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—
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1,292
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Preferred unitholders;
600,000
units issued and outstanding in 2018 and 2017
|
594
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589
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Common unitholders;
245,472,743
units issued and outstanding (217,097,057 in 2017)
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4,093
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2,925
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Total Equity
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4,687
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4,806
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Total Liabilities and Equity
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$
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10,197
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$
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9,505
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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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4
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Financial Statements
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Nine Months Ended
September 30, |
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2018 (a)
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2017 (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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429
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$
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253
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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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268
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|
|
222
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Loss (gain) on asset disposals and impairments
|
2
|
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(25
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)
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Other operating activities
|
27
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23
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Changes in current assets and liabilities
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4
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62
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Changes in noncurrent assets and liabilities
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(11
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)
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(11
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)
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Net cash from operating activities
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719
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524
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Cash Flows From (Used In) Investing Activities
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Capital expenditures
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(566
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)
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|
(220
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)
|
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Acquisitions, net of cash
|
(379
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)
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|
(1,230
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)
|
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Proceeds from sales of assets
|
—
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|
|
46
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|
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Net cash used in investing activities
|
(945
|
)
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|
(1,404
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)
|
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Cash Flows From (Used In) Financing Activities
|
|
|
|
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Borrowings under revolving credit agreements
|
1,030
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|
319
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Repayments under revolving credit agreements
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(333
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)
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(614
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)
|
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Proceeds from issuance of common units, net of issuance costs
|
—
|
|
|
284
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|
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Proceeds from issuance of general partner units, net of issuance costs
|
—
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|
|
6
|
|
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Quarterly distributions to common unitholders
|
(620
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)
|
|
(329
|
)
|
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Quarterly distributions to general partner
|
—
|
|
|
(131
|
)
|
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Distributions to preferred unitholders
|
(29
|
)
|
|
—
|
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Distributions in connection with acquisitions
|
(300
|
)
|
|
(5
|
)
|
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Sponsor contributions of equity to the Predecessors
|
406
|
|
|
678
|
|
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Capital contributions by affiliate
|
27
|
|
|
24
|
|
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Other financing activities
|
—
|
|
|
(2
|
)
|
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Net cash from financing activities
|
181
|
|
|
230
|
|
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Decrease in Cash and Cash Equivalents
|
(45
|
)
|
|
(650
|
)
|
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Cash and Cash Equivalents, Beginning of Period
|
75
|
|
|
688
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Cash and Cash Equivalents, End of Period
|
$
|
30
|
|
|
$
|
38
|
|
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|
September 30, 2018
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5
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Notes to Condensed Consolidated Financial Statements (Unaudited)
|
6
|
|
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Notes to Condensed Consolidated Financial Statements (Unaudited)
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|
September 30, 2018
|
7
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Notes to Condensed Consolidated Financial Statements (Unaudited)
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8
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Notes to Condensed Consolidated Financial Statements (Unaudited)
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•
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Crude oil and other feedstock storage tankage and refined product storage tankage at Andeavor’s Mandan, Salt Lake City and Los Angeles refineries;
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•
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Rail terminals and truck racks at Andeavor’s Mandan, Salt Lake City and Los Angeles refineries for the loading and unloading of various refined products from manifest and other railcars and trucks, respectively;
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•
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Interconnecting pipeline facilities in the Los Angeles area as well as other railroad tracks and adjoining lands;
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•
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Mesquite and Yucca truck unloading stations in New Mexico for the unloading of crude trucks and injection of crude into the TexNewMex pipeline;
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•
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Mason East and Jackrabbit (“Wink”) truck unloading and injection stations in Texas that receive crude via the T-Station line and trucks for injection into the Kinder Morgan and Bobcat Pipeline;
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•
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The Jal storage, injection and rail unloading facility in New Mexico that stores and supplies natural gas liquids for use in Andeavor’s El Paso refinery;
|
•
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Natural gas liquid storage tankage, a rail and truck terminal for the loading and unloading of natural gas liquids from railcars and trucks as well as from the waterline at the Wingate facility in New Mexico;
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•
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Crude oil and other feedstock storage tankage at the Clearbrook terminal in Minnesota;
|
•
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Bobcat Pipeline that transports crude oil between the Mason East Station and the Wink Station;
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•
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Benny Pipeline that delivers crude oil from the Conan terminal in Texas to a connection with gathering lines in New Mexico;
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•
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All of the issued and outstanding limited liability company interests in: (i) Tesoro Great Plains Midstream LLC, which owns BakkenLink Pipeline LLC, (ii) Andeavor MPL Holdings LLC, which holds the investment in MPL, (iii) Andeavor Logistics CD LLC, (iv) Western Refining Conan Gathering, LLC, which owns the Conan Crude Oil Gathering System (v) Western Refining Delaware Basin Storage, LLC, (vi) Asphalt Terminals LLC, which holds the investment in PNAC, and (vii)
67%
of all of the issued and outstanding limited liability company interests in ALRP; and
|
•
|
Certain related real property interests.
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|
September 30, 2018
|
9
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
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Cash
|
$
|
22
|
|
Receivables
|
112
|
|
|
Inventories
|
11
|
|
|
Prepayments and Other Current Assets
|
25
|
|
|
Property, Plant and Equipment (a)
|
1,357
|
|
|
Goodwill
|
558
|
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Acquired Intangibles
|
130
|
|
|
Other Noncurrent Assets
|
2
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Accounts Payable
|
(167
|
)
|
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Accrued Liabilities
|
(41
|
)
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Debt
|
(347
|
)
|
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Total purchase price
|
$
|
1,662
|
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(a)
|
Estimated useful lives ranging from
3
to
22
years have been assumed based on the valuation.
|
10
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
||||
|
September 30, 2017
|
|
September 30, 2017
|
||||
Revenues
|
$
|
1,094
|
|
|
$
|
3,172
|
|
Net earnings (a)
|
90
|
|
|
258
|
|
(a)
|
While many recurring adjustments impact the pro forma figures presented, the pro forma condensed statements of consolidated operations for the
three and nine
months ended
September 30, 2017
includes a significant non-recurring adjustment to recognize the WNRL Merger acquisition and integration costs and reflects these costs in the first quarter of 2017, the period the acquisition was assumed to be completed for pro forma purposes. For the
nine
months ended
September 30, 2017
, we recognized acquisition costs related to the WNRL Merger of
$17 million
as well as
$3 million
of severance costs.
|
|
Three Months Ended September 30, 2018
|
|
Nine Months Ended September 30, 2018
|
||||||||||||||||||||
|
Combined
|
|
Andeavor Logistics LP
|
|
Predecessors
|
|
Combined
|
|
Andeavor Logistics LP
|
|
Predecessors
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Revenues
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Affiliate
|
$
|
415
|
|
|
$
|
411
|
|
|
$
|
4
|
|
|
$
|
1,131
|
|
|
$
|
1,110
|
|
|
$
|
21
|
|
Third-party
|
227
|
|
|
224
|
|
|
3
|
|
|
626
|
|
|
617
|
|
|
9
|
|
||||||
Total Revenues
|
642
|
|
|
635
|
|
|
7
|
|
|
1,757
|
|
|
1,727
|
|
|
30
|
|
||||||
Costs and Expenses
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
NGL expense (exclusive of items shown separately below)
|
73
|
|
|
73
|
|
|
—
|
|
|
166
|
|
|
166
|
|
|
—
|
|
||||||
Operating expenses (exclusive of depreciation and amortization)
|
236
|
|
|
227
|
|
|
9
|
|
|
658
|
|
|
618
|
|
|
40
|
|
||||||
Depreciation and amortization expenses
|
86
|
|
|
83
|
|
|
3
|
|
|
268
|
|
|
246
|
|
|
22
|
|
||||||
General and administrative expenses
|
31
|
|
|
30
|
|
|
1
|
|
|
91
|
|
|
82
|
|
|
9
|
|
||||||
Loss on asset disposals and impairments
|
1
|
|
|
1
|
|
|
—
|
|
|
2
|
|
|
2
|
|
|
—
|
|
||||||
Operating Income (Loss)
|
215
|
|
|
221
|
|
|
(6
|
)
|
|
572
|
|
|
613
|
|
|
(41
|
)
|
||||||
Interest and financing costs, net
|
(57
|
)
|
|
(56
|
)
|
|
(1
|
)
|
|
(172
|
)
|
|
(168
|
)
|
|
(4
|
)
|
||||||
Equity in earnings of equity method investments
|
7
|
|
|
4
|
|
|
3
|
|
|
25
|
|
|
9
|
|
|
16
|
|
||||||
Other income, net
|
1
|
|
|
1
|
|
|
—
|
|
|
4
|
|
|
3
|
|
|
1
|
|
||||||
Net Earnings (Loss)
|
$
|
166
|
|
|
$
|
170
|
|
|
$
|
(4
|
)
|
|
$
|
429
|
|
|
$
|
457
|
|
|
$
|
(28
|
)
|
Loss attributable to Predecessors
|
4
|
|
|
—
|
|
|
4
|
|
|
28
|
|
|
—
|
|
|
28
|
|
||||||
Net Earnings Attributable to Partners
|
170
|
|
|
170
|
|
|
—
|
|
|
457
|
|
|
457
|
|
|
—
|
|
||||||
Preferred unitholders’ interest in net earnings
|
(10
|
)
|
|
(10
|
)
|
|
—
|
|
|
(34
|
)
|
|
(34
|
)
|
|
—
|
|
||||||
Limited Partners’ Interest in Net Earnings
|
$
|
160
|
|
|
$
|
160
|
|
|
$
|
—
|
|
|
$
|
423
|
|
|
$
|
423
|
|
|
$
|
—
|
|
|
|
September 30, 2018
|
11
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
Three Months Ended September 30, 2017
|
|
Nine Months Ended September 30, 2017
|
||||||||||||||||||||
|
Combined
|
|
Andeavor Logistics LP
|
|
Predecessors
|
|
Combined
|
|
Andeavor Logistics LP
|
|
Predecessors
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Revenues
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Affiliate
|
$
|
468
|
|
|
$
|
219
|
|
|
$
|
249
|
|
|
$
|
951
|
|
|
$
|
624
|
|
|
$
|
327
|
|
Third-party
|
626
|
|
|
225
|
|
|
401
|
|
|
1,184
|
|
|
653
|
|
|
531
|
|
||||||
Total Revenues
|
1,094
|
|
|
444
|
|
|
650
|
|
|
2,135
|
|
|
1,277
|
|
|
858
|
|
||||||
Costs and Expenses
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Cost of fuel and other (exclusive of items shown separately below) (a)
|
554
|
|
|
—
|
|
|
554
|
|
|
716
|
|
|
—
|
|
|
716
|
|
||||||
NGL expense (exclusive of items shown separately below)
|
64
|
|
|
64
|
|
|
—
|
|
|
179
|
|
|
179
|
|
|
—
|
|
||||||
Operating expenses (exclusive of depreciation and amortization)
|
199
|
|
|
141
|
|
|
58
|
|
|
512
|
|
|
399
|
|
|
113
|
|
||||||
Depreciation and amortization expenses
|
85
|
|
|
60
|
|
|
25
|
|
|
222
|
|
|
178
|
|
|
44
|
|
||||||
General and administrative expenses
|
44
|
|
|
27
|
|
|
17
|
|
|
107
|
|
|
78
|
|
|
29
|
|
||||||
(Gain) loss on asset disposals and impairments
|
1
|
|
|
1
|
|
|
—
|
|
|
(25
|
)
|
|
(24
|
)
|
|
(1
|
)
|
||||||
Operating Income (Loss)
|
147
|
|
|
151
|
|
|
(4
|
)
|
|
424
|
|
|
467
|
|
|
(43
|
)
|
||||||
Interest and financing costs, net
|
(68
|
)
|
|
(61
|
)
|
|
(7
|
)
|
|
(193
|
)
|
|
(184
|
)
|
|
(9
|
)
|
||||||
Equity in earnings of equity method investments
|
6
|
|
|
2
|
|
|
4
|
|
|
13
|
|
|
7
|
|
|
6
|
|
||||||
Other income, net
|
5
|
|
|
5
|
|
|
—
|
|
|
9
|
|
|
9
|
|
|
—
|
|
||||||
Net Earnings (Loss)
|
$
|
90
|
|
|
$
|
97
|
|
|
$
|
(7
|
)
|
|
$
|
253
|
|
|
$
|
299
|
|
|
$
|
(46
|
)
|
Loss attributable to Predecessors
|
7
|
|
|
—
|
|
|
7
|
|
|
46
|
|
|
—
|
|
|
46
|
|
||||||
Net Earnings Attributable to Partners
|
97
|
|
|
97
|
|
|
—
|
|
|
299
|
|
|
299
|
|
|
—
|
|
||||||
General partner’s interest in net earnings, including incentive distribution rights
|
—
|
|
|
—
|
|
|
—
|
|
|
(79
|
)
|
|
(79
|
)
|
|
—
|
|
||||||
Limited Partners’ Interest in Net Earnings
|
$
|
97
|
|
|
$
|
97
|
|
|
$
|
—
|
|
|
$
|
220
|
|
|
$
|
220
|
|
|
$
|
—
|
|
12
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
|
|
|
|
Termination Provisions
|
|
Commercial Agreement
|
Initiation Date
|
Term
|
Renewals
|
Refinery Shutdown Notice Period (a)
|
Force Majeure
|
Transportation Services Agreement (LAR Interconnecting Pipelines)
|
August 2018
|
10 years
|
2 x 5 years
|
12 months
|
Andeavor Logistics can declare (unilateral)
|
Master Terminalling Services Agreement
|
August 2018
|
10 years
|
2 x 5 years
|
||
Master Unloading and Storage Agreement (WNRL)
|
August 2018
|
10 years
|
2 x 5 years
|
N/A
|
|
Asphalt Terminalling, Transportation and Storage Services Agreement
|
August 2018
|
10 years
|
2 x 5 years
|
(a)
|
Fixed minimum volumes remain in effect during routine turnarounds.
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Revenues (a)
|
$
|
415
|
|
|
$
|
468
|
|
|
$
|
1,131
|
|
|
$
|
951
|
|
Operating expenses (b)
|
82
|
|
|
67
|
|
|
216
|
|
|
185
|
|
||||
General and administrative expenses
|
31
|
|
|
30
|
|
|
77
|
|
|
77
|
|
|
|
September 30, 2018
|
13
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
(a)
|
Andeavor accounted for
65%
and
43%
of our total revenues for the
three
months ended
September 30, 2018
and
2017
, respectively, and
64%
and
45%
for the
nine
months ended
September 30, 2018
and
2017
, respectively.
|
(b)
|
Net of reimbursements from Andeavor pursuant to the Amended Omnibus Agreement, the Carson Assets Indemnity Agreement and other affiliate agreements of
$2 million
and
$7 million
for the
three
months ended
September 30, 2018
and
2017
respectively, and
$12 million
for both the
nine
months ended
September 30, 2018
and
2017
.
|
|
September 30,
2018 |
|
December 31, 2017 (a)
|
||||
Terminals and tankage
|
$
|
3,595
|
|
|
$
|
3,557
|
|
Pipelines
|
3,344
|
|
|
2,825
|
|
||
Land and leasehold improvements
|
289
|
|
|
282
|
|
||
Buildings and improvements
|
94
|
|
|
91
|
|
||
Other
|
142
|
|
|
142
|
|
||
Construction in progress
|
501
|
|
|
346
|
|
||
Property, Plant and Equipment, at Cost
|
7,965
|
|
|
7,243
|
|
||
Accumulated Depreciation
|
(1,215
|
)
|
|
(994
|
)
|
||
Property, Plant and Equipment, Net
|
$
|
6,750
|
|
|
$
|
6,249
|
|
(a)
|
Property, plant and equipment transferred to the Partnership in the 2018 Drop Down was recorded at historical costs. The Partnership recorded property, plant and equipment of
$948 million
and accumulated depreciation of
$112 million
as of December 31, 2017 in connection with the 2018 Drop Down.
|
|
September 30,
2018 |
|
December 31, 2017 (a)
|
||||
Terminalling and Transportation (b)
|
$
|
231
|
|
|
$
|
260
|
|
Gathering and Processing (b)
|
695
|
|
|
607
|
|
||
Wholesale
|
62
|
|
|
89
|
|
||
Goodwill
|
$
|
988
|
|
|
$
|
956
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
|
(b)
|
Goodwill transferred to the Partnership in the 2018 Drop Down was recorded at historical cost. We recorded goodwill of
$39 million
and
$225 million
in our Terminalling and Transportation and Gathering and Processing segments, respectively, as of December 31, 2017 as a result of the 2018 Drop Down.
|
14
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
•
|
ALRP -
We own a
67%
interest in ALRP, a recently constructed crude oil pipeline located in the Delaware and Midland basins in west Texas.
|
•
|
MPL
-
We have a
17%
interest in MPL, which owns and operates a crude oil pipeline in Minnesota.
|
•
|
PNAC -
We own a
50%
interest in PNAC, which owns and operates an asphalt terminal in Nevada.
|
•
|
RGS -
We have a
78%
interest in Rendezvous Gas Services, L.L.C. (“RGS”), which owns and operates the infrastructure that transports gas from certain fields to several re-delivery points in southwestern Wyoming, including natural gas processing facilities that are owned by us or a third party.
|
•
|
TRG -
We own a
50%
interest in Three Rivers Gathering, L.L.C. (“TRG”) located in the southeastern Uinta Basin. TRG was formed with Ute Energy to transport natural gas gathered by Uintah Basin Field Services, L.L.C. (“UBFS”) and other third-party volumes to gas processing facilities.
|
•
|
UBFS -
We own a
38%
interest in UBFS, which owns and operates the natural gas gathering infrastructure located in the southeastern Uinta Basin.
|
|
ALRP (a)
|
|
MPL
(a)
|
|
PNAC (a)
|
|
RGS
|
|
TRG
|
|
UBFS
|
|
Total
|
||||||||||||||
Balance at December 31, 2017 (b)
|
$
|
—
|
|
|
$
|
120
|
|
|
$
|
—
|
|
|
$
|
268
|
|
|
$
|
37
|
|
|
$
|
15
|
|
|
$
|
440
|
|
Acquired interests
|
159
|
|
|
—
|
|
|
27
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
186
|
|
|||||||
Equity in earnings
|
4
|
|
|
14
|
|
|
—
|
|
|
4
|
|
|
2
|
|
|
1
|
|
|
25
|
|
|||||||
Cumulative effect of accounting standard adoption
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(3
|
)
|
|
—
|
|
|
(3
|
)
|
|||||||
Distributions received
|
(4
|
)
|
|
(14
|
)
|
|
—
|
|
|
(16
|
)
|
|
(5
|
)
|
|
(2
|
)
|
|
(41
|
)
|
|||||||
Balance at September 30, 2018 (b)
|
$
|
159
|
|
|
$
|
120
|
|
|
$
|
27
|
|
|
$
|
256
|
|
|
$
|
31
|
|
|
$
|
14
|
|
|
$
|
607
|
|
(a)
|
These equity method investments were included in the 2018 Drop Down. Amounts were adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.
|
(b)
|
The carrying amount of our investments in ALRP, MPL, PNAC, RGS, TRG and UBFS exceeded the underlying equity in net assets by
$75 million
,
$34 million
,
$17 million
,
$127 million
,
$14 million
and
$6 million
, respectively, at
September 30, 2018
. The carrying amount of our investments in MPL, RGS, TRG and UBFS exceeded the underlying equity in net assets by
$35 million
,
$130 million
,
$15 million
and
$6 million
, respectively, at December 31, 2017. The carrying amounts of our investments that exceed the underlying equity in net assets are amortized over the useful life of the underlying fixed assets and included in equity in earnings (loss).
|
|
September 30,
2018 |
|
December 31, 2017
|
||||
Total debt
|
$
|
4,878
|
|
|
$
|
4,182
|
|
Unamortized issuance costs
|
(48
|
)
|
|
(54
|
)
|
||
Current maturities
|
(1
|
)
|
|
(1
|
)
|
||
Debt, Net of Current Maturities and Unamortized Issuance Costs
|
$
|
4,829
|
|
|
$
|
4,127
|
|
|
|
September 30, 2018
|
15
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
Total
Capacity
|
|
Amount Borrowed as of September 30, 2018
|
|
Outstanding
Letters of Credit
|
|
Available Capacity as of September 30, 2018
|
|
Weighted Average Interest Rate
|
|
Expiration
|
|||||||||
Revolving Credit Facility (a)
|
$
|
1,100
|
|
|
$
|
820
|
|
|
$
|
—
|
|
|
$
|
280
|
|
|
3.95
|
%
|
|
January 29, 2021
|
Dropdown Credit Facility
|
1,000
|
|
|
300
|
|
|
—
|
|
|
700
|
|
|
3.86
|
%
|
|
January 29, 2021
|
||||
Total Credit Facilities (a)
|
$
|
2,100
|
|
|
$
|
1,120
|
|
|
$
|
—
|
|
|
$
|
980
|
|
|
|
|
|
(a)
|
On January 5, 2018, we amended our Revolving Credit Facility to increase the aggregate commitments from
$600 million
to
$1.1 billion
and to permit the incurrence of incremental loans. 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.
|
|
Equity of Predecessors (a)
|
|
Partnership
|
|
Total
|
||||||||||
|
|
Common
|
|
Preferred
|
|
||||||||||
Balance at December 31, 2017
|
$
|
1,292
|
|
|
$
|
2,925
|
|
|
$
|
589
|
|
|
$
|
4,806
|
|
Sponsor contributions of assets to the Predecessors
|
406
|
|
|
—
|
|
|
—
|
|
|
406
|
|
||||
Loss attributable to the Predecessors
|
(28
|
)
|
|
—
|
|
|
—
|
|
|
(28
|
)
|
||||
Net assets not assumed by Andeavor Logistics
|
(19
|
)
|
|
—
|
|
|
—
|
|
|
(19
|
)
|
||||
Allocation of net assets acquired by the unitholders
|
(1,651
|
)
|
|
1,651
|
|
|
—
|
|
|
—
|
|
||||
Distributions to common and preferred unitholders (b)
|
—
|
|
|
(620
|
)
|
|
(29
|
)
|
|
(649
|
)
|
||||
Distributions to common unitholders related to acquisitions (c)
|
—
|
|
|
(300
|
)
|
|
—
|
|
|
(300
|
)
|
||||
Net earnings attributable to partners
|
—
|
|
|
423
|
|
|
34
|
|
|
457
|
|
||||
Cumulative effect of accounting standard adoption
|
—
|
|
|
(22
|
)
|
|
—
|
|
|
(22
|
)
|
||||
Contributions (d)
|
—
|
|
|
34
|
|
|
—
|
|
|
34
|
|
||||
Other
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
||||
Balance at September 30, 2018
|
$
|
—
|
|
|
$
|
4,093
|
|
|
$
|
594
|
|
|
$
|
4,687
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
|
(b)
|
Represents cash distributions declared and paid during the
nine
months ended
September 30, 2018
.
|
(c)
|
Distributions to common unitholders include
$300 million
in cash payments for the 2018 Drop Down. As an entity under common control with Andeavor, we record the assets that we acquire from Andeavor in our consolidated balance sheets at Andeavor’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Andeavor is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net increase of
$1.4 billion
in our equity balance during the
nine
months ended
September 30, 2018
.
|
(d)
|
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.
|
16
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
Quarter Ended
|
Quarterly Distribution Per Common Unit
|
|
Total Cash Distribution
(in millions)
|
|
Date of Distribution
|
|
Unitholders Record Date
|
||||
December 31, 2017 (a)
|
$
|
1.000
|
|
|
$
|
205
|
|
|
February 14, 2018
|
|
January 31, 2018
|
March 31, 2018 (a)
|
1.015
|
|
|
205
|
|
|
May 15, 2018
|
|
May 1, 2018
|
||
June 30, 2018 (a)
|
1.030
|
|
|
209
|
|
|
August 14, 2018
|
|
August 3, 2018
|
||
September 30, 2018 (a)(b)
|
1.030
|
|
|
238
|
|
|
November 14, 2018
|
|
November 5, 2018
|
(a)
|
This distribution is net of
$15 million
waived by TLGP for each of the
three
months ended
September 30, 2018
, June 30, 2018 and March 31, 2018, as well as
$12.5 million
for the three months ended December 31, 2017. TLGP’s distribution waivers for 2018 and 2019 remain in effect as instituted in 2017 under the terms of our partnership agreement.
|
(b)
|
This distribution was declared on
October 26, 2018
and will be paid on the date of distribution.
|
|
|
September 30, 2018
|
17
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Net earnings
|
$
|
166
|
|
|
$
|
90
|
|
|
$
|
429
|
|
|
$
|
253
|
|
Special allocations of net earnings (“Special Allocations”) (a)
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
||||
Net earnings, including Special Allocations
|
166
|
|
|
90
|
|
|
429
|
|
|
254
|
|
||||
Distributions on Preferred Units (b)
|
(11
|
)
|
|
—
|
|
|
(31
|
)
|
|
—
|
|
||||
Net earnings attributable to common units
|
155
|
|
|
90
|
|
|
398
|
|
|
254
|
|
||||
General partner’s distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
(6
|
)
|
||||
General partner’s IDRs (c)
|
—
|
|
|
—
|
|
|
—
|
|
|
(75
|
)
|
||||
Limited partners’ distributions on common units
|
(238
|
)
|
|
(201
|
)
|
|
(652
|
)
|
|
(407
|
)
|
||||
Distributions on common units greater than earnings
|
$
|
(83
|
)
|
|
$
|
(111
|
)
|
|
$
|
(254
|
)
|
|
$
|
(234
|
)
|
General partner’s earnings:
|
|
|
|
|
|
|
|
||||||||
Distributions
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
6
|
|
General partner’s IDRs (c)
|
—
|
|
|
—
|
|
|
—
|
|
|
75
|
|
||||
Allocation of distributions greater than earnings (d)
|
(4
|
)
|
|
(8
|
)
|
|
(28
|
)
|
|
(48
|
)
|
||||
Total general partner’s earnings
|
$
|
(4
|
)
|
|
$
|
(8
|
)
|
|
$
|
(28
|
)
|
|
$
|
33
|
|
Limited partners’ earnings on common units:
|
|
|
|
|
|
|
|
||||||||
Distributions (e)
|
$
|
238
|
|
|
$
|
201
|
|
|
$
|
652
|
|
|
$
|
407
|
|
Special Allocations (a)
|
—
|
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
||||
Allocation of distributions greater than earnings
|
(79
|
)
|
|
(103
|
)
|
|
(226
|
)
|
|
(186
|
)
|
||||
Total limited partners’ earnings on common units
|
$
|
159
|
|
|
$
|
98
|
|
|
$
|
426
|
|
|
$
|
220
|
|
Weighted average limited partner units outstanding:
|
|
|
|
|
|
|
|
||||||||
Common units - basic
|
234.4
|
|
|
108.0
|
|
|
223.0
|
|
|
107.0
|
|
||||
Common units - diluted (f)
|
234.6
|
|
|
108.1
|
|
|
223.2
|
|
|
107.1
|
|
||||
Net earnings per limited partner unit: (g)
|
|
|
|
|
|
|
|
||||||||
Common - basic
|
$
|
0.68
|
|
|
$
|
0.90
|
|
|
$
|
1.91
|
|
|
$
|
2.05
|
|
Common - diluted
|
$
|
0.68
|
|
|
$
|
0.90
|
|
|
$
|
1.91
|
|
|
$
|
2.05
|
|
(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 Revolving Credit Facility in lieu of using all cash on hand to fund the acquisition of crude oil, natural gas and produced water gathering systems and two natural gas processing facilities from Whiting Oil and Gas Corporation, GBK Investments, LLC and WBI Energy Midstream, LLC (the “North Dakota Gathering and Processing Assets”) during the
nine
months ended
September 30, 2017
.
|
(b)
|
The Preferred Units entitle unitholders to receive preferred distributions on a semi-annually basis.
|
(c)
|
IDRs entitled 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
$38 million
of IDRs waived by TLGP for the
nine
months ended
September 30, 2017
, respectively. Our general partner no longer holds IDRs as a result of the IDR/GP Transaction.
|
(d)
|
We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of
$4 million
and
$28 million
for the three and nine months ended
September 30, 2018
, respectively, and losses of
$7 million
and
$46 million
for the three and nine months ended
September 30, 2017
, respectively.
|
(e)
|
Distributions of earnings for limited partners’ common units for the
three
and
nine
months ended
September 30, 2018
is net of a
$15 million
and
$45 million
waiver, respectively, from Andeavor in connection with the WNRL Merger.
|
(f)
|
Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units.
|
(g)
|
Amounts may not recalculate due to rounding of dollar and unit information.
|
18
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
|
|
September 30, 2018
|
19
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
December 31, 2017 (a)
|
|
Adjustments for ASC 606 (b)
|
|
Balance at January 1, 2018
|
|
September 30,
2018 |
||||||||
Receivables from contracts with customers
|
$
|
443
|
|
|
$
|
(34
|
)
|
|
$
|
409
|
|
|
$
|
437
|
|
Other contract assets
|
—
|
|
|
34
|
|
|
34
|
|
|
31
|
|
||||
Deferred income, current
|
23
|
|
|
—
|
|
|
23
|
|
|
22
|
|
||||
Deferred income, noncurrent
|
43
|
|
|
19
|
|
|
62
|
|
|
64
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
|
(b)
|
These amounts exclude balances associated with equity method investments. We recognized a cumulative adjustment of
$3 million
as a decrease to Equity Method Investments in our condensed consolidated balance sheets as of January 1, 2018 for the impacts related to our equity method investment in Three Rivers Gathering, LLC. There were
no
material impacts to this balance during the
nine
months ended
September 30, 2018
due to the adoption.
|
20
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
|
Three Months Ended September 30, 2018
|
|
Nine Months Ended September 30, 2018
|
||||||||||||||||||||
|
Terminalling and Transportation
|
|
Gathering and Processing
|
|
Wholesale
|
|
Terminalling and Transportation
|
|
Gathering and Processing
|
|
Wholesale
|
||||||||||||
Service Revenues (a)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Refined products
|
$
|
240
|
|
|
$
|
—
|
|
|
$
|
4
|
|
|
$
|
650
|
|
|
$
|
—
|
|
|
$
|
13
|
|
Crude oil and water
|
39
|
|
|
108
|
|
|
—
|
|
|
108
|
|
|
313
|
|
|
—
|
|
||||||
Natural gas
|
—
|
|
|
100
|
|
|
—
|
|
|
—
|
|
|
296
|
|
|
—
|
|
||||||
Other
|
1
|
|
|
—
|
|
|
—
|
|
|
4
|
|
|
—
|
|
|
—
|
|
||||||
Total Service Revenues
|
280
|
|
|
208
|
|
|
4
|
|
|
762
|
|
|
609
|
|
|
13
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Product Revenues
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
NGL products
|
—
|
|
|
137
|
|
|
—
|
|
|
—
|
|
|
336
|
|
|
—
|
|
||||||
Refined products
|
—
|
|
|
—
|
|
|
13
|
|
|
—
|
|
|
—
|
|
|
37
|
|
||||||
Total Product Revenues
|
—
|
|
|
137
|
|
|
13
|
|
|
—
|
|
|
336
|
|
|
37
|
|
||||||
Total Revenues
|
$
|
280
|
|
|
$
|
345
|
|
|
$
|
17
|
|
|
$
|
762
|
|
|
$
|
945
|
|
|
$
|
50
|
|
(a)
|
Includes
$114 million
and
$292 million
of lease revenues for the
three
and
nine
months ended
September 30, 2018
, respectively.
|
|
|
September 30, 2018
|
21
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2018 (a)
|
|
2017 (a)
|
|
2018 (a)
|
|
2017 (a)
|
||||||||
Revenues
|
|
|
|
|
|
|
|
||||||||
Terminalling and Transportation:
|
|
|
|
|
|
|
|
||||||||
Terminalling
|
$
|
235
|
|
|
$
|
189
|
|
|
$
|
643
|
|
|
$
|
493
|
|
Pipeline transportation
|
44
|
|
|
34
|
|
|
115
|
|
|
97
|
|
||||
Other revenues
|
1
|
|
|
7
|
|
|
4
|
|
|
9
|
|
||||
Total Terminalling and Transportation
|
280
|
|
|
230
|
|
|
762
|
|
|
599
|
|
||||
Gathering and Processing:
|
|
|
|
|
|
|
|
||||||||
NGL sales
|
137
|
|
|
90
|
|
|
336
|
|
|
254
|
|
||||
Gas gathering and processing
|
82
|
|
|
85
|
|
|
249
|
|
|
252
|
|
||||
Crude oil and water gathering
|
86
|
|
|
76
|
|
|
241
|
|
|
170
|
|
||||
Pass-thru and other
|
40
|
|
|
44
|
|
|
119
|
|
|
120
|
|
||||
Total Gathering and Processing
|
345
|
|
|
295
|
|
|
945
|
|
|
796
|
|
||||
Wholesale:
|
|
|
|
|
|
|
|
||||||||
Fuel sales (b)
|
13
|
|
|
565
|
|
|
37
|
|
|
730
|
|
||||
Other wholesale
|
7
|
|
|
4
|
|
|
25
|
|
|
10
|
|
||||
Total Wholesale
|
20
|
|
|
569
|
|
|
62
|
|
|
740
|
|
||||
Intersegment wholesale revenues
|
(3
|
)
|
|
—
|
|
|
(12
|
)
|
|
—
|
|
||||
Total Revenues
|
$
|
642
|
|
|
$
|
1,094
|
|
|
$
|
1,757
|
|
|
$
|
2,135
|
|
|
|
|
|
|
|
|
|
||||||||
Segment Operating Income
|
|
|
|
|
|
|
|
||||||||
Terminalling and Transportation
|
$
|
140
|
|
|
$
|
103
|
|
|
$
|
351
|
|
|
$
|
290
|
|
Gathering and Processing
|
80
|
|
|
50
|
|
|
226
|
|
|
158
|
|
||||
Wholesale
|
7
|
|
|
7
|
|
|
22
|
|
|
9
|
|
||||
Total Segment Operating Income
|
227
|
|
|
160
|
|
|
599
|
|
|
457
|
|
||||
Unallocated general and administrative expenses
|
(12
|
)
|
|
(13
|
)
|
|
(27
|
)
|
|
(33
|
)
|
||||
Operating Income
|
215
|
|
|
147
|
|
|
572
|
|
|
424
|
|
||||
Interest and financing costs, net
|
(57
|
)
|
|
(68
|
)
|
|
(172
|
)
|
|
(193
|
)
|
||||
Equity in earnings of equity method investments
|
7
|
|
|
6
|
|
|
25
|
|
|
13
|
|
||||
Other income, net
|
1
|
|
|
5
|
|
|
4
|
|
|
9
|
|
||||
Net Earnings
|
$
|
166
|
|
|
$
|
90
|
|
|
$
|
429
|
|
|
$
|
253
|
|
|
|
|
|
|
|
|
|
||||||||
Depreciation and Amortization Expenses
|
|
|
|
|
|
|
|
||||||||
Terminalling and Transportation
|
$
|
35
|
|
|
$
|
32
|
|
|
$
|
105
|
|
|
$
|
85
|
|
Gathering and Processing
|
47
|
|
|
51
|
|
|
154
|
|
|
134
|
|
||||
Wholesale
|
4
|
|
|
2
|
|
|
9
|
|
|
3
|
|
||||
Total Depreciation and Amortization Expenses
|
$
|
86
|
|
|
$
|
85
|
|
|
$
|
268
|
|
|
$
|
222
|
|
|
|
|
|
|
|
|
|
||||||||
Capital Expenditures
|
|
|
|
|
|
|
|
||||||||
Terminalling and Transportation
|
$
|
76
|
|
|
$
|
51
|
|
|
$
|
155
|
|
|
$
|
127
|
|
Gathering and Processing
|
110
|
|
|
41
|
|
|
368
|
|
|
85
|
|
||||
Wholesale
|
—
|
|
|
—
|
|
|
1
|
|
|
—
|
|
||||
Total Capital Expenditures
|
$
|
186
|
|
|
$
|
92
|
|
|
$
|
524
|
|
|
$
|
212
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
|
(b)
|
The presentation of wholesale fuel sales was impacted by adoption of ASC 606 on January 1, 2018. Beginning January 1, 2018 in connection with the adoption, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor were netted.
|
22
|
|
|
|
|
Notes to Condensed Consolidated Financial Statements (Unaudited)
|
|
|
September 30,
2018 |
|
December 31, 2017 (a)
|
||||
Terminalling and Transportation
|
$
|
3,408
|
|
|
$
|
3,045
|
|
Gathering and Processing
|
6,378
|
|
|
6,006
|
|
||
Wholesale
|
354
|
|
|
342
|
|
||
Other
|
57
|
|
|
112
|
|
||
Total Identifiable Assets
|
$
|
10,197
|
|
|
$
|
9,505
|
|
(a)
|
Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.
|
|
|
September 30, 2018
|
23
|
Management’s Discussion and Analysis
|
24
|
|
|
|
|
Management’s Discussion and Analysis
|
|
•
|
increasing our terminalling volumes by expanding capacity and growing our third-party services at certain terminals;
|
•
|
optimizing volumes and growing third-party throughput at our Terminalling and Transportation assets; and
|
•
|
pursuing strategic assets in the western and inland U.S.
|
•
|
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 region to enhance and improve overall basin logistics efficiencies;
|
•
|
expanding our crude oil gathering footprint in the Permian Basin; and
|
•
|
pursuing strategic assets across the western and inland U.S.
|
|
|
September 30, 2018
|
25
|
Management’s Discussion and Analysis
|
•
|
Average terminalling revenue per barrel - calculated as total terminalling revenue divided by terminalling throughput presented in thousands of barrels per day (“Mbpd”) multiplied by 1,000 and multiplied by the number of days in the period, (
92
days for both the
three
months ended
September 30, 2018
(the “
2018
Quarter”) and
2017
(the “
2017
Quarter”) and
273
days for both the
nine
months ended
September 30, 2018
(the “
2018
Period”) and
2017
(the “
2017
Period”);
|
•
|
Average pipeline transportation revenue per barrel - calculated as total pipeline transportation revenue divided by pipeline transportation throughput presented in Mbpd multiplied by 1,000 and multiplied by the number of days in the period as outlined above;
|
•
|
Average margin on NGL sales per barrel - calculated as the difference between the NGL sales revenues and the amounts recognized as NGL expense divided by our NGL sales volumes in barrels presented in Mbpd multiplied by 1,000 and multiplied by the number of days in the period as outlined above;
|
•
|
Average gas gathering and processing revenue per Million British thermal units (“MMBtu”) - calculated as total gathering and processing fee-based revenue divided by gas gathering throughput presented in thousands of MMBtu per day (“MMBtu/d”) multiplied by 1,000 and multiplied by the number of days in the period as outlined above;
|
•
|
Average crude oil and water gathering revenue per barrel - calculated as total crude oil and water gathering fee-based revenue divided by crude oil and water gathering throughput presented in Mbpd multiplied by 1,000 and multiplied by the number of days in the period as outlined above;
|
•
|
Wholesale fuel sales per gallon - calculated as wholesale fuel revenues divided by our total wholesale fuel sales volume in gallons; and
|
•
|
Average wholesale fuel sales margin per gallon - calculated as the difference between total wholesale fuel revenues and wholesale cost of fuel and other divided by our total wholesale fuel sales volume in gallons.
|
26
|
|
|
|
|
Management’s Discussion and Analysis
|
|
•
|
Financial non-GAAP measure of EBITDA - calculated as U.S. GAAP-based net earnings before interest, income taxes and depreciation and amortization expense;
|
•
|
Financial non-GAAP measure of Segment EBITDA - calculated as a segment’s U.S. GAAP-based operating income before depreciation and amortization expense plus equity in earnings (loss) of equity method investments and other income (expense), net;
|
•
|
Liquidity non-GAAP measure of distributable cash flow - calculated as U.S. GAAP-based net cash flow from operating activities adjusted for changes in working capital, amounts spent on maintenance capital net of reimbursements and other adjustments not expected to settle in cash;
|
•
|
Liquidity non-GAAP measure of distributable cash flow attributable to common unitholders - calculated as distributable cash flow minus distributions associated with the Preferred Units;
|
•
|
Operating performance measure of average margin on NGL sales per barrel - calculated as the difference between the NGL sales revenues and the amounts recognized as NGL expense divided by our NGL sales volumes in barrels presented in Mbpd multiplied by 1,000 and multiplied by the number of days in the period as previously outlined; and
|
•
|
Operating performance measure of average wholesale fuel sales margin per gallon - calculated as the difference between total wholesale fuel revenues and wholesale’s cost of fuel divided by our total wholesale fuel sales volumes in gallons.
|
•
|
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.
|
|
|
September 30, 2018
|
27
|
Management’s Discussion and Analysis
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding these non-GAAP measures.
|
28
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
|
September 30, 2018
|
29
|
Management’s Discussion and Analysis
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding these non-GAAP measures.
|
30
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
|
September 30, 2018
|
31
|
Management’s Discussion and Analysis
|
32
|
|
|
|
|
Management’s Discussion and Analysis
|
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
|
|
September 30, 2018
|
33
|
Management’s Discussion and Analysis
|
|
Three Months Ended September 30,
|
||||||
|
2018 (a)
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
Terminalling
|
$
|
235
|
|
|
$
|
189
|
|
Pipeline transportation
|
44
|
|
|
34
|
|
||
Other revenues
|
1
|
|
|
7
|
|
||
Total Revenues
|
280
|
|
|
230
|
|
||
Costs and Expenses
|
|
|
|
||||
Operating expenses (b)
|
99
|
|
|
80
|
|
||
Depreciation and amortization expenses
|
35
|
|
|
32
|
|
||
General and administrative expenses
|
7
|
|
|
15
|
|
||
Gain on asset disposals and impairments
|
(1
|
)
|
|
—
|
|
||
Operating Income
|
$
|
140
|
|
|
$
|
103
|
|
Segment EBITDA (c)
|
$
|
180
|
|
|
$
|
142
|
|
Rates (d)
|
|
|
|
||||
Average terminalling revenue per barrel
|
$
|
1.43
|
|
|
$
|
1.18
|
|
Average pipeline transportation revenue per barrel
|
$
|
0.45
|
|
|
$
|
0.40
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
Operating expenses included an imbalance settlement gain of
$1 million
for the
2017
Quarter. There was
no
gain for the 2018 Quarter.
|
(c)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(d)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
34
|
|
|
|
|
Management’s Discussion and Analysis
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
|
Nine Months Ended
September 30, |
||||||
|
2018 (a)
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
Terminalling
|
$
|
643
|
|
|
$
|
493
|
|
Pipeline transportation
|
115
|
|
|
97
|
|
||
Other revenues
|
4
|
|
|
9
|
|
||
Total Revenues
|
762
|
|
|
599
|
|
||
Costs and Expenses
|
|
|
|
||||
Operating expenses (b)
|
279
|
|
|
216
|
|
||
Depreciation and amortization expenses
|
105
|
|
|
85
|
|
||
General and administrative expenses
|
27
|
|
|
33
|
|
||
Gain on asset disposals and impairments
|
—
|
|
|
(25
|
)
|
||
Operating Income
|
$
|
351
|
|
|
$
|
290
|
|
Segment EBITDA (c)
|
$
|
474
|
|
|
$
|
384
|
|
Rates (d)
|
|
|
|
||||
Average terminalling revenue per barrel
|
$
|
1.28
|
|
|
$
|
1.32
|
|
Average pipeline transportation revenue per barrel
|
$
|
0.42
|
|
|
$
|
0.40
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
Operating expenses included an imbalance settlement gain of
$3 million
for the
2017
Period. There was
no
gain for the 2018 Period.
|
(c)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(d)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
|
|
September 30, 2018
|
35
|
Management’s Discussion and Analysis
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(a)
|
Volumes represent barrels sold in keep-whole arrangements, net barrels retained in POP arrangements and other associated products.
|
(b)
|
The adoption of ASC 606 changed the presentation of our gas gathering and processing throughput volumes. Volumes processed internally to enhance our NGL sales are no longer reported in our throughput volumes as certain fees contained within our commodity contracts are now reported as a reduction of “NGL expense”. The impact of the adoption during the
2018
Quarter was
184
thousand MMBtu/d now being used internally and not reported in the throughput volumes used to calculate our average gas gathering and processing revenue per MMBtu.
|
(c)
|
Adjusted to include the historical results of the Predecessors.
|
36
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
Three Months Ended
September 30, |
||||||
|
2018 (a)
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
NGL sales (b)
|
$
|
137
|
|
|
$
|
90
|
|
Gas gathering and processing
|
82
|
|
|
85
|
|
||
Crude oil and water gathering
|
86
|
|
|
76
|
|
||
Pass-thru and other
|
40
|
|
|
44
|
|
||
Total Revenues
|
345
|
|
|
295
|
|
||
Costs and Expenses
|
|
|
|
||||
NGL expense (excluding items shown separately below) (b)
|
73
|
|
|
64
|
|
||
Operating expenses (c)
|
131
|
|
|
113
|
|
||
Depreciation and amortization expenses
|
47
|
|
|
51
|
|
||
General and administrative expenses
|
12
|
|
|
16
|
|
||
Loss on asset disposals and impairments
|
2
|
|
|
1
|
|
||
Operating Income
|
$
|
80
|
|
|
$
|
50
|
|
Segment EBITDA (d)
|
$
|
130
|
|
|
$
|
103
|
|
Rates (e)
|
|
|
|
||||
Average margin on NGL sales per barrel (b)(d)(f)
|
$
|
71.47
|
|
|
$
|
38.30
|
|
Average gas gathering and processing revenue per MMBtu (f)
|
$
|
1.27
|
|
|
$
|
0.96
|
|
Average crude oil and water gathering revenue per barrel
|
$
|
2.03
|
|
|
$
|
1.95
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
We had
24.0
Mbpd and
21.1
Mbpd of gross NGL sales under our agreements for POP and keep-whole arrangements for the
2018
Quarter and
2017
Quarter, respectively. We retained
9.5
Mbpd and
7.0
Mbpd under these arrangements, respectively. The difference between gross sales barrels and barrels retained is reflected in NGL expense resulting from the gross presentation required for the POP arrangements associated with the North Dakota Gathering and Processing Assets.
|
(c)
|
Operating expenses include an imbalance settlement gain of
$1 million
for the
2017
Quarter. There was
no
gain for the
2018
Quarter.
|
(d)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(e)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
(f)
|
Due to the adoption of ASC 606, certain cost recoveries previously presented as service revenues are now reflected as reductions to NGL expense, resulting in an increase to the average margin on NGL sales per barrel. In addition, volumes processed internally to enhance our NGL sales are no longer reported in our throughput volumes used to calculate our average gas gathering and processing revenue per MMBtu as certain fees contained within our commodity contracts are now reported as a reduction of NGL expense. The mix of remaining volumes resulted in a higher recognized gas gathering and processing rate.
|
|
|
September 30, 2018
|
37
|
Management’s Discussion and Analysis
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(a)
|
Volumes represent barrels sold in keep-whole arrangements, net barrels retained in POP arrangements and other associated products.
|
(b)
|
The adoption of ASC 606 changed the presentation of our gas gathering and processing throughput volumes. Volumes processed internally to enhance our NGL sales are no longer reported in our throughput volumes as certain fees contained within our commodity contracts are now reported as a reduction of “NGL expense”. The impact of the adoption during the
2018
Period was
170
thousand MMBtu/d now being used internally and not reported in our throughput volumes used to calculate our average gas gathering and processing revenue per MMBtu.
|
(c)
|
Adjusted to include the historical results of the Predecessors.
|
38
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
Nine Months Ended
September 30, |
||||||
|
2018 (a)
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
NGL sales (b)
|
$
|
336
|
|
|
$
|
254
|
|
Gas gathering and processing
|
249
|
|
|
252
|
|
||
Crude oil and water gathering
|
241
|
|
|
170
|
|
||
Pass-thru and other (c)
|
119
|
|
|
120
|
|
||
Total Revenues
|
945
|
|
|
796
|
|
||
Costs and Expenses
|
|
|
|
||||
NGL expense (excluding items shown separately below) (b)(c)
|
166
|
|
|
179
|
|
||
Operating expenses (d)
|
361
|
|
|
284
|
|
||
Depreciation and amortization expenses
|
154
|
|
|
134
|
|
||
General and administrative expenses
|
36
|
|
|
41
|
|
||
Loss on asset disposals and impairments
|
2
|
|
|
—
|
|
||
Operating Income
|
$
|
226
|
|
|
$
|
158
|
|
Segment EBITDA (e)
|
$
|
391
|
|
|
$
|
299
|
|
Rates (f)
|
|
|
|
||||
Average margin on NGL sales per barrel (b)(c)(e)(g)
|
$
|
61.70
|
|
|
$
|
38.27
|
|
Average gas gathering and processing revenue per MMBtu (g)
|
$
|
1.17
|
|
|
$
|
0.97
|
|
Average crude oil and water gathering revenue per barrel
|
$
|
2.13
|
|
|
$
|
1.71
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
We had
24.4
Mbpd and
21.0
Mbpd of gross NGL sales under our agreements for POP and keep-whole arrangements for the
2018
Period and
2017
Period, respectively. We retained
10.1
Mbpd and
7.3
Mbpd under these arrangements, respectively. The difference between gross sales barrels and barrels retained is reflected in NGL expense resulting from the gross presentation required for the POP arrangements associated with the North Dakota Gathering and Processing Assets.
|
(c)
|
Included in the NGL expense for the
2017
Period was approximately
$2 million
of costs 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.
|
(d)
|
Operating expenses include an imbalance settlement gain of
$4 million
for the
2017
Period. There was
no
gain for the
2018
Period.
|
(e)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(f)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
(g)
|
Due to the adoption of ASC 606, certain cost recoveries previously presented as service revenues are now reflected as reductions to NGL expense, resulting in an increase to the average margin on NGL sales per barrel. In addition, volumes processed internally to enhance our NGL sales are no longer reported in our throughput volumes used to calculate our average gas gathering and processing revenue per MMBtu as certain fees contained within our commodity contracts are now reported as a reduction of NGL expense. The mix of remaining volumes resulted in a higher recognized gas gathering and processing rate.
|
|
|
September 30, 2018
|
39
|
Management’s Discussion and Analysis
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
40
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
Three Months Ended
September 30, |
||||||
|
2018
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
Fuel sales (b)
|
$
|
13
|
|
|
$
|
565
|
|
Other wholesale
|
7
|
|
|
4
|
|
||
Total Revenues
|
20
|
|
|
569
|
|
||
Costs and Expenses
|
|
|
|
||||
Cost of fuel and other (excluding items shown separately below) (b)
|
—
|
|
|
554
|
|
||
Operating expenses (excluding depreciation and amortization)
|
9
|
|
|
6
|
|
||
Depreciation and amortization expenses
|
4
|
|
|
2
|
|
||
General and administrative expenses
|
—
|
|
|
—
|
|
||
Operating Income
|
$
|
7
|
|
|
$
|
7
|
|
Segment EBITDA (c)
|
$
|
11
|
|
|
$
|
9
|
|
Volumes and Rates (d)
|
|
|
|
||||
Fuel sales volumes (millions of gallons)
|
311
|
|
|
329
|
|
||
Wholesale fuel sales per gallon (b)
|
|
4.0
|
¢
|
|
|
||
Average wholesale fuel sales margin per gallon (b)(c)
|
|
|
|
3.0
|
¢
|
(a)
|
Adjusted to include the historical results of the Predecessors. The Wholesale business was acquired in the WNRL Merger and only represents operations since June 1, 2017, the date the business was originally acquired by Andeavor.
|
(b)
|
Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the 2018 Quarter were netted. Therefore, we no longer present cost of fuel and other or average margin on fuel sales per gallon. Instead, we now present wholesale fuel sales per gallon, which is not a direct comparison of the previous metric.
|
(c)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(d)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
(a)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
|
|
September 30, 2018
|
41
|
Management’s Discussion and Analysis
|
|
Nine Months Ended
September 30, |
||||||
|
2018
|
|
2017 (a)
|
||||
Revenues
|
|
|
|
||||
Fuel sales (b)
|
$
|
37
|
|
|
$
|
730
|
|
Other wholesale
|
25
|
|
|
10
|
|
||
Total Revenues
|
62
|
|
|
740
|
|
||
Costs and Expenses
|
|
|
|
||||
Cost of fuel and other (excluding items shown separately below) (b)
|
—
|
|
|
716
|
|
||
Operating expenses (excluding depreciation and amortization)
|
30
|
|
|
12
|
|
||
Depreciation and amortization expenses
|
9
|
|
|
3
|
|
||
General and administrative expenses
|
1
|
|
|
—
|
|
||
Operating Income
|
$
|
22
|
|
|
$
|
9
|
|
|
|
|
|
||||
Segment EBITDA (c)
|
$
|
31
|
|
|
$
|
12
|
|
|
|
|
|
||||
Volumes and Rates (d)
|
|
|
|
||||
Fuel sales volumes (millions of gallons)
|
904
|
|
|
430
|
|
||
Wholesale fuel sales per gallon (b)
|
|
4.0
|
¢
|
|
|
||
Average wholesale fuel sales margin per gallon (b)(c)
|
|
|
|
3.0
|
¢
|
(a)
|
Adjusted to include the historical results of the Predecessors. The Wholesale business was acquired in the WNRL Merger and only represents operations since June 1, 2017, the date the business was originally acquired by Andeavor.
|
(b)
|
Due to the adoption of ASC 606 effective January 1, 2018, the revenues and costs associated with our fuel purchase and supply arrangements with Andeavor for the 2018 Period were netted. Therefore, we no longer present cost of fuel and other or average margin on fuel sales per gallon. Instead, we now present wholesale fuel sales per gallon, which is not a direct comparison of the previous metric.
|
(c)
|
See “Non-GAAP Reconciliations” section for further information regarding this non-GAAP measure.
|
(d)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
42
|
|
|
|
|
Management’s Discussion and Analysis
|
|
Debt, including current maturities:
|
September 30, 2018
|
|
December 31, 2017
|
||||
Credit facilities
|
$
|
1,120
|
|
|
$
|
423
|
|
Senior notes
|
3,750
|
|
|
3,750
|
|
||
Capital lease obligations
|
8
|
|
|
9
|
|
||
Total Debt
|
4,878
|
|
|
4,182
|
|
||
Unamortized Issuance Costs
|
(48
|
)
|
|
(54
|
)
|
||
Debt, Net of Unamortized Issuance Costs
|
4,830
|
|
|
4,128
|
|
||
Total Equity
|
4,687
|
|
|
4,806
|
|
||
Total Capitalization
|
$
|
9,517
|
|
|
$
|
8,934
|
|
Credit Facility
|
Total
Capacity
|
|
Amount Borrowed as of September 30, 2018
|
|
Available Capacity as of September 30, 2018
|
|
Weighted Average Interest Rate
|
|
Expiration
|
|||||||
Revolving Credit Facility
|
$
|
1,100
|
|
|
$
|
820
|
|
|
$
|
280
|
|
|
3.95
|
%
|
|
January 29, 2021
|
Dropdown Credit Facility
|
1,000
|
|
|
300
|
|
|
700
|
|
|
3.86
|
%
|
|
January 29, 2021
|
|||
Total Credit Facilities
|
$
|
2,100
|
|
|
$
|
1,120
|
|
|
$
|
980
|
|
|
|
|
|
Credit Facility
|
30 Day Eurodollar (LIBOR) Rate at September 30, 2018
|
|
Eurodollar Margin
|
|
Base Rate
|
|
Base Rate Margin
|
|
Commitment Fee
(unused portion)
|
Revolving Credit Facility (a)
|
2.26%
|
|
1.75%
|
|
5.25%
|
|
0.75%
|
|
0.300%
|
Dropdown Credit Facility (a)
|
2.26%
|
|
1.76%
|
|
5.25%
|
|
0.76%
|
|
0.300%
|
(a)
|
We have the option to elect whether our 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.
|
|
|
September 30, 2018
|
43
|
Management’s Discussion and Analysis
|
|
Nine Months Ended
September 30, |
||||||
|
2018 (a)
|
|
2017 (a)
|
||||
Cash Flows From (Used in):
|
|
|
|
||||
Operating activities
|
$
|
719
|
|
|
$
|
524
|
|
Investing activities
|
(945
|
)
|
|
(1,404
|
)
|
||
Financing activities
|
181
|
|
|
230
|
|
||
Decrease in Cash and Cash Equivalents
|
$
|
(45
|
)
|
|
$
|
(650
|
)
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
44
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
|
September 30, 2018
|
45
|
Management’s Discussion and Analysis
|
|
Three Months Ended September 30,
|
||||||||||||||||||||||
|
2018 (a)
|
|
2017 (a)
|
|
2018 (a)
|
|
2017 (a)
|
|
2018
|
|
2017 (a)
|
||||||||||||
|
Terminalling and Transportation
|
|
Gathering and Processing
|
|
Wholesale
|
||||||||||||||||||
Segment Operating Income
|
$
|
140
|
|
|
$
|
103
|
|
|
$
|
80
|
|
|
$
|
50
|
|
|
$
|
7
|
|
|
$
|
7
|
|
Depreciation and amortization expenses
|
35
|
|
|
32
|
|
|
47
|
|
|
51
|
|
|
4
|
|
|
2
|
|
||||||
Equity in earnings of equity method investments
|
4
|
|
|
4
|
|
|
3
|
|
|
2
|
|
|
—
|
|
|
—
|
|
||||||
Other income, net
|
1
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Segment EBITDA
|
$
|
180
|
|
|
$
|
142
|
|
|
$
|
130
|
|
|
$
|
103
|
|
|
$
|
11
|
|
|
$
|
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
Nine Months Ended September 30,
|
||||||||||||||||||||||
|
2018 (a)
|
|
2017 (a)
|
|
2018 (a)
|
|
2017 (a)
|
|
2018
|
|
2017 (a)
|
||||||||||||
|
Terminalling and Transportation
|
|
Gathering and Processing
|
|
Wholesale
|
||||||||||||||||||
Segment Operating Income
|
$
|
351
|
|
|
$
|
290
|
|
|
$
|
226
|
|
|
$
|
158
|
|
|
$
|
22
|
|
|
$
|
9
|
|
Depreciation and amortization expenses
|
105
|
|
|
85
|
|
|
154
|
|
|
134
|
|
|
9
|
|
|
3
|
|
||||||
Equity in earnings of equity method investments
|
14
|
|
|
6
|
|
|
11
|
|
|
7
|
|
|
—
|
|
|
—
|
|
||||||
Other income, net
|
4
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Segment EBITDA
|
$
|
474
|
|
|
$
|
384
|
|
|
$
|
391
|
|
|
$
|
299
|
|
|
$
|
31
|
|
|
$
|
12
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2018 (a)
|
|
2017 (a)
|
|
2018 (a)
|
|
2017 (a)
|
||||||||
Net Cash from Operating Activities
|
$
|
172
|
|
|
$
|
225
|
|
|
$
|
719
|
|
|
$
|
524
|
|
Changes in assets and liabilities
|
96
|
|
|
(45
|
)
|
|
7
|
|
|
(51
|
)
|
||||
Predecessors impact
|
1
|
|
|
(8
|
)
|
|
12
|
|
|
20
|
|
||||
Maintenance capital expenditures (b)
|
(26
|
)
|
|
(33
|
)
|
|
(70
|
)
|
|
(80
|
)
|
||||
Reimbursement for maintenance capital expenditures (b)
|
7
|
|
|
7
|
|
|
19
|
|
|
22
|
|
||||
Proceeds from sale of assets
|
—
|
|
|
—
|
|
|
—
|
|
|
28
|
|
||||
Adjustments for equity method investments
|
(6
|
)
|
|
4
|
|
|
(3
|
)
|
|
5
|
|
||||
Changes in deferred revenue (c)
|
13
|
|
|
(2
|
)
|
|
8
|
|
|
5
|
|
||||
Other (d)
|
5
|
|
|
—
|
|
|
3
|
|
|
4
|
|
||||
Distributable Cash Flow
|
262
|
|
|
148
|
|
|
695
|
|
|
477
|
|
||||
Less: Preferred unit distributions (e)
|
(11
|
)
|
|
—
|
|
|
(31
|
)
|
|
—
|
|
||||
Distributable Cash Flow Attributable to Common Unitholders
|
$
|
251
|
|
|
$
|
148
|
|
|
$
|
664
|
|
|
$
|
477
|
|
(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.
|
(c)
|
Included in changes in deferred revenue are adjustments to remove the impact of the adoption of the new revenue recognition accounting standard on January 1, 2018 as well as the impact from the timing of recognition with certain of our contracts that contain minimum volume commitment with clawback provisions, which are predominantly recognized annually in the third quarter based on current contract terms.
|
(d)
|
Other includes transaction costs related to recent acquisitions and settlement expenses.
|
(e)
|
Represents the cash distributions earned by the Preferred Units for the three and
nine
months ended
September 30, 2018
assuming a distribution is declared by the Board. Cash distributions to be paid to holders of the Preferred Units are not available to common unitholders.
|
46
|
|
|
|
|
Management’s Discussion and Analysis
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
|
2018 (a)
|
|
2017 (a)
|
|
2018 (a)
|
|
2017 (a)
|
||||||||
Segment Operating Income
|
$
|
80
|
|
|
$
|
50
|
|
|
$
|
226
|
|
|
$
|
158
|
|
Add back:
|
|
|
|
|
|
|
|
||||||||
Operating expenses
|
131
|
|
|
113
|
|
|
361
|
|
|
284
|
|
||||
General and administrative expenses
|
12
|
|
|
16
|
|
|
36
|
|
|
41
|
|
||||
Depreciation and amortization expenses
|
47
|
|
|
51
|
|
|
154
|
|
|
134
|
|
||||
Loss on asset disposals and impairments
|
2
|
|
|
1
|
|
|
2
|
|
|
—
|
|
||||
Other commodity purchases (b)
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
||||
Subtract:
|
|
|
|
|
|
|
|
||||||||
Gas gathering and processing revenues
|
(82
|
)
|
|
(85
|
)
|
|
(249
|
)
|
|
(252
|
)
|
||||
Crude oil gathering revenues
|
(86
|
)
|
|
(76
|
)
|
|
(241
|
)
|
|
(170
|
)
|
||||
Pass-thru and other revenues
|
(40
|
)
|
|
(44
|
)
|
|
(119
|
)
|
|
(120
|
)
|
||||
Margin on NGL Sales
|
$
|
64
|
|
|
$
|
26
|
|
|
$
|
170
|
|
|
$
|
77
|
|
Divided by Total Volumes for the Period:
|
|
|
|
|
|
|
|
||||||||
NGLs sales volumes (Mbpd)
|
9.5
|
|
|
7.0
|
|
|
10.1
|
|
|
7.3
|
|
||||
Number of days in the period
|
92
|
|
|
92
|
|
|
273
|
|
|
273
|
|
||||
Total volumes for the period (thousands of barrels) (c)
|
874
|
|
|
644
|
|
|
2,757
|
|
|
1,993
|
|
||||
Average Margin on NGL Sales per Barrel (c)
|
$
|
71.47
|
|
|
$
|
38.30
|
|
|
$
|
61.70
|
|
|
$
|
38.27
|
|
(a)
|
Adjusted to include the historical results of the Predecessors.
|
(b)
|
Included in NGL expense for the
nine
months ended
September 30, 2017
was approximately
$2 million
of costs related to crude oil volumes obtained and immediately sold in connection with the North Dakota Gathering and Processing Assets acquisition.
|
(c)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
|
Three Months Ended
|
|
Nine Months Ended
|
||||
|
September 30, 2017 (a)
|
||||||
Segment Operating Income
|
$
|
7
|
|
|
$
|
9
|
|
Add back:
|
|
|
|
||||
Operating expenses (excluding depreciation and amortization)
|
6
|
|
|
12
|
|
||
Depreciation and amortization expenses
|
2
|
|
|
3
|
|
||
Subtract:
|
|
|
|
||||
Other wholesale revenues
|
(4
|
)
|
|
(10
|
)
|
||
Wholesale Fuel Sales Margin
|
$
|
11
|
|
|
$
|
14
|
|
Divided by Total Volumes for the Period:
|
|
|
|
||||
Fuel sales volumes (millions of gallons)
|
329
|
|
|
430
|
|
||
Average Wholesale Fuel Sales Margin per Gallon (b)
|
|
3.0
|
¢
|
|
|
3.0
|
¢
|
(a)
|
Adjusted to include the historical results of the Predecessors. The Wholesale business was acquired in the WNRL Merger and only represent operations since June 1, 2017, the date the business was originally acquired by Andeavor.
|
(b)
|
Amounts may not recalculate due to rounding of dollar and volume information.
|
|
|
September 30, 2018
|
47
|
Management’s Discussion and Analysis
|
•
|
changes in the expected value of and benefits derived from acquisitions, including any inability to successfully integrate acquisitions, realize expected synergies or achieve operational efficiency and effectiveness;
|
•
|
changes in global economic conditions on our business, on the business of our key customers, and on our customers’ suppliers, business partners and credit lenders;
|
•
|
a material change in the crude oil and natural gas produced in the basins where we operate;
|
•
|
the ability of our key customers 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;
|
•
|
regulatory and other requirements concerning the transportation of crude oil, natural gas, NGLs and refined products, particularly in the areas where we operate;
|
•
|
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;
|
•
|
changes in our tax status;
|
•
|
the ability of our largest customers to perform under the terms of our gathering agreements;
|
•
|
the risk of contract cancellation, non-renewal or failure to perform by those in our supply and distribution chains, 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;
|
•
|
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 or the areas in which our customers operate;
|
•
|
disruptions due to equipment interruption or failure at our facilities, MPC’s or Andeavor’s facilities or third-party facilities on which our key customers are dependent;
|
•
|
our inability to complete acquisitions on economically acceptable terms or within anticipated timeframes;
|
•
|
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 expected timing, 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 MPC;
|
•
|
risks related to labor relations and workplace safety;
|
•
|
political developments; and
|
•
|
the factors described in greater detail under “Competition” and “Risk Factors” in Items 1 and 1A of our Annual Report on Form 10-K for the year ended
December 31, 2017
, in “Risk Factors” in Part II, Item 1A of this Quarterly Report on Form 10-Q, and our other filings with the SEC.
|
48
|
|
|
|
|
Quantitative and Qualitative Disclosures about Market Risk
|
|
|
|
September 30, 2018
|
49
|
Legal Proceedings, Risk Factors and Unregistered Sales of Equity Securities
|
50
|
|
|
|
|
Exhibits
|
Exhibit Number
|
|
|
|
Incorporated by Reference (File No. 1-35143, unless otherwise indicated)
|
||||
|
Description of Exhibit
|
|
Form
|
|
Exhibit
|
|
Filing Date
|
|
‡
2.1
|
|
|
8-K
|
|
2.1
|
|
8/14/2017
|
|
|
|
|
|
|
|
|
|
|
‡
2.2
|
|
|
8-K
|
|
2.1
|
|
11/8/2017
|
|
|
|
|
|
|
|
|
|
|
‡ 2.3
|
|
|
10-Q
|
|
2.3
|
|
5/7/2018
|
|
|
|
|
|
|
|
|
|
|
2.4
|
|
|
8-K
|
|
2.1
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
*2.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1
|
|
|
8-K
|
|
3.1
|
|
10/29/2018
|
|
|
|
|
|
|
|
|
|
|
3.2
|
|
|
8-K
|
|
3.1
|
|
12/1/2017
|
|
|
|
|
|
|
|
|
|
|
3.3
|
|
|
8-K
|
|
3.2
|
|
10/2/2018
|
|
|
|
|
|
|
|
|
|
|
10.1
|
|
|
8-K
|
|
10.1
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
*10.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.3
|
|
|
8-K
|
|
10.2
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
*10.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2018
|
51
|
Exhibits
|
Exhibit Number
|
|
|
|
Incorporated by Reference (File No. 1-35143, unless otherwise indicated)
|
||||
|
Description of Exhibit
|
|
Form
|
|
Exhibit
|
|
Filing Date
|
|
10.5
|
|
|
8-K
|
|
10.3
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
10.6
|
|
|
8-K
|
|
10.4
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
10.7
|
|
|
8-K
|
|
10.5
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
10.8
|
|
|
8-K
|
|
10.6
|
|
8/7/2018
|
|
|
|
|
|
|
|
|
|
|
*10.9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*10.10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*10.11
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*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
|
|
|
|
|
|
|
‡
|
Certain schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K. A copy of any omitted schedule will be furnished supplementally to the SEC on request.
|
*
|
Filed herewith
|
**
|
Submitted electronically herewith
|
52
|
|
|
|
|
|
|
Andeavor Logistics LP
|
|
|
|
|
|
|
|
By:
|
Tesoro Logistics GP, LLC
|
|
|
|
Its general partner
|
|
|
|
|
Date:
|
November 7, 2018
|
By:
|
/s/ D. ANDREW WOODWARD
|
|
|
|
D. Andrew Woodward
|
|
|
|
Vice President, Finance
|
|
|
|
(Principal Financial Officer and Duly Authorized Signatory)
|
|
|
September 30, 2018
|
53
|
ANDEAVOR PARTIES:
|
ANDEAVOR
By:
/s/ Gregory J. Goff
Gregory J. Goff
President and Chief Executive Officer
|
WESTERN REFINING SOUTHWEST, INC.
By:
/s/ Gregory J. Goff
Gregory J. Goff
President and Chief Executive Officer
TESORO REFINING & MARKETING COMPANY LLC
By:
/s/ Gregory J. Goff
Gregory J. Goff
President and Chief Executive Officer
|
TESORO GREAT PLAINS MIDSTREAM LLC
By:
/s/ Gregory J. Goff
Gregory J. Goff
President and Chief Executive Officer
|
TESORO GREAT PLAINS GATHERING & MARKETING LLC
By:
/s/ Gregory J. Goff
Gregory J. Goff
President and Chief Executive Officer
|
LOGISTICS PARTIES:
|
ANDEAVOR LOGISTICS LP
By: TESORO LOGISTICS GP, LLC,
its General Partner
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
TESORO LOGISTICS OPERATIONS LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
TESORO LOGISTICS PIPELINES LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
WESTERN REFINING TERMINALS, LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
WESTERN REFINING PIPELINE, LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
|
TESORO HIGH PLAINS PIPELINE COMPANY LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
WESTERN REFINING LOGISTICS LP
By: Western Refining Logistics GP, LLC,
its general partner
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
|
WNRL ENERGY LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
TESORO SOCAL PIPELINE COMPANY LLC
By:
/s/ Steven M. Sterin
Steven M. Sterin
President and Chief Financial Officer
|
Asset No.
|
Asset Description
|
10002782
|
LEVEL & PRESSURE INDICATORS FB-766,FB-767 & FB-704
|
10007669
|
M&E- RAILTRACK SOLENOID FRZ PROTECTN
|
10007672
|
M&E-ELECTR DISTR.-REF OM PRESSURIZATN LEL DETECTOR
|
10007674
|
M&E-EXCHANGER- REFINING- TNKFLD WATER DR
|
10007675
|
M&E-FIRE/SAFETY EQPT - REFINING TANKFIELD WALKWAYS
|
10007677
|
M&E - I.S.B.L.-INSTRUMENTS-REF- LIQ LEVEL ALARM
|
10007679
|
M&E - I.S.B.L. - LINES, PIPING - REF
|
10007681
|
M&E- JP-8 MODIFICTNS-ABV GRADE PIPING
|
10007682
|
M&E-I.S.B.L.-LINES, PIPING-REF- DECANTING TANK
|
10007683
|
M&E-I.S.B.L.-LINES, PIPING-REF- TNKFLD WATER DR
|
10007685
|
M&E - I.S.B.L. - LINES, PIPING - REF
|
10007686
|
M&E -MACT - CONVERT TK 746 TO METHANOL SERV
|
10007688
|
M&E - PIPE FROM TK730/733
|
10007689
|
M&E-I.S.B.L.-LINES, PIPING-REF- TANK HEADERS
|
10007690
|
M&E - I.S.B.L. - LINES, PIPING - REF - SE 731 TK.
|
10007691
|
M&E-I.S.B.L.-LINES, PIPING-REF- E TKFLD FIREWAL
|
10007692
|
M&E-ISBL LINES- FIREWTR SYS WST TKFLD (PX-1697)
|
10007694
|
M&E-I.S.B.L.-LINES, PIPING- TNKFLD WATER DRAW SYS
|
10007695
|
ISBL LINES, PIPING - FB723 REPLACE ROOF (PX-1771)
|
10007696
|
M&E-I.S.B.L.-LINES, PIPING-REF- FB RPLC ROOF
|
10007697
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L.
|
10007700
|
M&E- REPL LVL ALARMS ON PROPRANE DRUMS
|
10007701
|
M&E - I.S.B.L.- REF INSTR M. BUTTONS TO ACT DELUGE
|
10007705
|
M&E - LINES, ELECTRICAL LINES: -
|
10007710
|
M&E - LINES, ELECTRICAL LINES: -
|
10007716
|
M&E - LINES, ELECTRICAL LINES: -
|
10007717
|
M&E - LINES, ELECTRICAL LINES: -
|
10007719
|
M&E - LINES, ELECTRICAL LINES: -
|
10007720
|
M&E - LINES, ELECTRICAL LINES: - EF044
|
10007721
|
M&E - LINES, ELECTRICAL LINES: - EF044
|
10007722
|
M&E - LINES, ELECTRICAL LINES: - EF044
|
10007723
|
M&E - LINES, ELECTRICAL LINES: -
|
10007730
|
ELECTRICAL LINES: - TKFIELD WATER DRAW SYSTEM
|
10007732
|
M&E - LINES, ELECTRICAL LINES: - TNKFLD WATER DR
|
10007736
|
M&E - LINES, ELECTRICAL LINES: - EF042 MOTOR CON
|
Asset No.
|
Asset Description
|
10007737
|
M&E - LINES, ELECTRICAL LINES: - EF042 MOTOR CON
|
10007738
|
M&E - LINES, ELECTRICAL LINES: - EF042 MOTOR CON
|
10007740
|
M&E - LINES, ELECTRICAL LINES: -
|
10007741
|
M&E - LINES, ELECTRICAL LINES: -
|
10007742
|
M&E - LINES, ELECTRICAL LINES: - EF043
|
10007743
|
M&E - LINES, ELECTRICAL LINES: - EF043
|
10007744
|
M&E - LINES, ELECTRICAL LINES: - EF043
|
10007745
|
M&E - LINES, ELECTRICAL LINES: - 440 VOLT
|
10007746
|
M&E - LINES, ELECTRICAL LINES - JET FUEL FACILITY
|
10007749
|
ELECTR. LINES -CONVRT TK751 TO EMERG. SERV. (X-24)
|
10007755
|
M&E - LINES, ELECTRICAL LINES: - STD.TRIPLEPHASE
|
10007758
|
M&E - LINES, ELECTRICAL LINES: -
|
10007761
|
M&E - LINES, ELECTRICAL LINES: -
|
10007762
|
M&E -LOADING RACKS - REF M&E - LOADING RACKS - REF
|
10007763
|
M&E - PROCESS UNIT - STRUCTURAL STEEL - REFINING
|
10007764
|
M&E-PUC CONST-AOC REF,TRANS,SP, N- CRD GRVITOMETER
|
10007766
|
M&E-PUC CONST-AOC REF,TRANS,SP, N- TK-769-52-06-13
|
10007773
|
M&E - PUMP UNIT - REFINING PUMP POWER UNIT - FB-716 Mixer
|
10007780
|
M&E - TANK: ABOVE GROUND STORAGE
|
10007781
|
M&E - TANK: ABOVE GROUND STORAGE
|
10007782
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF12 FB-702
|
10007783
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF12 FB-702
|
10007784
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF12 FB-702
|
10007785
|
M&E - TANK: ABOVE GROUND STORAGE - REF - RISER FB-734
|
10007786
|
M&E-TANK:ABOVE GRND STORAGE-REF- 5 FOAM NOZZLES FB-705
|
10007787
|
TANK 725 - CONE ROOF
|
10007788
|
M&E - TANK: ABOVE GROUND STORAGE - REF - CONE ROOF FB-703
|
10007789
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF15 FB-703
|
10007790
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF15 FB-703
|
10007791
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF15 FB-703
|
10007792
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-746
|
10007793
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF188 FB-742
|
10007794
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF188 FB-742
|
10007795
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF188 FB-742
|
10007796
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF FB-764
|
10007797
|
M&E-TANK:ABOVE GRND STORAGE-REF- HEATING COILS
|
10007798
|
TANK: NOZZLE ASS'MBLYS ON TANKS (MCI-2601) FB-728
|
10007799
|
TANK:ABOVE GRND STORAGE-REF- NOZZLE ASS'BLYS TK752
|
10007800
|
M&E-TANK:ABOVE GRND STORAGE-REF- LEVEL INDICATOR FB-704
|
10007801
|
M&E-TANK:ABOVE GRND STORAGE-REF- 1-1/2IN ORB VAL FB-767
|
10007802
|
M&E - TANK: ABOVE GROUND STORAGE - REFS
|
10007803
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF214 FB-752
|
Asset No.
|
Asset Description
|
10007804
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF214 FB-752
|
10007805
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF214 FB-752
|
10007806
|
TANK: ABOVE GROUND STORAGE - REFINING TANK TK-749 FB-749
|
10007807
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-764
|
10007808
|
M&E - TANK: ABOVE GROUND STORAGE - EF208 FB747
|
10007809
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF208 FB-747
|
10007810
|
M&E-TANK:ABOVE GRND STORAGE-REF- INSTRUMENTATION FB-704
|
10007811
|
M&E-TANK:ABOVE GRND STORAGE-REF- INSTITION TR567 FB-766
|
10007812
|
M&E-TANK:ABOVE GRND STORAGE-REF- HEATING CABLE FB-767
|
10007813
|
M&E - TANK: ABOVE GROUND STORAGE - REF - NOZZLE FB-703
|
10007814
|
M&E - TANK: ABOVE GROUND STORAGE - REF - LIGHTNIN FB-733
|
10007815
|
TANK:ABOVE GRND STORAGE-TK 765 EARTH DIKE
|
10007816
|
TANK:ABOVE GRND STORAGE - EARTH DIKE TK 765
|
10007817
|
M&E-TANK:ABOVE GRND STORAGE-REF- EF252 EARTH DK FB-765
|
10007818
|
M&E-TANK- DOOR SHEETS for TKS 713, 727, & 734
|
10007819
|
M&E-TANK:ABOVE GRND STORAGE-REF- NEW EPOXY FLOOR FB-703
|
10007820
|
M&E-TANK:ABOVE GRND STORAGE-REF- MIXER NOZZLE FB-701
|
10007821
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-744
|
10007822
|
M&E-TANK:ABOVE GRND STORAGE-REF- 8FT DECANTR LIN FB-715
|
10007823
|
M&E-TANK:ABOVE GRND STORAGE-REF- 89A2412801-02 FB-706
|
10007824
|
M&E-TANK:ABOVE GRND STORAGE-REF- TIE-IN DVN STGE FB-771
|
10007825
|
M&E-TANK:ABOVE GRND STORAGE-REF- CHANGE SERVICE FB-740
|
10007826
|
M&E-TANK: EXT CIRC LINES FOR ENVIRON. GAS REV. FB-728
|
10007827
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF FB-729
|
10007828
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF127 FB-729
|
10007829
|
M&E - TANK: ABOVE GROUND STORAGE - TK729
|
10007830
|
M&E - TANK: ABOVE GROUND STORAGE - EF127 TK 729
|
10007831
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF190 FB-742
|
10007832
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF258
|
10007833
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF190 FB-742
|
10007834
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF190 FB-742
|
10007835
|
M&E-TANK:ABOVE GRND - 3-SAMPLE VALVES TK 757
|
10007836
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLASS BTM. FB-742
|
10007837
|
M&E-TANK:ABOVE GRND STORAGE-REF- EPOXY FLOOR FB-723
|
10007838
|
M&E-TANK:ABOVE GRND STORAGE-REF- EPOXY FLOOR FB-708
|
10007839
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-712
|
10007840
|
M&E-TANK:ABOVE GRND STORAGE-REF- MIXER NOZZLE FB-701
|
10007841
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-770
|
10007842
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF108 FB-725
|
10007843
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF122 FB-728
|
10007844
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF122 FB-728
|
10007845
|
M&E - TANK: ABOVE GROUND STORAGE - EF122 TK 728
|
Asset No.
|
Asset Description
|
10007846
|
M&E-TANK:ABOVE GRND STORAGE-REF- CONVERT SERVICE FB-740
|
10007847
|
TANK: ABOVE GROUND - MIXER ON TK 716 (PX-1519)
|
10007848
|
M&E - TANK: ABOVE GROUND STORAGE - NU-2 TK 723
|
10007849
|
M&E-TANK:ABOVE GRND STORAGE-REF- MIXER NOZZLE
|
10007850
|
M&E - TANK: ABOVE GROUND STORAGE - REF - CONE ROOF FB-745
|
10007851
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-709
|
10007852
|
M&E - TANK: ABOVE GROUND STORAGE - REF - FB-701
|
10007853
|
M&E - TANK: ABOVE GROUND STORAGE - REF - CONE ROOF FB-730
|
10007854
|
M&E - TANK: ABOVE GROUND STORAGE - TANK 704
|
10007855
|
M&E - TANK: ABOVE GROUND STORAGE - REF - TK-704
|
10007856
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF259
|
10007857
|
M&E - TANK: ABOVE GROUND STORAGE - EF140 FB732
|
10007858
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF259
|
10007859
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF140 FB-732
|
10007860
|
M&E - TANK: ABOVE GROUND STORAGE - EF140 TK-732
|
10007861
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-765
|
10007862
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-746
|
10007863
|
M&E - TANK: ABOVE GROUND STORAGE - REF - PLATFORM FB-767
|
10007864
|
M&E-TANK:ABV GRND STORGE-REF MODIFY T-735 TO T-736
|
10007865
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF172 FB-739
|
10007866
|
TANK: ABOVE GROUND STORAGE - REF -CONE ROOF TK 765
|
10007867
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF 743
|
10007868
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF FB-705
|
10007869
|
TANK: ABOVE GROUND STORAGE - REF - TK 739
|
10007870
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF173 FB-739
|
10007871
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF237 FB-758
|
10007872
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF237 FB-758
|
10007873
|
M&E-TANK:ABOVE GRND STORAGE-REF- DEFLECTOR PLATE FB-734
|
10007874
|
M&E - TANK: ABOVE GROUND STORAGE - REF - LADDERS FB-766
|
10007875
|
M&E-TANK:ABOVE GRND STORAGE-REF- ELECT FACILITIE FB-744
|
10007876
|
M&E - TANK: ABOVE GROUND STORAGE - REF - FIREWALL FB-770
|
10007878
|
M&E-TANK:ABOVE GRND STORAGE-REF- INSUL ROOF TK 741
|
10007879
|
M&E-TANK:ABOVE GRND STORAGE-REF- CNVT TO LDD REG FB-757
|
10007880
|
M&E-TANK:ABOVE GRND STORAGE-REF- 88A0440601 FB-734
|
10007881
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF104 FB-724
|
10007882
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF123 FB-728
|
10007883
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF123 FB-728
|
10007884
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF226 FB-755
|
10007885
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF207 FB-747
|
10007886
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF207 FB-747
|
10007887
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF207 FB-747
|
10007888
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-746
|
Asset No.
|
Asset Description
|
10007889
|
M&E-TANK:ABOVE GRND STORAGE-REF- DEFLECTORS FB-704
|
10007890
|
M&E-TANK:ABOVE GRND- DEFLECTORS TK 766
|
10007891
|
M&E - TANK: ABOVE GROUND STORAGE - REF - LABOR FB-770
|
10007892
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOOR COATING FB-737
|
10007893
|
M&E-TANK:ABOVE GRND STORAGE-REF- AUR PIPELN REV FB-724, FB-748
|
10007894
|
M&E - TANK: ABOVE GROUND STORAGE - REF - LIGHTNIN FB-742
|
10007895
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-723
|
10007896
|
M&E-TANK: FIREWATER DRAIN TK 704
|
10007897
|
M&E - TANK: ABOVE GROUND STORAGE - REF - LIGHTNIN FB-711
|
10007898
|
LIGHTNING TANK MIXERS - TK703 & TK730 (PX-1637)
|
10007899
|
M&E-TANK:ABOVE GRND STORAGE-REF- FB723 RPLC ROOF
|
10007901
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-758
|
10007902
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF124 FB-728
|
10007905
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF238 FB-758
|
10007906
|
TANK 758-HP CONE TK-IN SERV 1954-EF238 FB-758
|
10007907
|
M&E - TANK: ABOVE GROUND STORAGE - REF - PLATFORMS FB-759-763
|
10007908
|
M&E - TANK: ABOVE GROUND STORAGE - REF - PIPING FB-723
|
10007910
|
INSTALLATION OF MIXERS ON TKS 741 & 758
|
10007911
|
M&E - TANK: ABOVE GROUND STORAGE - REF - 558725 FB-701
|
10007912
|
M&E-TANK:ABOVE GRND STORAGE-REF- WATER VALVES FB-704
|
10007913
|
M&E-TANK:ABOVE GRND STORAGE-REF- ELECT FACILITIE FB-732
|
10007914
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-732
|
10007915
|
M&E - TANK: ABOVE GROUND STORAGE - REF - PIPING FB-716
|
10007916
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-771
|
10007917
|
AIR BLOWING FACILITIES FOR FB-714 D.O. TANK
|
10007918
|
TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF TK 723
|
10007919
|
M&E - TANK: ABOVE GROUND STORAGE - REF - EF103 724
|
10007920
|
TANK: ABOVE GROUND STORAGE - TANK 701
|
10007921
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLOATING ROOF FB-748
|
10007922
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-758
|
10007923
|
TANK 750 - FLOATING ROOF
|
10007924
|
M&E-TANK:ABOVE GRND STORAGE-REF- SITE PREP-TK-764
|
10007925
|
M&E-TANK:ABOVE GRND STORAGE-REF- CONCRETE BAFFLE - Fire Protection
|
10007926
|
M&E - TANK: ABOVE GROUND STORAGE - REF - GRADING FB-759 - 763
|
10007927
|
REPLACING WOODEB SLEEPERS IN TK FIELD & PIPE ALLEY
|
10007928
|
M&E-TANK:ABOVE GRND STORAGE-REF- W/CONE ROOF FB-731
|
10007929
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-737
|
10007930
|
M&E-TANK:ABOVE GRND STORAGE-REF- REVISE HEADER FB-751
|
10007931
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-768
|
10007932
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-714 & 715
|
10007933
|
M&E - TANK: ABOVE GROUND STORAGE - REFINING TANK FB-741
|
10007934
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIREWALL DRAIN FB-716
|
Asset No.
|
Asset Description
|
10007935
|
M&E-TANK:ABOVE GRND STORAGE-REF- REVISE PIPING FB-734
|
10007936
|
M&E-TANK:ABOVE GRND STORAGE-REF- LEVEL SYSTEM FB-766
|
10007938
|
M&E-TANK:ABOVE GRND STORAGE-REF- TRACE GAGE LINE FB-767
|
10007939
|
M&E-TANK:ABOVE GRND STORAGE-REF- FOAM INJ.NOZZLE FB-752
|
10007940
|
M&E-TANK:ABOVE GRND STORAGE-REF- TRACE GAGE LINE FB-767
|
10007941
|
M&E-TANK:ABOVE GRND STORAGE-REF- FLEX ROOF DRAIN FB-740
|
10007942
|
M&E-TANK:ABOVE GRND STORAGE-REF- REVISE PIPING FB-734
|
10007943
|
M&E-TANK:ABOVE GRND STORAGE-REF- REVISE PIPING FB-734
|
10007944
|
M&E-TANK:ABOVE GRND STORAGE-REF- LEVEL INDICATOR FB-767
|
10007945
|
M&E-TANK:ABOVE GRND- FOAMITE NOZZLES TK 724
|
10007946
|
M&E - TANK: ABOVE GROUND STORAGE - TK 771
|
10007947
|
M&E-TANK: FLEX.ROOF DRAIN TK 740
|
10007948
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLASS BTM. FB-742
|
10007949
|
TANK ABOVE GRND - EPOXY FLOOR TK 708 (PX-3513)
|
10007950
|
M&E-TANK:ABOVE GRND STORAGE-REF- EPOXY FLOOR FB-723
|
10007951
|
M&E - TANK: ABOVE GROUND STORAGE - REF - NOZZLE FB-703
|
10007952
|
M&E-TANK:ABOVE GRND STORAGE-REF- S/N 8421318701 FB-701
|
10007953
|
M&E-TANK:ABOVE GRND STORAGE-REF- MIXER NOZZLE FB-701
|
10007954
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-710
|
10007955
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-709
|
10007956
|
TANK: ABOVE GROUND STORAGE- REF - CONE ROOF TK-745
|
10007957
|
CONVERT TK757 TO LDED & TK 732 TO TYPE A
|
10007958
|
M&E-TANK:ABOVE GRND STORAGE-REF- LIGHTNIN W/25HP FB-750
|
10007959
|
M&E-TANK:ABOVE GRND STORAGE-REF- FIBERGLAS FLOOR FB-744
|
10007963
|
RAILROAD EQPT RR40 RAIL LOADING FACILITY UPGRADE
|
10010043
|
DYED LS1 AND LS2
|
10010056
|
RAIL CLASS YARD EXPANSION
|
10010072
|
UPGD FIRE PROT ON BUTANE SPHERE
|
10010075
|
INSTAL LEVL ALRM RV COLLECTN PO
|
10010076
|
DCS INSTLN OM/CHG ORDR EX C&O P
|
10010689
|
MERCAPTAN INJECTION SYSTEM
|
10011037
|
RESIDENCE TANK FB-745 CONVERSION
|
10011045
|
RESIDENCE TANK FB-745 CONVERSION
|
10011049
|
MERCAPTAN INJECTION SYSTEM
|
10011159
|
FB728 TANK INTERNAL FLOATING PAN AND CONE ROOF
|
10011333
|
ROOF REPLACEMENT - TANK FB720
|
10011415
|
M&E - I.S.B.L. - INSTRUMENTS - REFINING
|
10011416
|
PIPING TO UNLOAD FIELD BUTANE
|
10011454
|
FLOATING SUCTION - FB731 HVN TANK
|
10011482
|
M&E - I.S.B.L. - LINES, PIPING
|
10011491
|
TANKFIELD PIPING - DDU ULSD OSBL
|
10011494
|
TANKFIELD PIPING PLATFORMS - DDU ULSD OSBL
|
Asset No.
|
Asset Description
|
10011545
|
FLOAT SUCTION - FB771 DEBUTANIZED VIRGIN NAPTHA TK
|
10011680
|
TANKFIELD PIPING - DDU ULSD OSBL
|
10011922
|
M&E - ISBL,LINES, PIPING - FOR TK 757 (PX-3505)
|
10011923
|
4" PIPING - LCO RAILRACK
|
10011978
|
TANK 729 ROOF UPGRADE
|
10012299
|
PIPES & VALVES - ULSD OSBL HANDLING
|
10012301
|
MIXER-GD719A - TANK-FB719 - ULSD OSBL HANDLING
|
10012302
|
TANK MODIFICATIONS-FB703, FB710, FB711 - ULSD OSBL
|
10012303
|
INSTRUMENTATION - ULSD OSBL HANDLING
|
10012322
|
M&E-I.S.B.L.-LINES, PIPING-REF- 2409'LF GASOL
|
10012323
|
M&E - I.S.B.L. - 4" LEAD-FREE CIRCULATION LINE
|
10012613
|
ETHANOL IMPLEMENTATION - TANK 740 LOADING PUMP
|
10012614
|
ETHANOL IMPLEMENTATION - TANK 740 LOADING STATION
|
10012615
|
ETHANOL IMPLEMENTATION - PIPES, VALVES & FITTINGS
|
10012616
|
ETHANOL IMPLEMENTATION - TANK 758 ROOF
|
10012995
|
TANK FB-752 - DOUBLE BOTTOM FLOOR
|
10013027
|
ISBL LINES & PIPING - IMPROVE C3, C4, LPG HANDLING
|
10013028
|
CONCRETE PIER SUPPORTS - LCO RAILRACK
|
10013810
|
M&E - FIRE/SAFETY EQPT - REFINING WTR.TO GA-759S
|
10013886
|
TANK FB-752 - DOUBLE BOTTOM FLOOR
|
10014101
|
GA-771 DUAL TANDEM SEAL ASSEMBLY
|
10014102
|
GA-771S DUAL TANDEM SEAL ASSEMBLY
|
10014103
|
GA-772 DUAL TANDEM SEAL ASSEMBLY
|
10014104
|
GA-772S DUAL TANDEM SEAL ASSEMBLY
|
10014319
|
OIL MOVEMENT (O.M.) -BLOCK / BLEED VALVES & PIPING
|
10014335
|
GA-780 HVN CHARGE PUMP
|
|
FB-707 TANK MODIFICATIONS - WET GAS SCRUBBER
|
10014814
|
LPG RERUN PUMP WITH VFD DRIVE - GA-758
|
10014815
|
PIPE, VALVES, AND FITTINGS- OFF-SPEC LPG RERUN SYS
|
10015864
|
FB-723 Tank Bottom
|
10016601
|
FB-717 (2 SETS OF 5 SAMPLE TABS)
|
10016602
|
FB-718 (2 SETS OF 5 SAMPLE TABS)
|
10016603
|
FB-719 (2 SETS OF 5 SAMPLE TABS)
|
10016604
|
FB-720 (2 SETS OF 5 SAMPLE TABS)
|
10016605
|
FB-726 (2 SETS OF 5 SAMPLE TABS)
|
10016606
|
FB-730 (2 SETS OF 8 SAMPLE TABS)
|
10016607
|
FB-732 (2 SETS OF 8 SAMPLE TABS)
|
10016608
|
FB-733 (2 SETS OF 8 SAMPLE TABS)
|
10016609
|
FB-734 (2 SETS OF 8 SAMPLE TABS)
|
10016610
|
FB-723 (2 SETS OF 8 SAMPLE TABS)
|
10016611
|
FB-725 (2 SETS OF 5 SAMPLE TABS)
|
10016612
|
FB-729 (2 SETS OF 5 SAMPLE TABS)
|
Asset No.
|
Asset Description
|
10016613
|
FB-740 (2 SETS OF 5 SAMPLE TABS)
|
10016614
|
FB-748 (2 SETS OF 5 SAMPLE TABS)
|
10016615
|
FB-750 (2 SETS OF 5 SAMPLE TABS)
|
10016616
|
FB-752 (2 SETS OF 5 SAMPLE TABS)
|
10017148
|
FB-701 AUTOMATIC TANK GAUGING SYSTEM
|
10017149
|
FB-702 AUTOMATIC TANK GAUGING SYSTEM
|
10017150
|
FB-753 AUTOMATIC TANK GAUGING SYSTEM
|
10017151
|
FB-723 AUTOMATIC TANK GAUGING SYSTEM
|
10017152
|
FB-740 AUTOMATIC TANK GAUGING SYSTEM
|
10017153
|
FB-725 AUTOMATIC TANK GAUGING SYSTEM
|
10017154
|
FB-729 AUTOMATIC TANK GAUGING SYSTEM
|
10017155
|
FB-748 AUTOMATIC TANK GAUGING SYSTEM
|
10017156
|
FB-750 AUTOMATIC TANK GAUGING SYSTEM
|
10017157
|
FB-752 AUTOMATIC TANK GAUGING SYSTEM
|
10017158
|
FB-714 AUTOMATIC TANK GAUGING SYSTEM
|
10017159
|
FB-715 AUTOMATIC TANK GAUGING SYSTEM
|
10017160
|
FB-741 AUTOMATIC TANK GAUGING SYSTEM
|
10017161
|
ELECTR./CIVIL INFRASTRUCTURE - AUTO TANK GAUGING
|
10017162
|
AUTOMATIC TANK GAUGING PC HARDWARE
|
10017163
|
AUTOMATIC TANK GAUGING PC SOFTWARE (ENTIS XL)
|
10017722
|
PIPE, VALVES, FITTINGS
|
10017728
|
FB-716 NEW ROOF, INTERNAL COATING, AND GAUGE POLE
|
10017729
|
FB-718 NEW GAUGE POLE AND COATING
|
10017730
|
DISTILLATE SURGE TANK CONTROL VALVE USV-718
|
10017731
|
GASOLINE SURGE TANK CONTROL VALVE USV-716
|
10017732
|
TANK 716 LEVEL GAUGE LT-7716
|
10017733
|
TANK 718 LEVEL GAUGE LT-7718
|
10017734
|
TANK 718 TEMPERATURE TRANSMITTER TUT-7718
|
10017735
|
TANK 716 TEMPERATURE TRANSMITTER TUT-7716
|
10017736
|
TANK 718 HIGH LEVEL SWITCH LSHH-7718
|
10017737
|
TANK 716 HIGH LEVEL SWITCH LSHH-7716
|
10017738
|
4” PIPING FROM FB-727 TO FB-733
|
10017738
|
4" PIPING FROM FB-727 TO FB-733
|
10019266
|
SAMPLE TAPS FOR TANK 711
|
10019401
|
FB-705 CONE ROOF
|
10019402
|
FB-705 ALUMINUM INTERNAL FLOATING ROOF
|
10019403
|
FB-705 FOAM CHAMBERS
|
10019508
|
TANK 703 NEW DOUBLE BOTTOM
|
10019509
|
TANK 703 FOAM CHAMBERS
|
10019531
|
TANK 703 NEW BERM
|
10019755
|
PIPE/VALVES/FITTINGS - PUMP SUCTION AND DISCHARGE
|
10021206
|
LEVEL TRANSMITTER: TKS 711,717,726,727,730,733,734
|
Asset No.
|
Asset Description
|
10021207
|
TEMP TRANSMITTERS: TKS 711,717,726,727,730,733,734
|
10021208
|
LEVEL ALARMS: TKS 711,717, 726,727,730, 733,734
|
10021209
|
LADDER ON TANK FB-741
|
10021210
|
LADDER ON TANK FB-715
|
10021211
|
PLATFORM FOR FB-702
|
10021212
|
PLATFORM FOR FB-717
|
10021213
|
PLATFORM FOR FB-752
|
10021214
|
GAUGE POLE FOR FB-711
|
10021215
|
NEW NOZZLES FOR FB-726 (NO GAUGE POLE)
|
10021216
|
GAUGE POLE FOR FB-727
|
10021217
|
GAUGE POLE FOR FB-730
|
10021218
|
GAUGE POLE FOR FB-733
|
10021219
|
GAUGE POLE FOR FB-734
|
10021220
|
CONTROL SYSTEM SOFTWARE
|
10022256
|
PIPING FOR KEROSENE INJECTION INTO HEATER OIL
|
10022357
|
FB-753 NEW DOUBLE BOTTOM WITH COATING
|
10022358
|
FB-753 TANK BASIN UPGRADE
|
10022462
|
FB-709 NEW DOUBLE BOTTOM WITH COATING
|
10022463
|
FB-709 TANK BASIN UPGRADE
|
10022797
|
EMERGENCY SHUT-OFF VALVE USV-6754 & CONDUIT/CABLE
|
10022798
|
PIPING ASSOCIATED WITH USV-6754
|
10022799
|
LEVEL TRANSMITTER: TANK 747
|
10022800
|
TEMP TRANSMITTERS TANK 747
|
10022801
|
LEVEL ALARM: TANK 747
|
10022802
|
CONTROL SYSTEM SOFTWARE
|
10023702
|
FB-712 NEW DOUBLE BOTTOM
|
10023703
|
FB-712 FOAM PIPING AND CHAMBERS
|
30000664
|
Electrical/Instrument Components
|
30001339
|
Concrete/Earth
|
95000461
|
Repair Costs
|
95000462
|
Repair Costs
|
99000364
|
TANK 727 FLOOR COATING & REPAIRS
|
99000370
|
TANK 764- NEW DOUBLE BOTTOM FLOOR
|
99000371
|
TANK 764 - MAJOR PLANNED UPGRADES
|
99000445
|
TANK 718 NEW CONE ROOF & COATING
|
99000454
|
FB-736 DOUBLE BOTTOM FLOOR
|
99000455
|
FB-736 CONE ROOF
|
99000765
|
FB-701 TANK RESTORATION COSTS
|
99000855
|
FB-728 MISC. REPAIRS AND COATINGS
|
99000947
|
FB-714 RING #1
|
99000948
|
FB-714 MISC. BOTTOM PATCHING
|
99000972
|
FB-727 SECOND COURSE PARTIAL REPLACEMENT
|
Asset No.
|
Asset Description
|
99001051
|
FB-771 PRIMARY SEAL
|
99001052
|
FB-771 SECONDARY SEAL
|
99001053
|
FB-771 ERF SUMP
|
99001159
|
FB-771 TANK BASIN UPGRADE
|
99001320
|
FB-753 TANK RESTORATION
|
99001460
|
FB-731 OUTER RIM REPLACE AND TANK INSP
|
99001477
|
FB-709 CONE ROOF REPLACEMENT
|
99001667
|
FB-702 MISC REPAIRS TO PRIMARY & SECONDARY SEALS;
|
99001668
|
FB-715 SHELL REPAIRS
|
99001675
|
FB-747 BOTTOM REPAIRS
|
10005992
|
M&E - I.S.B.L.-INSTRUMENTS-REF- SILVER GASOLINE
|
10006089
|
M&E-I.S.B.L.-LINES, PIPING-REF- TK 705 HVN SVC
|
10006104
|
FACILITIES TO BLEND RR 40 DSL IN TK 744
|
10006213
|
M&E-I.S.B.L.-LINES, PIPING-REF- L.FREE PREMIUM
|
10006218
|
M&E-I.S.B.L.-LINES, PIPING-REF- INSUL.&HT.TRACE crude line
|
10006220
|
M&E-I.S.B.L.-LINES, PIPING-REF- INSUL.&HT.TRACE crude line
|
10006238
|
M&E-I.S.B.L.-LINES, PIPING-REF- SILVER GASOLINE
|
10006247
|
M&E - LINES, ELECTRICAL LINES: - EXT LTNG FB-750
|
10006268
|
M&E - PUMP UNIT - REFINING - GA730S FLO BYPS
|
10006289
|
M&E - PUMP UNIT - REFINING - C3 LOADING
|
10006320
|
M&E - PUMP UNIT - REFINING - SITE PREP. GA - 778
|
10006009
|
M&E-I.S.B.L.-LINES, PIPING-REF- SEGREGATE RR40
|
10006056
|
M&E-I.S.B.L.-LINES, PIPING-REF- PARALLEL CRUDE
|
10007214
|
M&E - ANALYTICAL EQPT - REFINING LABORATORY EQPT - LPG Upgrade
|
10007220
|
M&E - REFINING COMPRESSOR UNIT - ELECTRICAL:LPG facility upgrade
|
10007307
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - TRACK #6
|
10007337
|
M&E - I.S.B.L.-INSTRUMENTS-REF- CETANE IMPROVR gatepak
|
10007353
|
M&E - I.S.B.L. - INSTRUMENTS - REFINING upgrade LPG alarms
|
10007354
|
LPG/BUTANE TV SURVIELLANCE & REMOTE STOP VALVES
|
10007357
|
M&E - I.S.B.L. - INSTRUMENTS - REFINING LPG upgrade
|
10007358
|
M&E - ISBL INSTRUMENTS- REMOTE TRIP LPG/BUTANE
|
10007464
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L. LPG Upgrade
|
10007466
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L. LPG facility upgrade
|
10007470
|
M&E-I.S.B.L.-LINES, PIPING-REF- LPG FACIL UPGRD
|
10007474
|
M&E-I.S.B.L.-LINES, PIPING-REF- RR40 DCO HEADER
|
10007475
|
CONVERT FB-756 AST INTO WATER/GASO SEPARATOR
|
10007527
|
M&E - LINES, ELECTRICAL LINES: - LPG Upgrade
|
10007529
|
M&E - LINES, ELECTRICAL LINES: - LPG facility upgrade
|
10007531
|
M&E - LINES, ELECTRICAL LINES: - ALARMS LPG AREA
|
10007555
|
M&E - PUC CONST-AOC RFG,TRANS, SP, N LPG facility upgrade
|
10007587
|
M&E-TANK:ABOVE GRND STORAGE-REF- S/N 8421318702 FB-729 Mixers
|
10007606
|
M&E-TANK:ABOVE GRND STORAGE-REF- S/N 8421318702 FB-729 Mixers
|
Asset No.
|
Asset Description
|
10007613
|
M&E - FIRE/SAFETY EQPT - REFINING LPG TK.LOAD LIN
|
10007614
|
M&E - GARAGE, SERVICE TOOLS & EQUIPMENT
|
10007615
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- WARNING LIGHTS
|
10007617
|
TRACK 4 - 1500LF
|
10007618
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF001LF1500
|
10007619
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF001LF1500
|
10007620
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF0086-107H
|
10007621
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF0086-107H
|
10007622
|
M&E - GARAGE, SERVICE TOOLS & EQUIPMENT
|
10007623
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- RAILROAD SPUR
|
10007624
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- C3 LOADING
|
10007625
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- CAS'GHD.UNLOAD.
|
10007626
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- FIELD C4 UNLOAD
|
10007627
|
M&E - GARAGE,SERVICE TOOLS & EQUIPMENT - REFINING
|
10007628
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF005 LPG RACKS
|
10007629
|
M&E-GARAGE,SERV TOOLS & EQPT-REF- EF005 LPG RACKS
|
10007630
|
M&E -GARAGE,SERV TOOLS & EQPT-REF- EF005 LPG RACKS
|
10007631
|
M&E -GARAGE,SERV TOOLS & EQPT-REF- FIELD C4 UNLOAD
|
10007632
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - GOODALL
|
10007633
|
M&E - GARAGE,SERVICE TOOLS & EQUIPMENT - REFINING
|
10007634
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - NU 5
|
10007635
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - EF006
|
10007636
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - EF006
|
10007637
|
M&E - GARAGE,SERVICE TOOLS & EQPT - REF - EF006
|
10007638
|
M&E -GARAGE,SERV TOOLS & EQPT-REF- MOVE SPOUTS 3T2
|
10007639
|
M&E - GARAGE,SERVICE TOOLS & EQUIPMENT - REFINING
|
10007640
|
M&E - GARAGE,SERVICE TOOLS & EQUIPMENT - REFINING
|
10007641
|
M&E- RR CASINGHEAD UNLOAD GASOLINE (PX-524)
|
10007642
|
M&E - I.S.B.L. - INSTRUMENTS - REFINING
|
10007643
|
M&E - I.S.B.L.-INSTRUMENTS-REF- MERCAPTAN
|
10007644
|
M&E - I.S.B.L.-INSTRUMENTS-REF- STORE METHANOL
|
10007645
|
M&E - I.S.B.L. - LINES, PIPING - REF - 3"4" 122'
|
10007646
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L.
|
10007647
|
M&E - I.S.B.L. - LINES, PIPING - REF - NU 2
|
10007648
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L.
|
10007649
|
M&E - I.S.B.L. - LINES, PIPING - REF - C3 LOADING
|
10007650
|
M&E-I.S.B.L.-LINES, PIPING-REF- CASEH'D.UNLOAD
|
10007651
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L.
|
10007652
|
M&E - I.S.B.L. - LINES, PIPING - REFINING I.S.B.L.
|
10007654
|
M&E - LINES, ELECTRICAL LINES: - LIGHT FIXTURES
|
10007655
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
10007656
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
Asset No.
|
Asset Description
|
10007657
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
10007658
|
M&E - LINES, ELECTRICAL LINES: - FIELD C4 UNLOAD
|
10007659
|
M&E - LINES, ELECTRICAL LINES: - FLOODLIGHT
|
10007660
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
10007661
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
10007662
|
M&E - LINES, ELECTRICAL LINES: - EF001
|
10007663
|
M&E - LINES, ELECTRICAL LINES: -
|
10007664
|
M&E - LINES, ELECTRICAL LINES: -
|
10007665
|
M&E - LINES, ELECTRICAL LINES: - FIELD C4 UNLOAD
|
10007666
|
M&E - LOADING RACKS - REF FURNACE OIL TO RAIL RACK
|
10007667
|
M&E - PUMP UNIT - REFINING - CAS'GHD.RUNDOWN GA-784
|
10010050
|
LPG RR LIGHTING UPGRD & SHELTER
|
10011481
|
M&E - I.S.B.L. - LINES, PIPING
|
10016485
|
LAND IMPROVEMENTS FOR CLASS YARD EXPANSION
|
10016486
|
NEW RAILROAD FOR CLASS YARD EXPANSION
|
10016487
|
SIX NAPHTHA LOADING ARMS
|
10016488
|
NAPHTHA LOADING - PIPES/VALVES/FITTINGS
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY (in Barrels)
|
Mandan
|
FB-701
|
96,000
|
Mandan
|
FB-702
|
96,000
|
Mandan
|
FB-703
|
96,000
|
Mandan
|
FB-705
|
96,000
|
Mandan
|
FB-706
|
96,000
|
Mandan
|
FB-707
|
32,900
|
Mandan
|
FB-708
|
30,000
|
Mandan
|
FB-709
|
30,000
|
Mandan
|
FB-710
|
30,000
|
Mandan
|
FB-711
|
30,000
|
Mandan
|
FB-712
|
30,000
|
Mandan
|
FB-714
|
30,000
|
Mandan
|
FB-715
|
20,000
|
Mandan
|
FB-716
|
15,000
|
Mandan
|
FB-717
|
43,000
|
Mandan
|
FB-718
|
30,000
|
Mandan
|
FB-719
|
30,000
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY (in Barrels)
|
Mandan
|
FB-720
|
30,000 (OOS)
|
Mandan
|
FB-721
|
10,000
|
Mandan
|
FB-722
|
10,000
|
Mandan
|
FB-723
|
96,000
|
Mandan
|
FB-724
|
96,000 (OOS)
|
Mandan
|
FB-725
|
96,000
|
Mandan
|
FB-726
|
96,000
|
Mandan
|
FB-727
|
96,000
|
Mandan
|
FB-728
|
96,000
|
Mandan
|
FB-729
|
96,000
|
Mandan
|
FB-730
|
96,000
|
Mandan
|
FB-731
|
96,000
|
Mandan
|
FB-732
|
30,000
|
Mandan
|
FB-733
|
96,000
|
Mandan
|
FB-734
|
96,000
|
Mandan
|
FB-737
|
20,000 (OOS)
|
Mandan
|
FB-738
|
43,000
|
Mandan
|
FB-740
|
20,000
|
Mandan
|
FB-741
|
15,000
|
Mandan
|
FB-742
|
30,000 (OOS)
|
Mandan
|
FB-743
|
20,000
|
Mandan
|
FB-744
|
24,000
|
Mandan
|
FB-745
|
20,000
|
Mandan
|
FB-746
|
700
|
Mandan
|
FB-747
|
96,000
|
Mandan
|
FB-748
|
96,000
|
Mandan
|
FB-749
|
300 (OOS)
|
Mandan
|
FB-750
|
96,000
|
Mandan
|
FB-751
|
96,000
|
Mandan
|
FB-752
|
96,000
|
Mandan
|
FB-753
|
96,000
|
Mandan
|
FB-754
|
96,000
|
Mandan
|
FB-755
|
96,000
|
Mandan
|
FB-756
|
24,000
|
Mandan
|
FB-758
|
5,000
|
Mandan
|
FB-764
|
96,000
|
Mandan
|
FB-766
|
22,000
|
Mandan
|
FB-767
|
8,000
|
Mandan
|
FB-768
|
1,000 (OOS)
|
Mandan
|
FB-771
|
96,000
|
Mandan
|
FB-773
|
12
|
Mandan
|
FB-774
|
21
|
Asset No.
|
Asset Description
|
10012941
|
PIPING - LCO TO TRUCK RACK LOADING SYSTEM
|
10004434
|
M&E -I.S.B.L.-INSTRUMENTS-REF -LOADING RACK
|
10002558
|
PIPING, CONTAINMENT PAD, ETC. FOR VACUUM TRUCKS
|
10004359
|
M&E-I.S.B.L.-LINES, PIPING-REF-HVY FUEL OIL RK
|
10005754
|
DCO TRUCK LOAD OUT
|
10002553
|
DCO TRUCK LOAD OUT
|
10011460
|
SUCTION AND DISCHARGE PIPING- BLACK WAX TRUCK RACK
|
10011457
|
CONCRETE PAD & DRAIN - BLACK WAX TRUCK RACK
|
10011470
|
CONCRETE PAD & DRAIN - BLACK WAX TRUCK RACK
|
10005758
|
HPD BLACK WAX UNLOADING
|
10011458
|
CONRETE PUMP PAD - BLACK WAX TRUCK RACK
|
10004358
|
M&E-I.S.B.L.-LINES, PIPING-REF-CRUDE OIL RACK
|
10004272
|
M&E-I.S.B.L.-LINES, PIPING-REF-CRUDE UNLOADING
|
10011459
|
PUMP - BLACK WAX TRUCK RACK
|
10011471
|
PUMP - BLACK WAX TRUCK RACK
|
10011473
|
PUMP - BLACK WAX TRUCK RACK
|
10011472
|
PUMP - BLACK WAX TRUCK RACK
|
10004491
|
M&E-GARAGE, SERV TOOLS & EQPT-REF-CRUDE OIL RACK
|
10011786
|
PUMP - BLACK WAX TRUCK RACK
|
10014884
|
BLR VAPOR RECOVERY SYSTEM COMPRESSION
|
10019965
|
BUTANE LOADING RACK STRUCTURAL REINFORCEMENT
|
10014885
|
BLR VAPOR RECOVERY SYSTEM AUTOMATION
|
10013156
|
BUTANE LOADING RACK PIPING
|
10004441
|
M&E -I.S.B.L.-INSTRUMENTS-REF-BLR TRC GROUDNG
|
10004363
|
M&E-I.S.B.L.-LINES, PIPING-REF-BUTANE LOADING
|
10004122
|
M&E-PROCESS UNIT COST CONST-AOC -BUTANE LOAD SPT
|
10013452
|
LAND (UNION PACIFIC RR TRACKS & PROPERTY)15 ACRES
|
10020131
|
LOADING ARMS/FALL PROTECTION SPOT 1/2 - MODIFY LOA
|
10013453
|
RAILROAD TRACKS
|
10011207
|
PIPING/CONTROL VALVES - ALKYLATE RAIL LOADING RACK
|
10011208
|
VAPOR RECOVERY SYS W/ WALKWAY- ALKY RAIL LOAD RACK
|
10004129
|
M&E- REF OMD:OFFLOAD KEROSENE FROM RAIL
|
10004139
|
M&E -LOADING RACKS -REF
|
10011258
|
PIPING/CONTROL VALVES - ALKYLATE RAIL LOADING RACK
|
10004138
|
M&E -LOADING RACKS -REF
|
Asset No.
|
Asset Description
|
10004493
|
M&E-GARAGE, SERV TOOLS & EQPT-REF-TANK CAR LOAD
|
10014303
|
BAKKEN CRUDE UNLOADING ARM
|
10011259
|
VAPOR RECOVERY SYS W/ WALKWAY- ALKY RAIL LOAD RACK
|
10004165
|
M&E -I.S.B.L.-INSTR -REF BLR U/G RAIL SPOT CAMERA
|
10003954
|
RAILROAD EQUIPMENT TANK CAR -
|
10011209
|
CONCRETE BASE @ VAPOR RECOVERY-ALKY RAIL LOAD RACK
|
10004365
|
M&E -I.S.B.L. -LINES, PIPING -REF -UN TRACK
|
10003955
|
RAILROAD EQUIPMENT TANK CAR -FREIGHT
|
10020134
|
TANK 188
|
10020127
|
F-848 PP STORAGE BULLET
|
10020128
|
F-849 PP STORAGE BULLET
|
10020135
|
PIPING FROM TLR TO TANKAGE
|
10048457
|
TANK 245
|
99000879
|
TANK 326 TURNAROUND IN 2014
|
10020136
|
STRUCTURAL STEEL FOR PIPING AND RELATED TO TANK
|
10017221
|
2013 PHASE 1 WAXEY TANK 186
|
10020129
|
J-988A PP LOADING PUMPS
|
10020130
|
J-988B PP LOADING PUMPS
|
10003994
|
M&E -TANK: ABV GRND STRAGE -REF -WATER DRAW SYS
|
10020318
|
J-878A SOFT START FOR PUMP
|
99000409
|
TANK 328 RESTORATIONS - 2012
|
10003997
|
M&E -TANK: ABV GRND STRAGE -REF TANK -LSDHF
|
99000410
|
TANK 325 RESTORATIONS - 2012
|
10014608
|
BLACK WAX PUMP
|
10004106
|
M&E -PUMP UNIT -REF POWER UNIT -WATER DRAW SYS
|
10004389
|
M&E -I.S.B.L.-INSTRUMENTS-REF -IN-LINE BLENDER
|
99001120
|
TANK 204
|
10011012
|
9TH ROAD CROSSING UPGRADE
|
99000368
|
TANK 323 RESTORATION - 2011
|
10004175
|
M&E -I.S.B.L. -LINES, PIPING -REF -PIPELINE
|
10014744
|
UPGRADE SPILL CONTAINMENT 2011
|
10011819
|
TK-204 ROOF AND PROTECTIVE COATING TO BOTTOM
|
10011903
|
ROOF - TANK 322
|
10003968
|
M&E-TANK:ABV GRND STRAGE-REF SLC-OMD TK243 BOTTOM
|
10013154
|
TANK 326 (2) PUMPS
|
10003962
|
M&E-TANK-REF CAP-SLC-OMD TF2, TK242 FLR REPL
|
10011934
|
TK-246 & TK-247 PIPING - ROUTED FOR ULSD #1
|
10004003
|
M&E -TANK: ABV GRND STRAGE -REF -TF2 BOTOM REPL
|
10011967
|
TK-204 PIPING - ROUTED TO HSD BLENDER (ULSD CONV)
|
10004030
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004137
|
M&E -PIPING FAC TO GET ISOBUTANE TO BLENDING
|
10004332
|
M&E-I.S.B.L.-LINES, PIPING-REF-WATER DRAW SYS
|
Asset No.
|
Asset Description
|
10004004
|
M&E -TANK: ABV GRND STRAGE -REF -TF2 BOTTOM REPL
|
99000357
|
TANK 243 RESTORATION - 2010
|
10004328
|
M&E-I.S.B.L.-LINES, PIPING-REF-OFF-TEST LINE
|
10004311
|
M&E-I.S.B.L.-LINES, PIPING-REF-IN-LINE BLENDER
|
10002568
|
UNITED MS-B 4" DISTILLATE PIPELINE PUMP
|
10004284
|
M&E-I.S.B.L.-LINES, PIPING-REF-TF3 ALKYLATE LP
|
10003966
|
M&E-TANK-SLC-TANK 245 SECONDRY CONTAINMNT BOTTOM
|
10002991
|
9TH ROAD CROSSING UPGRADE - PIPING
|
10004123
|
M&E -PROCESS UNIT COST CONST- NEW BLACK WAX PUMP
|
10013059
|
UPGR TANK CONTAINMENT SYS - ADJACENT TANKS 206/268
|
10003964
|
M&E-TANK:ABV GRND STRAGE-CAP-SLC-OMD TK209 BOTTOM
|
10003969
|
M&E -TANK: ABV GRND STRAGE -REF ABV GRND STRAGE -
|
10003999
|
M&E -TANK: ABV GRND STRAGE -REF TANK -LSDHF
|
10011715
|
ULTRAFORMATE 6"RUNDOWN LINE-OMD CONTRL RM TO TK298
|
10004300
|
M&E-I.S.B.L.-LINES, PIPING-REF-UPGRADE@TANK206
|
10004196
|
M&E -I.S.B.L. -LINES, PIPING -REF I.S.B.L.: -
|
10004024
|
M&E -TANK: ABOVE GROUND STORAGE
|
10012940
|
PIPING FROM TANK 211 TO PIPELINE
|
10004126
|
M&E -PROC UNIT COST CONST- TF2, TK 141 BOTTOM REPL
|
10004025
|
M&E -TANK: ABOVE GROUND STORAGE
|
10014260
|
TANK GAUGING UPGRADES 2008
|
10013145
|
REMOTE TELEMETRY UNIT 3 - LEVEL TRANSMITTER
|
10004169
|
M&E - REF CAP-SLC-OMD TURBO RUNDOWN EXPANSION
|
10004026
|
M&E -TANK: ABV GRND STRAGE -REF TANK -INTERNAL
|
10004010
|
M&E -TANK: ABV GRND STRAGE -REF TANK -STEEL BOTTOM
|
10004290
|
M&E-I.S.B.L.-LINES, PIPING-REF-TANK FARM NO 2
|
10003961
|
M&E-TANK-REF TF3 TK307 BOTTOM REPL & INTERNL COAT.
|
10004013
|
M&E -TANK: ABV GRND STRAGE -REF -NEW BOTTOM&ROOF
|
10022472
|
TANK 190
|
10003956
|
M&E -PIPING 1997 OMD MCI
|
10004000
|
M&E -TANK: ABV GRND STRAGE -REF -142 BOT REPLACE
|
10002570
|
SECONDARY FLOOR - TANK # 252
|
10010218
|
REPLACE PRIMARY AND SECONDARY SEAL IN TANK 326
|
10003970
|
M&E -TANK: ABV GRND STRAGE -REF
|
10004128
|
M&E- REF TK 141 CONVERSN TO RR 40/LCCO
|
10004088
|
M&E -PUMP UNIT -REF POWER UNIT -P-857 TK FARM#3
|
10004390
|
M&E -I.S.B.L.-INSTRUMENTS-REF -IN-LINE-BLENDER
|
10004335
|
M&E -I.S.B.L. -LINES, PIPING -REF -TANK 206
|
10004028
|
M&E -TANK: ABV GRND STRAGE -REF -PH 79 CKM0865
|
10003981
|
M&E -TANK: ABV GRND STRAGE -REF TANK -FOAM DAM
|
10011469
|
ROAD CROSSING - TANK FARM # 2
|
10004351
|
M&E -I.S.B.L. -LINES, PIPING -REF -TF2
|
Asset No.
|
Asset Description
|
10003982
|
M&E -TANK: ABV GRND STRAGE -REF TANK -NEW BOTTOM
|
10003993
|
M&E -TANK: ABV GRND STRAGE -REF -PRIM/SEC SEALS
|
10004310
|
M&E-I.S.B.L.-LINES, PIPING-REF-INLINE BLENDER
|
10004021
|
M&E -TANK: ABOVE GROUND STORAGE
|
10002571
|
SECONDARY FLOOR - TANK # 308
|
10003973
|
M&E -TANK: ABV GRND STRAGE -REF -SECONDARY SEAL
|
10003971
|
M&E -TANK: ABV GRND STRAGE -REF
|
10003988
|
M&E -TANK: ABV GRND STRAGE -REF -PRIMARY/SC SEAL
|
10004017
|
M&E -TANK: ABV GRND STRAGE -REF TANK -PIPING
|
10004049
|
M&E -TANK: ABV GRND STRAGE -REF TANK -STEAM HEAT
|
10004298
|
M&E-I.S.B.L.-LINES, PIPING-REF-TF2 12" 1000'
|
10005760
|
OMD 813 A/B/C LOW FLOW SWITCH
|
10004046
|
M&E -TANK: ABV GRND STRAGE -REF -HTG LEVEL SYS
|
10004012
|
M&E -TANK: ABV GRND STRAGE -REF TANK -NEW BOTTOM
|
10003998
|
M&E -TANK: ABV GRND STRAGE -REF -HTG LEVEL SYS
|
10004029
|
M&E -TANK: ABV GRND STRAGE -REF -FIBERGLASS BTM
|
10003967
|
M&E-TANK-CAP-SLC-OMD PLATFRMS AT TK188 & TK246
|
10004355
|
M&E -I.S.B.L. -LINES, PIPING -REF -TF #2&3
|
10003972
|
M&E -TANK: ABV GRND STRAGE -REF TANK -EXTERNAL
|
10004164
|
M&E -I.S.B.L.-INSTR -REF GASOLINE COMPOSITOR
|
10004007
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004329
|
M&E-I.S.B.L.-LINES, PIPING-REF-MTBE CTL VALVE
|
10004034
|
M&E -TANK: ABV GRND STRAGE -REF -FIBERGLASS BTM
|
10004297
|
M&E-I.S.B.L.-LINES, PIPING-REF-TF2 12" X 650'
|
10004127
|
M&E -TF2, TK 297 PRIMARY SEAL REPL & INTRNL COATNG
|
10004155
|
M&E -LINES, ELECTRICAL LINES: -TF3 PUMP STA
|
10004047
|
M&E -TANK: ABV GRND STRAGE -REF -SN-90A2968501
|
10004327
|
M&E -I.S.B.L. -LINES, PIPING -REF -TF2 TF3
|
10004044
|
M&E -TANK: ABOVE GROUND STORAGE
|
10003965
|
M&E-TANK-REF CAP-SLC-OMD-TK328 SEAL REPL
|
10005764
|
OMD-U/G T-329 RV & PIPING
|
10004089
|
M&E -PUMP UNIT -REF POWER UNIT -P-860ATK FARM#3
|
10003995
|
M&E -TANK: ABV GRND STRAGE -REF -RING REPLACEMNT
|
10004353
|
M&E-I.S.B.L.-LINES, PIPING-REF-TF2 INSULATED
|
10004356
|
M&E-I.S.B.L.-LINES, PIPING-REF-TF#3 RELOCATE
|
10004294
|
M&E-I.S.B.L.-LINES, PIPING-REF-TANK FARM NO 3
|
10004016
|
M&E -TANK: ABV GRND STRAGE -REF -ALTAMONT CRUDE
|
10004027
|
M&E -TANK: ABV GRND STRAGE -REF TANK -INTERNAL
|
10004051
|
M&E -TANK: ABV GRND STRAGE -REF -UNLOADING PIPE
|
10003974
|
M&E -TANK: ABV GRND STRAGE -REF -SECONDARY SEAL
|
10003978
|
M&E -TANK: ABV GRND STRAGE -REF -HEIGHT EXTENSIN
|
10004463
|
M&E-GARAGE, SERV TOOLS & EQPT-REF-OVERFLOW BASIN
|
Asset No.
|
Asset Description
|
10014057
|
OMD LIFT STATION LEVEL TRANSMITTERS
|
10004061
|
M&E -PUMP UNIT -REF POWER UNIT -TK FARM #3
|
10003336
|
M&E-TANK:ABOVE GROUND STRAGE-REF FOUNDATIONS
|
10003076
|
UPGRADE J818 PUMP AT TANK 190
|
10003990
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004371
|
M&E -I.S.B.L.-INSTRUMENTS-REF -TF3 LIGHTNG U/G
|
10004081
|
M&E -PUMP UNIT -REF POWER UNIT -6" PRODUCTS PL
|
10004070
|
M&E -PUMP UNIT -REF POWER UNIT -P-751 8" PROD PL
|
10004084
|
M&E -PUMP UNIT -REF POWER UNIT -P-751 8" PROD PL
|
10003987
|
M&E -TANK: ABV GRND STRAGE -REF TANK -90A2965501
|
10004009
|
M&E -TANK: ABV GRND STRAGE -REF -JENSEN 605-1.5
|
10004035
|
M&E -TANK: ABV GRND STRAGE -REF -MODEL 308RSES30
|
10004430
|
M&E -I.S.B.L.-INSTRUMENTS-REF -OMD-TAS TERMNAL
|
10004350
|
M&E -I.S.B.L. -LINES, PIPING -REF -TANK 246
|
10003976
|
M&E -TANK: ABV GRND STRAGE -REF -SEAL EXTENSION
|
10003991
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TANK LEVEL
|
10003983
|
M&E -TANK: ABV GRND STRAGE -REF -PRIMARY SEALS
|
10004020
|
M&E -TANK: ABV GRND STRAGE -REF TANK -CONE ROOF
|
10011641
|
HONEYWELL BLENDING SYSTEM - COMPUTER HARDWARE
|
10003339
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004393
|
M&E-I.S.B.L.-INSTRUMENTS-REF-BUTANE BLENDING
|
10004006
|
M&E -TANK: ABV GRND STRAGE -REF -JENSEN 620-VA20
|
10004240
|
M&E-I.S.B.L.-LINES, PIPING-REF-6" & 8" PROD U/G
|
10004286
|
M&E -I.S.B.L. -LINES, PIPING -REF -TF #2
|
10004014
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TK 252 DIKE
|
10004065
|
M&E -PUMP UNIT -REF POWER UNIT -TF BLENDER-1
|
10004018
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TANK 243
|
10003996
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004033
|
M&E -TANK: ABV GRND STRAGE -REF TANK -VALVES
|
10004321
|
M&E -I.S.B.L. -LINES, PIPING -REF -TANK 141
|
10003975
|
M&E -TANK: ABV GRND STRAGE -REF TANK -FOAM DAM
|
10003985
|
M&E -TANK: ABV GRND STRAGE -REF -JENSEN F-605-5
|
10003989
|
M&E -TANK: ABV GRND STRAGE -REF -SECONDARY SEAL
|
10004050
|
M&E -TANK: ABV GRND STRAGE -REF -STEAM HEAT TRAC
|
10003337
|
M&E -TANK: ABOVE GROUND STORAGE
|
10003979
|
M&E -TANK: ABV GRND STRAGE -REF TANK -DEA STORAGE
|
10004160
|
M&E -LINES, ELECTRICAL LINES: -TF2 TANKS
|
10004336
|
M&E-I.S.B.L.-LINES, PIPING-REF-T #190 JUMPOVER
|
10004085
|
M&E -PUMP UNIT -REF POWER UNIT -TK FARM3#2
|
10004337
|
M&E -I.S.B.L. -LINES, PIPING -REF -TANK 325
|
10003980
|
M&E -TANK: ABV GRND STRAGE -REF -SECONDARY SEAL
|
10004002
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TANK BOTTOM
|
Asset No.
|
Asset Description
|
10003958
|
M&E -TOWER -REF TOWER -LSDHF BLNDR TWR
|
10004045
|
M&E -TANK: ABV GRND STRAGE -REF -INLET MANIFOLD
|
10004052
|
M&E -TANK: ABV GRND STRAGE -REF -BUTANE BLANKET
|
10004402
|
M&E -I.S.B.L.-INSTRUMENTS-REF -COMP. SAMPLER
|
10004115
|
M&E-PROCESS UNIT COST CONST-AOC -OCTANE BLENDER
|
10012334
|
TK-246 & TK-247 PIPING - ROUTED FOR ULSD #1
|
10004326
|
M&E-I.S.B.L.-LINES, PIPING-REF-T325 JP-4FILTER
|
10004415
|
M&E -I.S.B.L.-INSTRUMENTS-REF-AVGAS BLENDING
|
10003992
|
M&E -TANK: ABV GRND STRAGE -REF -PRIMARY/SE SEAL
|
10004001
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TANK BOTTOM
|
10004068
|
M&E -PUMP UNIT -REF POWER UNIT -TF BLENDER-1
|
10004334
|
M&E-I.S.B.L.-LINES, PIPING-REF-T-325 JUMPOVER
|
10004120
|
M&E -PROCESS UNIT COST CONST-TANK 309
|
10004161
|
M&E -LINES, ELECTRICAL LINES: -TF3 TK 309 PUMP
|
10003338
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004015
|
M&E -TANK: ABV GRND STRAGE -REF TANK -TANK 243
|
10004154
|
M&E -LINES, ELECTRICAL LINES: -TF4 FLOOD LIGHT
|
10004323
|
M&E -I.S.B.L. -LINES, PIPING -REF -TANK 309
|
10004341
|
M&E-I.S.B.L.-LINES, PIPING-REF-325TK CROSSOVER
|
10004022
|
M&E -TANK: ABV GRND STRAGE -REF TANK -ULR SERVICE
|
10004330
|
M&E-I.S.B.L.-LINES, PIPING-REF-T-325 JUMPOVER
|
10004345
|
M&E-I.S.B.L.-LINES, PIPING-REF-WATER SUC TF4
|
10003340
|
M&E -TANK: ABOVE GROUND STORAGE
|
10003984
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004074
|
M&E -PUMP UNIT -REF PUMP POWER UNIT-TK-206
|
10003986
|
M&E -TANK: ABOVE GROUND STORAGE
|
10004011
|
M&E -TANK: ABV GRND STRAGE -REF TANK -INSTALLATION
|
10004039
|
M&E -TANK: ABV GRND STRAGE -REF TANK -LOWER LEGS
|
10004086
|
M&E -PUMP UNIT -REF POWER UNIT -TK FARM #2
|
99001185
|
TANK 212 TURNAROUND
|
10020133
|
NEW PIPING FOR OLEFINS
|
10004347
|
M&E-I.S.B.L.-LINES, PIPING-REF-156-188-268-322
|
10002560
|
SECONDARY BOTTOM & COATING - TANK # 158
|
10023600
|
TANK 244 ABOVE GROUND TANK
|
10020108
|
J-928G - YELLOW WAX CHARGE PUMPS
|
10020109
|
J-928H - YELLOW WAX CHARGE PUMPS
|
10020110
|
J-928E - BLACK WAX CHARGE PUMPS
|
10020111
|
J-928F - BLACK WAX CHARGE PUMPS
|
10020317
|
J-878A BOOSTER PUMP
|
10004121
|
M&E-PROCESS UNIT COST CONST-AOC -J809 PRESSUR SW
|
10004075
|
M&E -PUMP UNIT -REF POWER UNIT -J823B 3HP
|
10004107
|
M&E -PUMP UNIT -REF POWER UNIT -J892 PUMP
|
Asset No.
|
Asset Description
|
10005741
|
J-813 & J813A MOTOR STARTERS
|
10004346
|
M&E -I.S.B.L. -LINES, PIPING -REF -TF 2 & 3
|
10002807
|
PRIMARY & SECONDARY SEALS FOR TANK #298
|
10017856
|
SLC ETHANOL RATIO BLENDING PIPING & EQUIPMENT
|
10017855
|
SLC ETHANOL RATIO BLENDING SKIDS
|
10016669
|
ETHANOL RAIL UNLOADING RACK
|
10023825
|
PIPING FOR SAFETY SHOWER -ETHANOL UNLDG RACK
|
99000880
|
TANK 142 TURNAROUND IN 2014
|
10004487
|
M&E-GARAGE, SERV TOOLS & EQPT-REF-142 TK FIREWALL
|
10005749
|
RELOCATE TK 155 OOS PRESSURE VENT
|
10005681
|
M&E-PROCESS UNIT COST CONST-AOC -TF2 PIPING T245
|
99000762
|
TANK 291 YEAR 2013 TURNAROUND
|
99001737
|
TANK 328 ABOVE GROUND STORAGE TANK
|
99001540
|
TANK 330 TURNAROUND
|
99001540
|
TANK 330 TURNAROUND
|
10020317
|
J-878A BOOSTER PUMP
|
TBD
|
TANK 427D
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
Salt Lake City
|
141
|
14,896
|
Salt Lake City
|
142
|
14,323
|
Salt Lake City
|
155
|
10,313
|
Salt Lake City
|
157
|
19,915
|
Salt Lake City
|
158
|
19,915
|
Salt Lake City
|
186
|
58,748
|
Salt Lake City
|
188
|
58,748
|
Salt Lake City
|
190
|
48,348
|
Salt Lake City
|
204
|
55,094
|
Salt Lake City
|
206
|
62,091
|
Salt Lake City
|
209
|
(OOS)
|
Salt Lake City
|
212
|
56,627
|
Salt Lake City
|
213
|
56,627
|
Salt Lake City
|
236
|
56,627
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
Salt Lake City
|
242
|
55,688
|
Salt Lake City
|
243
|
55,209
|
Salt Lake City
|
244
|
15,484
|
Salt Lake City
|
245
|
24,071
|
Salt Lake City
|
246
|
11,190
|
Salt Lake City
|
247
|
11,190
|
Salt Lake City
|
248
|
60,000
|
Salt Lake City
|
252
|
55,688
|
Salt Lake City
|
291
|
15,107
|
Salt Lake City
|
294
|
(OOS)
|
Salt Lake City
|
297
|
3,275
|
Salt Lake City
|
298
|
3,575
|
Salt Lake City
|
305
|
5,117
|
Salt Lake City
|
306
|
5,117
|
Salt Lake City
|
307
|
6,714
|
Salt Lake City
|
308
|
6,714
|
Salt Lake City
|
309
|
(OOS)
|
Salt Lake City
|
310
|
(OOS)
|
Salt Lake City
|
312
|
(OOS)
|
Salt Lake City
|
314
|
(OOS)
|
Salt Lake City
|
315
|
(OOS)
|
Salt Lake City
|
321
|
24,171
|
Salt Lake City
|
322
|
37,871
|
Salt Lake City
|
323
|
37,871
|
Salt Lake City
|
324
|
54,974
|
Salt Lake City
|
325
|
54,974
|
Salt Lake City
|
326
|
54,974
|
Salt Lake City
|
327
|
54,974
|
Salt Lake City
|
328
|
54,974
|
Salt Lake City
|
329
|
10,313
|
Salt Lake City
|
330
|
24,071
|
Salt Lake City
|
331
|
33,105
|
Salt Lake City
|
848
|
2,800
|
Salt Lake City
|
849
|
2,800
|
Salt Lake City
|
427A
|
606
|
Salt Lake City
|
427B
|
606
|
Salt Lake City
|
427C
|
905
|
Salt Lake City
|
427D
|
905
|
Asset No.
|
Asset Description
|
10013233
|
Offsites - Buildings - 241 RP&S Control Room
|
10013238
|
Offsites - Buildings - Blender In-Line
|
10013251
|
Offsites - Blending
|
10013258
|
Offsites - Onsite Piping
|
10013271
|
Offsites - Pumps
|
10013281
|
Offsites - Tankage - TK-000476
|
10013303
|
Offsites - Tankage - TK-007501
|
10013304
|
Offsites - Tankage - TK-011000
|
10013305
|
OFFSITES - TANKAGE - TK-011001 LCO
|
10013306
|
Offsites - Tankage - TK-011002
|
10013307
|
OFFSITES - TANKAGE - TK-011003 DIESEL
|
10013308
|
Offsites - Tankage - TK-011004
|
10013309
|
Tank - TK-013500 FIRE WATER
|
10013310
|
TANK 013501 FIRE WATER
|
10013311
|
Offsites - Tankage - TK-013502
|
10013312
|
Offsites - Tankage - TK-013503
|
10013313
|
Offsites - Tankage - TK-013504
|
10013314
|
Offsites - Tankage - TK-013505
|
10013315
|
OFFSITES - TANKAGE - TK-013506 JET FUEL
|
10013316
|
Offsites - Tankage - TK-013507
|
10013317
|
OFFSITES - TANKAGE - TK-013508 AVGAS
|
10013318
|
Offsites - Tankage - TK-013509
|
10013319
|
Offsites - Tankage - TK-013510
|
10013320
|
TANK 013511 BRINE WATER TANK
|
10013321
|
Offsites - Tankage - TK-013512
|
10013330
|
Offsites - Tankage - TK-036001
|
10013331
|
OFFSITES - TANKAGE - TK-036002 JET A
|
10013332
|
Offsites - Tankage - TK-076000
|
10013333
|
Offsites - Tankage - TK-080034
|
10013334
|
Offsites - Tankage - TK-080038
|
10013335
|
Offsites - Tankage - TK-080039
|
10013336
|
Offsites - Tankage - TK-080042
|
10013338
|
OFFSITES - TANKAGE - TK-080044 GASOLINE
|
10013339
|
Offsites - Tankage - TK-080049
|
10013340
|
Offsites - Tankage - TK-080050
|
Asset No.
|
Asset Description
|
10013341
|
Offsites - Tankage - TK-080051 AZ-BOB
|
10013342
|
Offsites - Tankage - TK-080055
|
10013343
|
OFFSITES - TANKAGE - TK-080062 NAPTHA
|
10013344
|
OFFSITES - TANKAGE - TK-080063 HS CAT FEED
|
10013345
|
Offsites - Tankage - TK-080064
|
10013346
|
Tank 080065
|
10013347
|
Offsites - Tankage - TK-080065 Resid
|
10013348
|
Offsites - Tankage - TK-080066
|
10013349
|
Offsites - Tankage - TK-080067
|
10013350
|
Offsites - Tankage - TK-080069
|
10013351
|
Offsites - Tankage - TK-080070 AVJET A
|
10013352
|
Offsites - Tankage - TK-080077
|
10013353
|
Offsites - Tankage - TK-080078
|
10013354
|
OFFSITES - TANKAGE - TK-080080 CRUDE
|
10013355
|
Offsites - Tankage - TK-080081
|
10013356
|
Offsites - Tankage - TK-080083
|
10013357
|
Offsites - Tankage - TK-080084 SLOP
|
10013358
|
Offsites - Tankage - TK-080085
|
10013359
|
Offsites - Tankage - TK-080087
|
10013360
|
Offsites - Tankage - TK-080089
|
10013361
|
Offsites - Tankage - TK-080090
|
10013362
|
Offsites - Tankage - TK-080091
|
10013363
|
Offsites - Tankage - TK-080209
|
10013364
|
OFFSITES - TANKAGE - TK-080210 GASOLINE
|
10013365
|
Offsites - Tankage - TK-080211
|
10013366
|
Offsites - Tankage - TK-080212
|
10013367
|
OFFSITES - TANKAGE - TK-080213 NAPTHA
|
10013368
|
Offsites - Tankage - TK-080214 Naptha
|
10013369
|
Offsites - Tankage - TK-080215
|
10013370
|
Offsites - Tankage - TK-080217 - FCCU Hvy Naptha
|
10013371
|
Offsites - Tankage - TK-080219
|
10013372
|
OFFSITES - TANKAGE - TK-080220 CARBOB
|
10013373
|
OFFSITES - TANKAGE - TK-080221 REFORMER CHARGE
|
10013374
|
Offsites - Tankage - TK-096000
|
10013375
|
Offsites - Tankage - TK-096059
|
10013376
|
Offsites - Tankage - TK-118066
|
10013377
|
Offsites - Tankage - TK-125002
|
10013378
|
Offsites - Tankage - TK-125003
|
10013379
|
OFFSITES - TANKAGE - TK-125004 HTU NAPTHA
|
10013384
|
OFFSITES - TANKAGE - TK-020426 SOUR WATER
|
10013387
|
Offsites - Vapor Recovery Unit
|
10013432
|
RP&S: MOV FOR P-1692
|
Asset No.
|
Asset Description
|
10013448
|
GEN PLT, Gasoline Blendin
|
10013456
|
P/L PIG LAUNCHER & RECEIVER - AT REFINERY
|
10013472
|
TANK 7501 DOUBLE BOTTOM
|
10013473
|
TANK 13505 DOUBLE BOTTOM
|
10013474
|
TANK 80034 DOUBLE BOTTOM
|
10013475
|
TK 80217 - DOUBLE TANK BOTTOM NAPHTHA
|
10013477
|
TANK 80216 - ALUMINUM DOME
|
10013478
|
TANK 96000 - ALUMINUM DOME
|
10013543
|
TANK 80216 - ALUMINUM DOME REFORMATE
|
10013544
|
TANK 7501 DOUBLE BOTTOM
|
10013545
|
TANK 13505 DOUBLE BOTTOM CRU 2/3 LT. NAPHTNA
|
10013563
|
TANK 80034 DOUBLE BOTTOM
|
10013564
|
TK 80217 - DOUBLE TANK BOTTOM
|
10013567
|
TANK 96000 - ALUMINUM DOME GASOLINE
|
10013608
|
RPS Analyzers and Instrumentation
|
10013646
|
80084 SAAB TANK RADAR PRO GAUGE
|
10013647
|
80062 SAAB TANK RADAR PRO GAUGE
|
10013648
|
80085 SAAB TANK RADAR PRO GAUGE
|
10013649
|
80070 SAAB TANK RADAR PRO GAUGE
|
10013650
|
36002 SAAB TANK RADAR PRO GAUGE
|
10013651
|
80068 SAAB TANK RADAR PRO GAUGE
|
10013652
|
80058 REX LEVEL GAUGES
|
10013653
|
80080 SAAB TANK RADAR PRO GAUGE
|
10013654
|
80219 SAAB TANK RADAR PRO GAUGE
|
10013655
|
80081 SAAB TANK RADAR PRO GAUGE
|
10013656
|
80089 SAAB TANK RADAR PRO GAUGE
|
10013657
|
80063 SAAB TANK RADAR PRO GAUGE
|
10013658
|
80061 SAAB TANK RADAR PRO GAUGE
|
10013659
|
80067 SAAB TANK RADAR PRO GAUGE
|
10013660
|
7201 SAAB TANK RADAR PRO GAUGE
|
10013661
|
80083 SAAB TANK RADAR PRO GAUGE
|
10013662
|
80065 REX LEVEL GAUGES
|
10013663
|
80064 REX LEVEL GAUGES
|
10013664
|
80082 REX LEVEL GAUGES
|
10013665
|
7501 SAAB TANK RADAR PRO GAUGE
|
10013666
|
80079 SAAB TANK RADAR PRO GAUGE
|
10013667
|
80066 REX LEVEL GAUGES
|
10013671
|
80087 SAAB TANK RADAR PRO GAUGE
|
10013674
|
80084 SAAB TANK RADAR PRO GAUGE
|
10013675
|
80062 SAAB TANK RADAR PRO GAUGE
|
10013676
|
80085 SAAB TANK RADAR PRO GAUGE
|
10013677
|
80070 SAAB TANK RADAR PRO GAUGE
|
Asset No.
|
Asset Description
|
10013678
|
36002 SAAB TANK RADAR PRO GAUGE
|
10013679
|
80068 SAAB TANK RADAR PRO GAUGE
|
10013680
|
80058 REX LEVEL GAUGES
|
10013681
|
80080 SAAB TANK RADAR PRO GAUGE
|
10013682
|
80219 SAAB TANK RADAR PRO GAUGE
|
10013683
|
80081 SAAB TANK RADAR PRO GAUGE
|
10013684
|
80089 SAAB TANK RADAR PRO GAUGE
|
10013685
|
80063 SAAB TANK RADAR PRO GAUGE
|
10013686
|
80061 SAAB TANK RADAR PRO GAUGE
|
10013687
|
80067 SAAB TANK RADAR PRO GAUGE
|
10013688
|
7201 SAAB TANK RADAR PRO GAUGE
|
10013689
|
80083 SAAB TANK RADAR PRO GAUGE
|
10013690
|
80065 REX LEVEL GAUGES
|
10013691
|
80064 REX LEVEL GAUGES
|
10013692
|
80082 REX LEVEL GAUGES
|
10013693
|
7501 SAAB TANK RADAR PRO GAUGE
|
10013694
|
80066 REX LEVEL GAUGES
|
10013695
|
80087 SAAB TANK RADAR PRO GAUGE
|
10013817
|
TANK 80090 DOUBLE BOTTOM
|
10013818
|
TANK 80066 DOUBLE BOTTOM
|
10013819
|
TANK 80049 DOUBLE BOTTOM
|
10013820
|
TANK 96000 DOUBLE BOTTOM
|
10013880
|
P-1691 CENTRIFUGAL PUMP - HORIZONTAL
|
10013927
|
TRANSMIX 600' PIPING & 3" VALVE
|
10013928
|
TRANSMIX TRANSMITTER (72-FT924)
|
10014112
|
72PV-0532 MINIMUM FLOW BYPASS
|
10014113
|
72FV-1302 FLOW CONTROL VALVE
|
10014114
|
72FT-1302 WEDGE METER/ TRANSMITTER
|
10014115
|
72FV-1303 FLOW CONTROL VALVE
|
10014116
|
72FT-1303 WEDGE METER/ TRANSMITTER
|
10014117
|
72PV-1304 MINIMUM FLOW BYPASS
|
10014118
|
72FV-1301 HVY CRUDE CONTROL VALVE (RP&S)
|
10014119
|
72FT-1301 WEDGE METER/TRANSMITTER
|
10014120
|
72FV-1306 FLOW CONTROL VALVE
|
10014121
|
72FT-1306 WEDGE METER/TRANSMITTER
|
10014132
|
Offsites - Tankage - TK-080216 CRU HN
|
10014314
|
TRANSMIX 600' PIPING & 3" VALVE
|
10014340
|
TK-80090 -RP&S FLOATING ROOF STORAGE TANK FUEL OIL
|
10014341
|
TK-76000 - RP&S DOUBLE BOTTOM INSTALLATION
|
10014348
|
TK-80083 - RP&S FIXED ROOF STORAGE TANK - SLOP OIL
|
10014349
|
RPS-2 ILB FTIR ANALYZER 72AIT613
|
10014350
|
RPS-2 ILB FTIR ANALYZER 72AIT614
|
Asset No.
|
Asset Description
|
10014351
|
RPS-2 ILB FTIR ANALYZERS PLC 72LCP612
|
10014425
|
TK-80211 GASOLINE DOUBLE BOTTOM
|
10014427
|
TANK - 80069 SLOP
|
10014777
|
FIRE FOAM PIPING FOR TANK 80212
|
10014778
|
FIRE FOAM PIPING FOR TANK 80216
|
10014779
|
FIRE FOAM PIPING FOR TANK 96000
|
10014780
|
TK-80068
|
10014783
|
TK-80071 CRUDE
|
10015027
|
TANK 80075
|
10015028
|
MIXERS (ME-931 AND ME-932) FOR TANK 80075
|
10015029
|
SAMPLE PUMP P-3619 FOR TANK 80075
|
10015030
|
PIPING / ELECTRICAL - TANK 80075
|
10015031
|
INSTRUMENTATION AND AUTOMATION - TANK 80075
|
10015032
|
TANK 80079 CRUDE
|
10015033
|
TANK 80079 MIXERS ME-919 AND ME-920
|
10015034
|
SAMPLE PUMP P-3583 FOR TANK 80079
|
10015035
|
TANK 80079 PIPING / ELECTRICAL
|
10015036
|
TANK 80079 INSTRUMENTATION AND AUTOMATION
|
10015043
|
TANK 80076
|
10015044
|
TANK 80076 SAMPLE PUMP P-3583 & MOTOR M-4572
|
10015045
|
TANK 80076 MIXERS & MOTORS ME-921/922, M-4568/4569
|
10015046
|
TANK 80076 PIPING / ELECTRICAL
|
10015047
|
TANK 80076 AUTOMATIC GAUGING
|
10015255
|
TANK 80058
|
10015256
|
TANK 80058 ELECTRICAL
|
10015257
|
TK 80058 SAMPLE PUMP P-3617 MOTOR M-4598/4596/4597
|
10015258
|
TK 80058 PIPING
|
10015259
|
TANK 80058 GAUGE INSTRUMENTATION AND AUTOMATION
|
10015260
|
TANK 80214 ELECTRICAL
|
10015261
|
TANK 80214 DOUBLE BOTTOM
|
10015262
|
TANK 80214 PUMP P-3616 AND MOTOR M-4596
|
10015263
|
TANK 80214 PIPING
|
10015264
|
TANK 80214 GAUGING INSTRUMENTATION AND AUTOMATION
|
10015804
|
TANK 80216 DOUBLE BOTTOM
|
10015805
|
TANK 80216 INSTRUMENTATION AND GAUGING
|
10015806
|
TANK 80216 ELECTRICAL
|
10015807
|
TANK 80216 SAMPLE PUMP P-3622 M-4609
|
10015808
|
TANK 80216 PIPING
|
10015959
|
TANK 80045 WITH FLOATING ROOF
|
10015960
|
TANK 80045 INSTRUMENTATION AND ELECTRICAL
|
10015961
|
TANK 80045 MIXER ME-0935, MOTOR M-4606,
|
10015962
|
TANK 80045 SAMPLE PUMP P-3621 AND MOTOR M-4608
|
Asset No.
|
Asset Description
|
10015963
|
TANK 80045 PIPING
|
10015964
|
TANK 80045 AUTOMATIC GAUGING
|
10015978
|
TANK 80033 DIESEL
|
10015979
|
TANK 80033 INSTRUMENTATION AND GAUGING
|
10015980
|
TANK 80033 ELECTRICAL
|
10015981
|
TANK 80033 PIPING
|
10015982
|
TANK 80033 SAMPLE PUMP
|
10015983
|
TANK 80033 MIXER AND MOTOR
|
10016540
|
TANK 80072
|
10016541
|
TANK 80072 SAMPLE PUMP MOTOR P-3620 M-4605
|
10016542
|
TANK 80072 MIXER ME-933 & MOTOR M-4603
|
10016543
|
TANK 80072 MIXER ME-934 & MOTOR M-4604
|
10016544
|
TANK 80072 ELECTRICAL
|
10016545
|
TANK 80072 INSTRUMENTATION AND AUTOMATION
|
10016546
|
TANK 80072 PIPING
|
10016548
|
TANK 80061
|
10016549
|
TANK 80061 SAMPLE PUMP MOTOR P-3637 & MOTOR M-4626
|
10016550
|
TANK 80061 MIXER ME-940 & MOTOR M-4623
|
10016551
|
TANK 80061 ELECTRICAL
|
10016552
|
TANK 80061 INSTRUMENTATION AND AUTOMATION
|
10016553
|
TANK 80061 PIPING
|
10016577
|
TANK 80037
|
10016578
|
TANK 80037 SAMPLE PUMP P-3657 MOTOR M-4646
|
10016579
|
MIXER ME-948 & MOTOR M-4647
|
10016580
|
TANK 80037 ELECTRICAL
|
10016581
|
TANK 80037 INSTRUMENTATION AND AUTOMATION
|
10016582
|
TANK 80037 PIPING
|
10016583
|
TANK 80212 DOUBLE BOTTOM REPLACEMENT
|
10016584
|
TANK 80212 ELECTRICAL
|
10016585
|
TANK 80212 INSTRUMENTATION AND AUTOMATION
|
10016586
|
TANK 80212 PIPING
|
10016632
|
RAILROAD TRACKS RR-1175
|
10016705
|
TANK 80082
|
10016706
|
Tank 80082 SAMPLE PUMP P-3639 & MOTOR M-4628
|
10016707
|
Tank 80082 Piping
|
10016708
|
Tank 80082 MIXER ME-942 & MOTOR M-4625
|
10016709
|
Tank 80082 MIXER ME-943 & MOTOR M-4630
|
10016710
|
Tank 80082 ELECTRICAL
|
10016711
|
Tank 80082 INSTRUMENTATION AND AUTOMATION
|
10016721
|
TANK 80042 RADAR GAUGES
|
10016723
|
TANK 80044 RADAR GAUGES
|
10016724
|
TANK 80045 RADAR GAUGES
|
Asset No.
|
Asset Description
|
10016725
|
TANK 80049 RADAR GAUGES
|
10016726
|
TANK 80050 RADAR GAUGES
|
10016727
|
TANK 80051 RADAR GAUGES
|
10016728
|
TANK 80055 RADAR GAUGES
|
10016729
|
TANK 80057 RADAR GAUGES
|
10016730
|
TANK 80209 RADAR GAUGES
|
10016731
|
TANK 80210 RADAR GAUGES
|
10016732
|
TANK 80211 RADAR GAUGES
|
10016733
|
TANK 80212 RADAR GAUGES
|
10016734
|
TANK 80213 RADAR GAUGES
|
10016735
|
TANK 80214 RADAR GAUGES
|
10016736
|
TANK 80215 RADAR GAUGES
|
10016737
|
TANK 80216 RADAR GAUGES
|
10016738
|
TANK 80217 RADAR GAUGES
|
10016739
|
TANK 80220 RADAR GAUGES
|
10016740
|
TANK 80221 RADAR GAUGES
|
10016741
|
TANK 96000 RADAR GAUGES
|
10016742
|
TANK 96059 RADAR GAUGES
|
10016743
|
TANK 125002 RADAR GAUGES
|
10016744
|
TANK 125003 RADAR GAUGES
|
10016745
|
TANK 125004 RADAR GAUGES
|
10016922
|
TANK 80057
|
10016923
|
TK 80057 SAMPLE PUMP P-3638 & M-4627
|
10016924
|
TK 80057 MIXER ME-941 & MOTOR M-4624
|
10016925
|
TANK 80057 ELECTRICAL
|
10016926
|
TANK 80057 INSTRUMENTATION AND AUTOMATION
|
10016927
|
TANK 80057 PIPING
|
10017129
|
RP&S UGH PIPING
|
10017164
|
TANK 80033 FOAM PIPING
|
10017668
|
FOAM PIPING TK 80075
|
10017669
|
FOAM PIPING TK 80071
|
10017670
|
TK ROOF 13505
|
10017672
|
TK ROOF 80066
|
10017673
|
FOAM PIPING TK 80090
|
10017674
|
FOAM PIPING TK 80090 ADDTL COST
|
10017675
|
FOAM PIPING TK 13505
|
10017676
|
FOAM PIPING TK 80066
|
10017718
|
FOAM PIPING TK 80076
|
10017915
|
RP&S FIREWATER PIPING - PH 2-3
|
10018771
|
RP&S WATER DRAW LINES NTF
|
10019386
|
TK 80219 SLUDGE IMPROVEMENTS-PIPING
|
10019394
|
LINE-51 PRESSURE RELIEF VALVE TAG# R-7129
|
Asset No.
|
Asset Description
|
10019395
|
LINE-51 PRESSURE RELIEF VALVE TAG# R-7130
|
10019396
|
LINE-51 PIPING
|
10019400
|
RP&S TK 80219 DOUBLE BOTTOM
|
10019510
|
LAR-W TANK FARM-SYSTEM 1 PIPING
|
10019511
|
LAR-W TANK FARM-SYSTEM 3 PIPING
|
10019512
|
LAR-W TANK FARM-SYSTEM 4 PIPING
|
10019513
|
LAR-W TANK FARM-SYSTEM 5 PIPING
|
10019514
|
LAR-W TANK FARM-SYSTEM 6 PIPING
|
10019515
|
LAR-W TANK FARM-SYSTEM 7 PIPING
|
10019991
|
INLINE BLENDING RVP ANALYZER ELEMENT 72-AE-0658A
|
10019992
|
INLINE BLENDING RVP ANALYZER ELEMENT 72-AE-0658B
|
10019993
|
INLINE BLENDING RVP ANALYZER TRANSMITTER 72-AT-065
|
10019994
|
INLINE BLENDING RVP ANALYZER SAMPLE CON 72-AU-0658
|
10020138
|
SLUDGE PIPING REROUTE FROM TK-7501 & TK-7201
|
10020144
|
3 10' CONNECT PIPELINE CARSON TERMINAL 2 LNS 28/32
|
10020323
|
8,200' PIPELINE EXT OF 71R/79R @ VAULT 252 TO LARW
|
10021447
|
E51 7130 RV RE-ROUTE TO SLOPS- 42 FT-6 INCH PIPE
|
10021659
|
TANK 776 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021660
|
TANK 777 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021661
|
TANK 778 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021662
|
TANK 779 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021663
|
TANK 780 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021664
|
TANK 1501 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021665
|
TANK 1502 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021666
|
TANK 1503 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021667
|
TANK 6000 TRANSMITTERS -TANK GAUGING-PHASE III
|
10021668
|
TANK 6001 TRANSMITTERS -TANK GAUGING-PHASE III
|
10022407
|
METHANOL INJECTION FOUNDATION
|
10022420
|
HCU TO TK 80035 6" LINE - 110 FT
|
10022423
|
FPT BTTMS TO ULSD- CNTRL VALVE TO TK 36002 -FV 208
|
10022424
|
FPT BTTMS TO ULSD - CNTRL VALVE TO TK 80070 - PV 2
|
10022425
|
FPT BOTTOMS TO ULSD - PIPING 40 FT
|
10022598
|
LARW - GASOLINE COMP. TK FRM PIPE - 100 FT, 10 INC
|
10022663
|
PROPANE LOADOUT REC - VPR LINE 560 FT - AVRG 3 INC
|
10022664
|
PROPANE LOADOUT REC - 3" CV TO FLARE (74-FV525)
|
10022665
|
PROPANE LOADOUT REC - 2" CV TO PRPN BULLET (74-FV5
|
10022666
|
PROPANE LOADOUT REC - MERCAPTAN CONV. BED (V-3634)
|
10022667
|
PROPANE LOADOUT REC. ELECT & INSTRUMENTATION
|
10022677
|
DISTILLATE TIE - T16 (LBT) PIPING - 50FT, 12 INCH
|
10022778
|
RP&S ADDT'L WATER DRAW LINES
|
10023010
|
RP&S ADDT'L WATER DRAW LINES (FINAL PHASE)
|
10023311
|
TANK 80092
|
Asset No.
|
Asset Description
|
10023653
|
OFFSITES - TANKAGE - TK-080071-origin# 100042927-1
|
10023654
|
Offsites - Tankage - TK-080075-origin# 100042931-1
|
10023655
|
OFFSITES - TANKAGE - TK-080079-origin# 100042935-1
|
10023656
|
80079 SAAB TANK RADAR PRO GAUG-origin# 100043910-1
|
10023728
|
PACIFIC PIPELINE - PLC-PNL-1
|
10023729
|
PACIFIC PIPELINE - RIO-PNL-1
|
10023730
|
PACIFIC PIPELINE - RIO-PNL-2
|
10023802
|
TANK 80036
|
10023856
|
TANK 125001
|
30000280
|
TANK 80039 REBUILD
|
30000391
|
TANK 80065 REBUILD
|
30000396
|
TANK 80081 REBUILD
|
30000404
|
TANK 80038 REBUILD
|
30000463
|
Piping
|
30001283
|
TANK 125001 REBUILD
|
30001292
|
TANK 80036 REBUILD
|
30003929
|
TANK 80060 REBUILD
|
95000478
|
TANK 80218 1ST & 2ND SHELL COURSE
|
99000507
|
TANK 80221 DOUBLE BOTTOM REPLACEMENT
|
99001074
|
TANK 125000 FOAM CHAMBERS AND PIPING
|
99001075
|
TANK 125000 REBUILD
|
99001076
|
TANK 125000 INSTRUMENTATION AND ELECTRICAL
|
99001077
|
TANK 125000 PIPING
|
99001078
|
TANK 125000 SAMPLE STATIONS
|
99001358
|
TANK 80035
|
99000595
|
TANK 80218 ROOF REPLACEMENT
|
99000596
|
TANK 80218 INSTRUMENTATION AND GAUGING
|
10013383
|
OFFSITES - TANKAGE - TK-080218 WATER
|
10013996
|
Offsites - Tankage - TK-007201
|
10016513
|
TRUCK RACK FLARE HEADER PIPING
|
10016514
|
TRUCK RACK FLARE HEADER FOUNDATION AND SUPPORT
|
10016515
|
TRUCK RACK RELIEF VALVE R-6875
|
10016516
|
TRUCK RACK RELIEF VALVER-6876
|
10016517
|
TRUCK RACK RELIEF VALVER-6877
|
10016518
|
TRUCK RACK RELIEF VALVER-6878
|
10016519
|
TRUCK RACK RELIEF VALVER-6879
|
10016520
|
TRUCK RACK RELIEF VALVER-6705
|
10016521
|
TRUCK RACK RELIEF VALVER-6706
|
10016522
|
TRUCK RACK FH FIREPROOFING
|
10016523
|
TRUCK RACK FH INSTRUMENTATION
|
10017119
|
LPG TRUCK LOADING PIPING & VALVES PH1
|
10017209
|
LAR TKRK FLOW LOOP 02F106
|
Asset No.
|
Asset Description
|
10017210
|
LAR TKRK FLOW LOOP 74F0522
|
10020598
|
PROPANE RACK INSTRUMENTATION UPGRADES
|
10021646
|
RP&S-BUTANE TRUCK RCK PIPING - 150', 8"
|
10021647
|
RP&S-BUTANE TRUCK RCK PIPING - 350', 6"
|
10021648
|
RP&S-BUTANE TRUCK RCK PIPING - 150' - 4"
|
10021649
|
RP&S-BUTANE TRUCK RCK PIPING - 240' - 2"
|
10022899
|
RP&S-PROPANE TRUCK RCK PIPING - 50', 1"
|
10022900
|
RP&S-PROPANE TRUCK RCK PIPING -100', 10"
|
10022901
|
RP&S-PROPANE TRUCK RCK PIPING - 100', 6"
|
10022902
|
RP&S-PROPANE TRUCK RCK PIPING - 100', 3"
|
10022903
|
RP&S-PROPANE TRUCK RCK PIPING -150', 4"
|
10022904
|
RP&S-PROPANE TRUCK RCK -FLARE PIPING - 200', 2"
|
10022905
|
RP&S-PROPANE EQUALIZING LINE- 200', 2"
|
10012677
|
RAILROAD UNDERPASS CATHODIC PROTECTION ANODE BEDS
|
10012663
|
P/L PIG LAUNCHER & RECEIVER - AT REFINERY
|
10013262
|
In Line Blend Analyzers & Instrumentation
|
10018911
|
CUSTODY TRANSFER METER TAG# 72FT-111
|
10018912
|
TRANSMIX METER TAG# 72 FE-112
|
10018913
|
TRANSMIX METER TAG# 72 FE-113
|
10018914
|
TRANSMIX CUSTODY METER ELECTRICAL
|
10018915
|
TRANSMIX VALVE TAG# 72 FV-112
|
10018916
|
TRANSMIX VALVE TAG# 72 FV-113
|
30000174
|
Tank Gauges PH III
|
30000177
|
RAIL CAR FALL PROTECTION
|
30000308
|
LARW NW Tank Farm 5B Firewater Piping
|
30000335
|
70 Series Butane Sphere Level Gauges
|
30001335
|
LARW NW Tank Farm 5A Firewater Piping
|
10018873
|
LOADING RACKS
|
10018829
|
TK 0014 MTBE SO TK FIELD 3N/8W
|
10018831
|
TK 0959 FCC FEED E. OF #9 C.T. 22N/1W
|
10018834
|
TK 0061 COLD SOUR GAS OIL
|
10018835
|
TK 0062 REFORMATE
|
10018836
|
TK 0063 REFORMATE
|
10018837
|
TK 0773 HYDRO GO FD ASPH. BLENDG. 9N/4E
|
10018840
|
TK 0064 ALKYLATE
|
10018841
|
TK 0031 MTBE UNF JP-4 SO TK FIELD 8N/4W
|
10018864
|
TANKS < 4,000 BBLs (COUNT: 63)
|
10019290
|
INTERMEDIATE STOVE OIL FLEX
|
10020609
|
TK-73 PRESSURE TRANSMITTER
|
10020610
|
TK-76 PRESSURE TRANSMITTER
|
10023767
|
TANK 62 ACTUATOR - 75-HV-718
|
10023768
|
TANK 63 ACTUATOR -75-HV-719
|
Asset No.
|
Asset Description
|
10018838
|
TK 0016 ANS CRUDE N. SLOPE S. TK FIELD 3N/10W
|
10018839
|
TK 0017 ANS CRUDE N. SLOPE S. TK FIELD 3N/11W
|
10018846
|
1 CRUDE TK 0190 SLOP OIL UN TOLUENE 3N/2E
|
30001382
|
Other Machinery & Equipment
|
95000479
|
TANK 61 FLOOR
|
10019475
|
SPHERE 78 FIRE DELUGE SYSTEM
|
10021279
|
TK-FARM PROGRAMMABLE LOGIC CONTROLLER 75-PLC-9333
|
10021534
|
TK 16 - CRUDE FILL LINE (12"-206')
|
10021535
|
TK 16 - ALT FILL LINE (8"-152')
|
10021536
|
TK 16 - SUCTION LINE (12"-161')
|
10021537
|
TK 17 - CRUDE FILL LINE (12"-168')
|
10021538
|
TK 17 - ALT FILL LINE (8"-173')
|
10021539
|
TK 17 - SUCTION LINE (12"-185')
|
10022613
|
#1 TRTR TO PUMP SLAB PIPING - 200 FT - AVG 6 INCH
|
10047918
|
JET FUEL PIPING LINE 103
|
10023060
|
LARW FIREWATER SYSTEM NW TANK - 5A
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
LAR - Carson
|
14
|
358,162
|
LAR - Carson
|
16
|
96,247
|
LAR - Carson
|
17
|
95,649
|
LAR - Carson
|
31
|
82,396
|
LAR - Carson
|
61
|
100,965
|
LAR - Carson
|
62
|
100,312
|
LAR - Carson
|
63
|
100,600
|
LAR - Carson
|
64
|
100,220
|
LAR - Carson
|
73
|
30,570
|
LAR - Carson
|
74
|
15,021
|
LAR - Carson
|
75
|
14,972
|
LAR - Carson
|
76
|
30,570
|
LAR - Carson
|
78
|
10,239
|
LAR - Carson
|
959
|
163,366
|
LAR - Carson
|
350
|
1,770
|
LAR - Carson
|
351
|
1,770
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
LAR - Carson
|
352
|
1,770
|
LAR - Carson
|
353
|
1,770
|
LAR - Carson
|
354
|
1,770
|
LAR - Carson
|
355
|
1,770
|
LAR - Carson
|
398
|
6,910
|
LAR - Carson
|
399
|
6,910
|
LAR - Carson
|
677
|
16,671 (OOS)
|
LAR - Carson
|
678
|
16,690 (OOS)
|
LAR - Carson
|
679
|
16,307 (OOS)
|
LAR - Carson
|
680
|
16,279 (OOS)
|
LAR - Carson
|
681
|
30,000
|
LAR - Carson
|
682
|
30,000
|
LAR - Carson
|
683
|
30,000
|
LAR - Carson
|
684
|
30,000
|
LAR - Carson
|
773
|
97,844
|
LAR - Wilmington
|
476
|
400
|
LAR - Wilmington
|
776
|
700
|
LAR - Wilmington
|
777
|
700
|
LAR - Wilmington
|
778
|
700
|
LAR - Wilmington
|
779
|
700
|
LAR - Wilmington
|
780
|
700
|
LAR - Wilmington
|
1501
|
985
|
LAR - Wilmington
|
1502
|
985
|
LAR - Wilmington
|
1503
|
985
|
LAR - Wilmington
|
6000
|
6,000
|
LAR - Wilmington
|
6001
|
6,000
|
LAR - Wilmington
|
7201
|
7,156
|
LAR - Wilmington
|
7501
|
8,395
|
LAR - Wilmington
|
11000
|
11,567
|
LAR - Wilmington
|
11001
|
11,567 (OOS)
|
LAR - Wilmington
|
11002
|
11,567 (OOS)
|
LAR - Wilmington
|
11003
|
11,567 (OOS)
|
LAR - Wilmington
|
11004
|
11,567 (OOS)
|
LAR - Wilmington
|
13500
|
13,818 (OOS)
|
LAR - Wilmington
|
13501
|
13,818 (OOS)
|
LAR - Wilmington
|
13502
|
13,818
|
LAR - Wilmington
|
13503
|
13,818
|
LAR - Wilmington
|
13504
|
13,818
|
LAR - Wilmington
|
13505
|
13,818
|
LAR - Wilmington
|
13506
|
13,818
|
LAR - Wilmington
|
13507
|
13,818 (OOS)
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
LAR - Wilmington
|
13508
|
13,818
|
LAR - Wilmington
|
13509
|
13,818 (OOS)
|
LAR - Wilmington
|
13510
|
13,818
|
LAR - Wilmington
|
13511
|
13,818
|
LAR - Wilmington
|
13512
|
13,818 (OOS)
|
LAR - Wilmington
|
20426
|
20,144
|
LAR - Wilmington
|
36001
|
36,612
|
LAR - Wilmington
|
36002
|
36,612
|
LAR - Wilmington
|
50000
|
50,000
|
LAR - Wilmington
|
76000
|
76,158
|
LAR - Wilmington
|
80033
|
81,383
|
LAR - Wilmington
|
80034
|
81,383
|
LAR - Wilmington
|
80035
|
81,383
|
LAR - Wilmington
|
80036
|
81,383
|
LAR - Wilmington
|
80037
|
81,383
|
LAR - Wilmington
|
80038
|
81,383
|
LAR - Wilmington
|
80039
|
81,383
|
LAR - Wilmington
|
80042
|
81,383
|
LAR - Wilmington
|
80044
|
81,383
|
LAR - Wilmington
|
80045
|
81,383
|
LAR - Wilmington
|
80049
|
81,383
|
LAR - Wilmington
|
80050
|
81,383
|
LAR - Wilmington
|
80051
|
81,383
|
LAR - Wilmington
|
80055
|
81,383
|
LAR - Wilmington
|
80057
|
82,340
|
LAR - Wilmington
|
80058
|
81,383
|
LAR - Wilmington
|
80061
|
81,383
|
LAR - Wilmington
|
80062
|
81,383
|
LAR - Wilmington
|
80063
|
81,383
|
LAR - Wilmington
|
80064
|
81,383
|
LAR - Wilmington
|
80065
|
81,383
|
LAR - Wilmington
|
80066
|
81,383
|
LAR - Wilmington
|
80067
|
81,383
|
LAR - Wilmington
|
80068
|
81,383
|
LAR - Wilmington
|
80069
|
81,383
|
LAR - Wilmington
|
80070
|
81,383
|
LAR - Wilmington
|
80071
|
81,383
|
LAR - Wilmington
|
80072
|
81,383
|
LAR - Wilmington
|
80075
|
78,511
|
LAR - Wilmington
|
80076
|
81,383
|
LAR - Wilmington
|
80077
|
81,383
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
LAR - Wilmington
|
80078
|
81,383
|
LAR - Wilmington
|
80079
|
81,383
|
LAR - Wilmington
|
80080
|
81,383
|
LAR - Wilmington
|
80081
|
81,383
|
LAR - Wilmington
|
80082
|
81,383
|
LAR - Wilmington
|
80083
|
81,383
|
LAR - Wilmington
|
80084
|
81,383
|
LAR - Wilmington
|
80085
|
81,383
|
LAR - Wilmington
|
80087
|
81,383
|
LAR - Wilmington
|
80089
|
81,383
|
LAR - Wilmington
|
80090
|
81,383
|
LAR - Wilmington
|
80091
|
81,383
|
LAR - Wilmington
|
80092
|
81,383
|
LAR - Wilmington
|
80209
|
85,610
|
LAR - Wilmington
|
80210
|
85,610
|
LAR - Wilmington
|
80211
|
85,610
|
LAR - Wilmington
|
80212
|
85,610
|
LAR - Wilmington
|
80213
|
85,610
|
LAR - Wilmington
|
80214
|
85,610
|
LAR - Wilmington
|
80215
|
85,610
|
LAR - Wilmington
|
80216
|
85,610
|
LAR - Wilmington
|
80217
|
85,610
|
LAR - Wilmington
|
80218
|
80,000
|
LAR - Wilmington
|
80219
|
85,610
|
LAR - Wilmington
|
80220
|
85,610
|
LAR - Wilmington
|
80221
|
81,239
|
LAR - Wilmington
|
96000
|
96,689
|
LAR - Wilmington
|
96059
|
96,689
|
LAR - Wilmington
|
118066
|
117,477
|
LAR - Wilmington
|
125000
|
123,278
|
LAR - Wilmington
|
125001
|
123,278
|
LAR - Wilmington
|
125002
|
125,897
|
LAR - Wilmington
|
125003
|
125,897
|
LAR - Wilmington
|
125004
|
125,897
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY
(in barrels)
|
Wingate Terminal
|
V-500 - V-505
|
8,004
|
Wingate Terminal
|
V-506 - V-510
|
8,521
|
Wingate Terminal
|
V-516 - V-518
|
5,450
|
Wingate Terminal
|
V-511 - V515
|
12,413
|
Wingate Terminal
|
V-200 - V-207
|
9,941
|
Wingate Terminal
|
V-208
|
1,243
|
Wingate Terminal
|
V-400 - V-407
|
10,652
|
Wingate Terminal
|
V-209 - V-214
|
10,291
|
Wingate Terminal
|
V-215
|
7,676
|
Wingate Terminal
|
V-216
|
10,313
|
Wingate Terminal
|
V-100 - V-101
|
12,390
|
Wingate Terminal
|
V-102 - V-103
|
20,791
|
Wingate Terminal
|
V-104
|
10,313
|
Wingate Terminal
|
V-519
|
95
|
Asset Description
|
High voltage equipment, transformers and feeders up to the disconnect at the switch rack dedicated to assets owned by the Logistics Parties
|
ResCar train car repair facility
|
Asset Description
|
High voltage equipment, transformers and feeders up to the disconnect at the switch rack dedicated to assets owned by the Logistics Parties
|
Main fire water piping running along the perimeter of the tank farm and outside of the tank farm boundary
|
Any storm or wastewater piping inside the boundary of the tank farm
|
Asset Description
|
High voltage equipment and feeders remains the responsibility of the refinery up to the disconnect at the switch rack dedicated to assets owned by the Logistics Parties
|
Main 210lb steam line to/from the LARW Refinery Unit and the sulfur recovery plant (“SRP”)
|
Stripped pipelines to/from LARW Refinery Unit and the SRP
|
Fuel gas pipeline to/from LARW Refinery Unit and the SRP
|
Spare pipeline to/from LARW Refinery Unit and the SRP
|
Cross plant DEA
|
Cross plant flare
|
Cross plant LPG/H2/fuel gas system
|
Cross plant sour water systems
|
Cross plant vapor recovery systems unless equipment if fitted on tanks
|
Cross plant slop systems
|
Blended effluent pipeline from LCOD/HCOD to tank 80043
|
Wastewater separators and ponds
|
SRP blow down line from the SRP to ditch at tank-80216
|
Communication trunks and utility piping to/from the SRP and the refinery
|
Asset Description
|
Fractionation plant with associated vessels and piping
|
Asset Description
|
Tank T-60002 (owned by Granite Construction)
|
1.
|
In July 2016, the US EPA and the U.S. Department of Justice announced a $425 million settlement with TRMC, including the TRMC Anacortes Refinery, in relation to violations of the Clean Air Act. The settlement (the Consent Decree) with the U.S. Department of Justice requires that the storage tanks be added to the Refinery’s LDAR program and be monitored regularly for leaks. Some valve locations are difficult to monitor and may require relocation nearer to grade. These locations have been identified and will be addressed when
|
2.
|
The recent Consent Decree with the U.S. Department of Justice has required that the Refinery perform a BWON (Benzene Waste Operations National Emission Standards for Hazardous Air Pollutants) Audit to recalculate the Total Annual Benzene amount and the total benzene emitted under the 2 Mg per year exemption. During this process, the Refinery determined that it exceeded the 2 Mg exemption and reported the exceedance to NWCAA in the 2016 Annual Compliance Certification air operating permit.
|
1.
|
With respect to the Mandan Rail Rack and Trackage and the Salt Lake Rail Rack and Trackage (each as defined in the 2018 Assets Contribution Agreement), an August 2013 Fuels Consent Decree contains provisions that apply to tanks storing Conventional Gasoline. Capital Improvements and Audits have been performed under the Consent Decree, but the tanks are still subject to a mandated System-Wide Compliance Plan for sampling tank contents.
|
2.
|
With respect to the LARW Refinery Unit, the LARC Refinery Unit, and the LA Refinery Interconnecting Pipeline (each as defined in the 2018 Assets Contribution Agreement), litigation by environmental advocacy group(s),
CBE v. SCAQMD,
challenging the LARIC Environmental Impact Review for combining the LARW Refinery Unit and the LARC Refinery Unit. Contests anything within scope of that EIR, including LA Refinery Interconnecting Pipeline connections.
|
3.
|
For LARC Refinery Unit operations and assets only, the 2001 EPA Consent Decree entitled
U.S. and the State of Indiana, State of Ohio, and the Northwest Air Pollution Authority, Washington v. BP Exploration & Oil Co
.
|
4.
|
LARC Tankage (as defined in the 2018 Assets Contribution Agreement) was issued Cleanup and Abatement Order (CAO) No. 90-121, dated 22 August 1990.
|
5.
|
Certain of the Assets (as defined in the 2018 Assets Contribution Agreement) are subject to a 2016 Environmental Consent Decree with the United States Environmental Protection Agency and the Department of Justice.
|
•
|
The pump station for the Tesoro Alaska Pipeline is adjacent to the Kenai Refinery Lower Tank Farm. Multiple historic tank and buried pipeline releases have impacted soil and groundwater in the area; however there are no documented releases from the pipeline pump station. The soil and groundwater surrounding the pump station is considered characterized and undergoing groundwater monitoring and treatment.
|
•
|
A pipeline release in 2001 resulted in soil, groundwater and surface water impacts in an undeveloped area of the Kenai Peninsula. The quantity of the release is not known. Soil surrounding the release was excavated and stockpiled at the Kenai Refinery while groundwater and surface water were remediated on-site. The Alaska Department of Environmental Conservation issued a No Further Action letter for this cleanup effort in 2008. There are no other known release sites on the pipeline between the Kenai Refinery and Anchorage.
|
•
|
Historic spills and releases have impacted the Anchorage #1 terminal, including past releases from the Tesoro Alaska Pipeline receiving station. Groundwater remediation monitoring is ongoing across the Anchorage #1 terminal. In addition, a soil vapor venting system is being installed to address a flame suppressant compound detected in soils near the receiving station control room.
|
1.
|
Deviations reported under Anchorage Air Permit No. AQ0235TVP03, Issue Date: April 2, 2014, Effective Date: May 2, 2014
|
•
|
Flint Hills Resources Alaska, LLC did not submit a report as required under Condition 68 based upon defects listed in Condition 6.3 discovered during the out of service inspection conducted on T-4216 during July 2014. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015.
|
•
|
Flint Hills Resources Alaska, LLC did not report all emissions or operations that exceed or deviate from the requirements of its permit within 30 days of the end of the month in which the excess emission or deviation occurred. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015.
|
•
|
Flint Hills Resources Alaska, LLC did not perform preventative maintenance in accordance with 40 CFR Subpart ZZZZ within 365 days of effective date on EU IDs 7, 8, and 9. The maintenance was performed 2 days after that date. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated July 30, 2014.
|
•
|
Flint Hills Resources Alaska, LLC did not report all emissions or operations that exceed or deviate from the requirements of this permit within 30 days of the end of the month in which the excess emissions or deviation occurred. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015.
|
•
|
On April 10, 2014. ADEC issued Flint Hills Resources Alaska, LLC a letter of Acceptance of the Anchorage Facility Compliance Certificate, and identified 4 deviations from the air permit.
|
2.
|
In a letter dated July 22, 2015, the ADEC indicated that the Anchorage Terminal Oil Discharge Prevention and Contingency Plan needed the additional information specified in the July 22, 2015 letter to be submitted in order for the plan renewal to be approved. On September 2, 2015, the facility submitted the requested information and is awaiting ADEC approval.
|
3.
|
On May 15, 2015 Flint Hills Resources Alaska, LLC received a notice of failure to pay Air Quality fees relating to Air Permit No. AQ0235TVP03. Those fees were paid on June 2, 2015.
|
4.
|
In a letter dated October 1, 2015, ADEC approved the facility’s request for a waiver of secondary containment, subject to the terms of the letter, until March 31, 2016.
|
5.
|
On July 24, 2014 ADEC issued a letter to Flint Hills Resources Alaska, LLC advising that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the July 22, 2014 Anchorage Facility Jet Fuel release.
|
6.
|
On April 21, 2014, ADEC issued a letter to Flint Hills Resources Alaska, LLC advising it that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the April 20, 2014 gasoline release.
|
(i)
|
In a letter dated May 29, 2015, ADEC detailed items that needed correction related to ADEC’s May 19, 2015 inspection of the terminal and its Oil Discharge Prevention and Contingency Plan. The facility has submitted a response to ADEC and is working with the agency to correct the identified items.
|
(ii)
|
On April 24, 2014 ADEC advised Flint Hills Resources Alaska, LLC that the Primary Response Action Contractor is no longer an ADEC approved and registered contractor. Therefore, Flint Hills Resources Alaska, LLC’s Fairbanks Facility Oil Discharge Prevention and Contingency Plan was out of compliance and needed amendment.
|
(iii)
|
Two underground storage tanks are located at the Fairbank Terminal, both of which are used to store heating oil. One underground storage tank was removed from the Purchased Site prior to Flint Hills Resources Alaska, LLC’s leasehold.
|
(iv)
|
Asbestos materials has been identified and are known to be located at the Anchorage Facility in the following locations:
|
Material Type
|
Location(s)
|
EPA Category
|
Gray Caulk
(10% Chrysotile)
|
Fire Pump Room, Warehouse
|
Category II
|
Sheetrock
(4% Chrysotile)
|
Boiler Room, Warehouse
|
Category II
|
Brown Insulation
(5% Chrysotile)
|
Heat Exchanger Building
|
Category I
|
Window Caulk
(3% Chrysotile)
|
Warehouse
|
Category II
|
Gray Mastic
(10% Chrysotile)
|
Concrete Pad Near Tank 4136
|
Category II
|
Black Mastic
(6% Chrysotile)
|
Concrete Pad Near Tank 4136
|
Category II
|
Black Mastic
(17% Chrysotile)
|
Exchanger on West Side of Asphalt Tank Farm
|
Category II
|
Black Mastic
(6% Chrysotile)
|
Piping located near railroad tracks on Ocean Dock Road.
|
Category II
|
Black Mastic
(20% Chrysotile)
|
Piping on side of Tank 4263, East Tank Farm
|
Category II
|
White Insulation
(60% Chrysotile)
|
Piping on side of Tank 4263, East Tank Farm
|
Category I
|
Mastic/Insulation
(20% Chrysotile)
|
Top skirt of Tank 4263, East Tank Farm
|
Category I
|
Mastic
(15% Chrysotile)
|
Sections of buried pipelines
|
Category II
|
1.
|
On July 24, 2014 ADEC issued a letter to Flint Hills Resources Alaska, LLC advising that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the July 22, 2014 Anchorage Facility Jet Fuel release.
|
2.
|
On April 21, 2014, ADEC issued a letter to Flint Hills Resources Alaska, LLC advising it that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the April 20, 2014 gasoline release.
|
3.
|
In a letter dated July 22, 2015, ADEC indicated that the Anchorage Terminal Oil Discharge Prevention and Contingency Plan needed the additional information specified in the July 22 letter to be submitted in order for the plan renewal to be approved. On September 2, 2015, the facility submitted the requested information and is awaiting ADEC approval.
|
1.
|
Notice issued April 16, 2013 by the Bay Area Air Quality Management District (“
BAAQMD
”) related to liquid discovered on internal floating roof of Tank 870;
|
2.
|
Notice issued February 11, 2014 by BAAQMD related to a leaking PV valve on Tract 3 VRS Tank 613; and
|
3.
|
Notice issued August 12, 2014 by BAAQMD related to a ½ inch gap at well sliding cover on Tank 692.
|
1.
|
The transfer piping on the wharf has not been reviewed for risk of surge. In the event of misalignment during cargo operations or accidental valve closure on vessel or shore there is a potential to overpressure the transfer piping. A surge study will be conducted and any required modifications will be undertaken.
|
2.
|
There is a seep of oil through the north secondary containment dike for Tanks 6 and 7 and into the adjacent storm water swale. Absorbent booms are placed at intervals in the swale to contain the oil. Any oil that makes its way to the wastewater treatment facility can be
|
3.
|
The tank containment dikes are coated with asphalt and roofing tar and the asphalt coating is deteriorating on many of the dikes, vegetation is encroaching, and some minor sloughing was noted. If not maintained, further erosion may occur to containment dikes and there are potential compliance risk related to 40 CFR 121, SPCC, and WAC 173-180-320. A tank containment dike erosion control program is in place but needs to be accelerated to mitigate erosion issues over next three years.
|
4.
|
Certain floating roof deck fittings do not meet the requirements of Refinery MACT Subpart CC for storage tanks. According to TRMC representatives, seals/gaskets need to be replaced on 27 tanks in the Assets covered by the 2017 Anacortes Contribution Agreement.
|
5.
|
Per the Consent Decree mentioned in Schedule 1, the Refinery must install closed-purge, closed-loop, or closed-vent samplers at all storage tanks by 2021. According to facility representatives, there are 42 tanks left to retrofit in the Assets covered by the 2017 Anacortes Contribution Agreement.
|
6.
|
Several out-of-service assets are included in the drop, including 17 tanks, the asphalt loading rack, pipelines, the red dye shed, and lead shed areas. TRMC has indicated a total of 17 out-of-service tanks (Tanks 34, 46, 47, 48, 55, 62, 88, 89, 90, 95, 98, 99, 110, 147, 159, 232, and 249).
|
7.
|
Propane and butane vessels were observed to potentially not have drain-away protection that is sized and configured for one-half the largest vessel. A release should be able to drain away from the vessels to prevent further releases, explosions, and fires.
|
1.
|
On August 22, 1990, the Los Angeles Regional Water Quality Control Board (RWQCB) issued Cleanup and Abatement Order (CAO) No. 90-121 to Tesoro Refining & Marketing Company LLC (TRMC) for the LARC Refinery Unit. The CAO requires investigation and remediation of light non-aqueous phase liquid (LNAPL) on the water table and groundwater containing dissolved-phase petroleum hydrocarbons and methyl tert-butyl ether (MTBE). TRMC operates a LNAPL and groundwater recovery system predominantly along the western boundary of LARC Refinery Unit. LNAPL also is removed from selected wells within the process and tank farm areas via vacuum truck. Other remediation efforts at the LARC Refinery Unit include vapor-phase hydrocarbon extraction from soils and enhancing natural biologic degradation in groundwater. Groundwater and soil remediation and LNAPL removal will be ongoing.
|
2.
|
Subsurface environmental investigation at the LARW Refinery Unit began in the early 1980s. These investigations revealed soil and groundwater impacts from dissolved petroleum hydrocarbons, MTBE, tert-butyl alcohol (TBA) and LNAPL. Shell Oil Products US (SOPUS) is responsible for soil and groundwater remediation originating prior to May 2007. SOPUS has recovered LNAPL using a total fluids extraction system and tracked LNAPL recovery rates since 2010. A Remediation Feasibility Study was submitted by SOPUS to the RWQCB in August of 2017. SOPUS presented four "remedy packages" to meet remedy objectives; however, additional data are needed prior to designing a total fluids extraction or dual pump liquid extraction. Releases from TRMC operations have not commingled with impacts attributable to SOPUS.
|
3.
|
Groundwater impacts at the LARC Refinery Unit and the LARW Refinery Unit have migrated downward and offsite. SOPUS, TRMC and Kinder Morgan have modeled groundwater flow and continue to document natural biodegradation in the lower aquifers.
|
4.
|
On January 4, 2010, TRMC notified the California Emergency Management Agency of a naphtha release from LARW Refinery Unit Tank 80214. The release was initially estimated at 15,200 barrels. The RWQCB issued CAO R4-2011-0037 to TRMC on April 11, 2011. The CAO required the assessment and delineation of soil and groundwater impacts associated with this release. In response, TRMC investigated the Tank 80214 area and constructed a LNAPL and groundwater extraction system, which is under continuous operation. Remedial efforts are on-going, however active pumping is expected to be complete within 10 years.
|
5.
|
Underground piping is to be removed/decommissioned under Cleanup Abatement Order (CAO), Los Angeles Plant (File No. 85-20) issued by the California Water Quality Board, Los Angeles Region Order 88-70 was adopted June 27, 1988. Between 2003 and 2017, approximately 89,895 feet of aboveground pipeline was installed and approximately 69,182
|
1.
|
On October 16, 2018 the North Dakota Department of Health (NDOH) issued a RCRA Hazardous Waste Storage and Treatment and Corrective Action Permit (HW-002) for operations at the Mandan Refinery. The Permit requires the investigation and mitigation of hazardous wastes and hazardous waste constituents released from facility waste management units, including the wastewater collection system below areas of refinery operations and petroleum storage. Mitigation measures include collecting groundwater from down-gradient recovery trenches and monitoring groundwater twice per year. Continued groundwater monitoring, operation of the groundwater trench collection system, and annual reporting to the NDOH is expected to be on-going.
|
1.
|
TRMC operates a remediation system to contain and recover LNAPL and groundwater at the Salt Lake Refinery. This recovery and monitoring system is operated under a Stipulated Consent Order (SCO), dated January 9, 1992, between the Utah Solid and Hazardous Waste Control Board and Amoco Oil Company, the former refinery owner. Under the SCO, Amoco completed a RCRA Facility Investigation and developed a Corrective Action Plan (CAP) that included a groundwater remediation/containment system, tracking of soil impacts and establishing deed restrictions to limits property and groundwater use. The LNAPL extraction system operates primarily along the western boundary of the refinery, including the west side of the storage tank area. Dissolved petroleum hydrocarbons are no longer detected in site groundwater. As a result, TRMC is currently in discussions with the State of Utah Department of Environmental Quality, Division of Waste Management and Remediation Control, to update the SCO and CAP into a Site Management Plan and Environmental Covenant. It is unknown whether the State will agree with TRMC’s proposed and revised technical approach.
|
2.
|
Asphalt seeps within the bermed area at Tank 204 can impact operations within the containment area. The Salt Lake Refinery is currently removing residual pockets of asphalt through routine maintenance. The asphalt has not migrated through the containment area. Asphalt seeps are not expected to infiltrate through soils to the water table. Groundwater from monitoring wells located near Tank 204 do not contain dissolved petroleum hydrocarbons or LNAPL.
|
3.
|
LNAPL and water have been observed within the secondary containment at Tank 247. The wastewater treatment facility capacity at the Salt Lake Refinery can be overwhelmed following heavy precipitation events. The backup of hydrocarbon containing wastewater
|
4.
|
Laboratory instruments containing free-phase mercury were once used within the Bulk Loading Rack (BLR) Control Building. Impacts from this practice were discovered on December 1, 2014. The free phase mercury in soil was remediated in the immediate area of the BLR, and interior floors were cleaned and sealed. Mercury remains in the shallow soil surrounding the north side of the BLR Control Building; however institutional controls – including an asphalt cap - are in place to prevent earthwork or disturbing the area without approval and permitting. Post-remediation indoor air sampling demonstrated that the BLR Control Building is suitable for worker occupancy.
|
1.
|
The facility records at the JAL NGL Storage Facility include the following information regarding releases, impacts or potential impacts:
|
a)
|
A former compressor unit leaked an unknown quantity of oil containing poly-chlorinated biphenyls (PCBs).
|
b)
|
The southwest corner of the property is used for construction debris, out of service equipment, transformers and storage of other discarded materials. Contaminated soil also is placed in this area.
|
c)
|
Groundwater is impacted by former operation of brine ponds. Kinder Morgan is responsible for these groundwater impacts.
|
d)
|
Wastes, including water, solids, and lubricating oils, were previously disposed in an on-site injection well.
|
1.
|
In 2015, the New Mexico Oil Conservation Division issued Abatement Plan AP-121 to Western Refining. Site groundwater impacts will be addressed after the facility is closed or if contamination migrates off-site. Until closure of the facility’s active operations, the AP-121 requires monitoring eight wells and submitting a report each year. Groundwater monitoring and annual reporting is expected to be on-going.
|
2.
|
Asbestos is present at the Wingate Terminal, including buildings that are cladded in transite and pipes insulated with asbestos wrap. Currently, asbestos is kept sealed and managed in place.
|
3.
|
Two burn pits were used before the existing flare system was constructed. Flare pits may be a source of surface and subsurface soil impacts.
|
1.
|
A sump was reportedly overfilled on March 8, 2018 due to a power outage. This caused a release of 24.4 bbl of crude oil, which flowed across the terminal property and to adjacent undeveloped ranch land. Remedial actions are in process.
|
1.
|
Great Northern Gathering & Marketing LLC vs. Mountain Peak Builders, LLC
, Case No. 27-2015-CV-00222, District Court, McKenzie County, North Dakota;
Mountain Peak Builders, LLC vs. Great Northern Gathering & Marketing LLC
, Case No. 4:15-cv-034, the United States District Court of North Dakota;
Cross-Country Pipeline Supply Co., Inc. v. Great Northern Gathering & Marketing LLC and Great Northern Midstream LLC
, Civil Case No. 27-2017-CV-00305, in the District Court, McKenzie County, North Dakota. Three related suits regarding construction liens on certain Tesoro Great Plains Midstream
LLC
assets in North Dakota relating to work
for the
prior owner (all fully indemnified and being defended by third party/seller - secured by escrow).
|
2.
|
Efrain Onsurez v Rangeland Energy
- Litigation in which plaintiff claims that Rio Pipeline (fka Rangeland) drivers are trespassing on his land and related grievances. Affects Rio Pipeline assets in Texas and New Mexico.
|
3.
|
Other litigation scheduled on Schedule I (Environmental Litigation).
|
4.
|
The following HR lawsuits and pending administrative claims:
|
(1)
|
Executive management services of Andeavor employees who devote less than 50% of their business time to the business and affairs of the Partnership, including stock based compensation expense
|
(2)
|
Financial and administrative services (including, but not limited to, treasury and accounting)
|
(3)
|
Information technology services
|
(4)
|
Legal services
|
(5)
|
Health, safety and environmental services
|
(6)
|
Human resources services
|
Asset
|
|
Owner
|
|
|
|
Nikiski Dock and Storage Facility (Nikiski, Alaska)
A single-berth dock and storage facility located at the Kenai Refinery that includes five crude oil storage tanks with a combined capacity of approximately 930,000 barrels, ballast water treatment capability and associated pipelines, pumps and metering stations. The dock and storage facility receives crude oil from marine tankers and from local production fields via pipeline and truck, and also delivers refined products from the refinery to marine vessels.
|
|
Tesoro Alaska
|
|
|
|
|
|
|
|
|
|
|
|
|
a)
|
TRMC and the Operating Company shall mutually agree on the inspection schedule and the duration of such inspections so as to minimize disruption within the Wilmington and Carson refinery systems, with TRMC having the right to approve the final inspection schedule.
|
b)
|
If TRMC fails to renew the Carson II Storage Services Agreement, prior to November 12, 2022, in accordance with the terms thereof, the Partnership Group may elect to accelerate API 653 or API 510 inspections prior to the expiration of the Carson II Storage Agreement.
|
Tank Number
|
Year of Last Inspection
|
53
|
2013
|
87
|
2013
|
41
|
2013
|
4
|
2013
|
88
|
2013
|
5
|
2013
|
24
|
2013
|
325
|
2013
|
326
|
2013
|
45
|
2014
|
65
|
2014
|
89
|
2014
|
276
|
2014
|
289
|
2014
|
303
|
2014
|
340
|
2014
|
50
|
2014
|
302
|
2014
|
138
|
2014
|
139
|
2014
|
289
|
2015
|
65
|
2015
|
969
|
2015
|
40
|
2015
|
955
|
2015
|
194
|
2015
|
1.
|
Upon mutual consent on project scope between TAC and the Partnership, TAC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following instrumentation and control projects: AFE# 2012217023 (TCM Idea# 137100002), TCM Idea# 2014216018, TCM Idea# 2007002425. For any such projects listed above in this section 1 that are required to maintain safe operation of the Assets, the Partnership shall determine the final project scope in its sole discretion.
|
2.
|
All capital costs related to the assessment and upgrade or replacement of tank level measurement and transmitter instruments, upon mutual consent of TAC and the Partnership of the scope for the multi-year project. Notwithstanding the foregoing, the Partnership in its sole discretion shall determine the final scope of any element of the tank level instrument upgrade project required to maintain safe operation of the Assets.
|
3.
|
All capital costs related to installation of tank liners during first API 653 inspection cycle to bring each tank into conformance with Alaska Department of Environmental Conversation standards.
|
4.
|
All capital costs related to the assessment and necessary upgrades of cathodic protection system including:
|
•
|
Additional anode ground beds
|
•
|
Additional surface distributed anodes
|
•
|
Additional amperes of cathodic protection for on-grade storage tanks
|
•
|
Under tank monitoring systems
|
5.
|
All capital costs related to internal inspection, assessment and repair of Tank 11 internal floating roof.
|
1.
|
The parties agree that Tank 37 included in the Alaska Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 24 months prior to the date hereof, and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of TAC.
|
2.
|
Any costs or expenses related to:
|
•
|
Completion of pressure relief documentation, expected to be complete by year-end 2016.
|
•
|
Completion of area classification plans per NEC 500.4, expected to be complete by year-end 2017.
|
1.
|
All capital costs related to:
|
a)
|
Anchorage Terminal
|
•
|
Installation of permanent fire water pipeline supports with proper coating; expected to be complete by year-end 2017.
|
•
|
Assessment, evaluation and potential replacement of two deep anode ground beds (No. 2 and No. 5); expected to be completed within cathodic protection program by year-end 2018.
|
•
|
Installation of third tank floor on Tank 4236 with either new cathodic protection system or an El Segundo system; expected to be complete by year-end 2020.
|
•
|
Assessment and upgrades to add access platforms and roof protection to east side filter vessels; expected to be complete by year-end 2017.
|
b)
|
Fairbanks Terminal
|
•
|
Assessment, evaluation and potential replacement of two deep anode ground beds and installation of two new rectifiers to allow ground beds to be operated independently; expected to be completed within cathodic protection program by year-end 2018.
|
1.
|
Any costs or expenses related to:
|
a.
|
Anchorage Terminal
|
•
|
Inspection and assessment of buried product pipeline; expected to be complete by year-end 2017.
|
•
|
Assessment of manual operation of rail car sump tankage; expected to be complete by year-end 2017.
|
b.
|
Fairbanks Terminal – Any costs or expenses related to:
|
•
|
Arc flash assessment; expected to be complete by year-end 2017.
|
Tank Number
|
26
|
258
|
517
|
601
|
612
|
641
|
690
|
701
|
702
|
709
|
710
|
711
|
1.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following gasoline blending unit projects identified: TCM Idea# 2017211656, TCM Idea# 2016215025, TCM Idea# 2014215018, and TCM Idea# 2012215056. For any such projects listed above in this section 1 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion.
|
2.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following tank repairs, improvements and new build projects: TCM Idea# 2015215024, TCM Idea# 2015215023, TCM Idea# 2015215020, TCM Idea# 2015215022, TCM Idea# 2015215006, TCM Idea# 2016215005, TCM Idea# 2015215008, AFE# DTKRS.0600.2017.03 (TCM Idea# 2015215017), AFE# DTKRS.0600.2017.02 (TCM Idea# 2015215018), AFE# DTKRS.0600.2017.01 (TCM Idea# 2015215010), TCM Idea# 2015215019, TCM Idea# 2015215015, TCM Idea# 2015215012, TCM Idea# 2015215026, TCM Idea# 2009005038, AFE# DTKRS.0600.2016.03 (TCM Idea# 2011215042), AFE# DTKRS.0600.2016.05 (TCM Idea# 2009005041). For any such projects listed above in this section 2 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion.
|
3.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the tank improvement program listed under AFE# 164100007 (TCM Idea# 2015215004). The Partnership, in its sole discretion, shall determine the final scope of the project listed above in this section 3, if required to maintain safe operation and compliance of the Assets.
|
4.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following manifest rail unloading project identified: TCM Idea# 2016215023. The Partnership, in its sole discretion, shall determine the final scope of the project listed above in this section 4, if required to maintain safe operation and compliance of the Assets.
|
5.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following miscellaneous projects identified: AFE# 172100068 (TCM Idea# 2017211658), AFE# 162100077 (TCM Idea# 2016215022), TCM Idea# 2013215028, AFE#172100086 (TCM Idea# 2014215009). For any such projects listed above in this section 5 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion.
|
6.
|
All capital costs related to the installation of closed-purge, closed-loop, or closed-vent samplers at all storage tanks by 2021 (per the Consent Decree mentioned in Schedule 1). According to TRMC representatives, as recorded in section 2.2.4 of ERM’s Due Diligence Summary Report (October 2017), there are 42 tanks left to retrofit in the Assets covered by the 2017 Anacortes Contribution Agreement.
|
1.
|
The parties agree that the following tanks included in the 2017 Anacortes Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 36 months prior to the date hereof and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of TRMC.
|
Tank Number
|
TK001
|
TK019
|
TK024
|
TK025
|
TK026
|
TK028
|
TK060
|
TK091
|
TK092
|
TK134
|
TK248
|
TK156
|
TK158
|
TK180
|
TK241 A
|
TK241 B
|
2.
|
Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following miscellaneous projects identified in the tables below.
|
IEA) - Replace aging power poles in Tank Farm
|
IEA) - Upgrade Switch Racks
|
IEA) - Tank Farm Conduit
|
IEA) - Replace MOV's in the tank farm
|
IEA) - Replace Coggins Conduit and wire
|
IEA) - Tank Farm Grounding
|
IEA) - Install electric heat tracing
|
PIPE) - Upgrade steam piping in tank farm
|
REF) - Sample station compliance
|
IEA) - Skim oil sump level controller to P-709
|
INSP) - Required inspection work on V-801
|
INSP) - Required inspection work on TK-38
|
REF) - Purchase tank 8 heater
|
TKWK) - Roof Drains, Seal Failures
|
IEA) - Back pressure regulator for C4 to storage
|
INSP) - Offsite/Rack Piping RBMI Implementation – Field
|
REF) - Contingency boom replacement
|
IEA) - Causeway Conduit
|
PPXX) - Abrasive Blast and recoat wharf lines and remove asbestos conduit
|
REF) - Rebuild bumpers to be prioritized by operations
|
WINP) - Install stairway to access spill boats
|
RAIL) - Rail Maintenance & Inspection
|
Rail) - Rail Track Repair
|
3.
|
All additional operating expenses associated with accelerating the tank containment dike erosion control program, for the mitigation of erosion issues, over the next five years. This issue is recorded in section 2.2.2 of ERM’s Due Diligence Summary Report (October 2017) as well as section 3.2.1 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
4.
|
All costs related to the installation of independent high-high level switches, consistent with the established tank inspection and repair program. This issue is recorded in section 3.2.1 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
5.
|
All costs for any future modifications required to comply with Andeavor “Tank & Loading Rack” fire protection standard CPER-004 currently under review. This issue is recorded in section 3.4.11 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
6.
|
All costs for implementing a surge study for the wharf transfer piping and for any required modifications discovered as a result of this study. This issue is recorded in sections 2.2.1 and 6.2.1 of ERM’s Due Diligence Summary Report (October 2017).
|
7.
|
All costs for implementing a study of the dike arrangement to the north and east sides of Tank 38, which may not adequately direct contents to the remote containment area in the event of a vessel failure, and for any required modifications discovered as a result of this study. This issue is recorded in section 3.2.2 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
8.
|
All costs for potential future expenses of investigation and mitigation work related to seep of oil through the north secondary containment dike for tanks 6 and 7. This issue is recorded in sections 6.1.1 and 6.2.3 of ERM’s Due Diligence Summary Report (October 2017).
|
9.
|
All costs related to the installation of storage tank seals and gaskets, required by Refinery Sector Rule MACT Subpart CC, to be identified in the established compliance schedule for tank inspection and repair. This issue is recorded in section 2.2.3 of ERM’s Due Diligence Summary Report (October 2017).
|
10.
|
All costs to empty, blind-flange or air-gap any of the out-of-service tanks listed below.
|
Tank Number
|
TK034
|
TK046
|
TK047
|
TK048
|
TK055
|
TK062
|
TK088
|
TK089
|
TK090
|
TK095
|
TK098
|
TK099
|
TK110
|
TK147
|
TK159
|
TK232
|
TK249
|
11.
|
All costs for removal of out-of-service assets identified in section 6.2.8 of ERM’s Due Diligence Summary Report (October 2017). These assets include 17 tanks (shown in Section 10 above), asphalt loading rack, pipelines, red dye shed and lead shed.
|
12.
|
All costs related to the performing of an assessment of propane and butane vessel containment areas, and any resulting project expenses required, to ensure compliance with National Fire Protection Association (NFPA) fire codes. This issue is recorded in section 6.3.3 of ERM’s Due Diligence Summary Report (October 2017).
|
13.
|
All costs related to performing an initial direct assessment, and any resulting required repairs, of the Andeavor-owned segment of the underground “Kinder Morgan” crude pipeline. This issue is recorded in section 3.3.1 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
14.
|
All costs related to performing an initial inspection, and any resulting required repairs, of the wharf sumps. This issue is recorded in section 3.3.5 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
15.
|
All costs related to performing an initial inspection, and any resulting required repairs, of the cathodic protection (CP) systems for the aboveground storage tank bottoms, buried facility piping and marine structures. During this inspection the rectifiers will be surveyed and any rectifiers which are not Nationally Recognized Testing Laboratory (NRTL) listed per OSHA (Occupational Safety and Health Administration) and NFPA requirements will be replaced and costs will be subject for reimbursement. These issues are recorded in section 3.4.17 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017).
|
16.
|
All cost of in-service inspections and evaluations of the condition of tank walls and tank floors for each of the following tanks, using accepted engineering methods for non-invasive external inspections that do not require that a tank be emptied or structurally altered, which are conducted before the earlier of (i) an API 653 inspection of such tank and (ii) November 7, 2022, up to an aggregate reimbursable cost not to exceed two million dollars for all such tanks.
|
Tank Number
|
TK003
|
TK005
|
TK006
|
TK008
|
TK011
|
TK013
|
TK015
|
TK017
|
TK018
|
TK021
|
TK022
|
TK027
|
TK030
|
TK032
|
TK033
|
TK035
|
TK036
|
TK037
|
TK038
|
TK113
|
TK114
|
TK142
|
TK148
|
TK230
|
TK247
|
TK054
|
TK056
|
TK138
|
TK160
|
TK157
|
TK221
|
TK222
|
TK223
|
TK224
|
TK225
|
TK226
|
TK227
|
TK228
|
TK229
|
1.
|
Los Angeles Refinery Wilmington -
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of Partnership Group, the Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified:
|
IDEA #
|
AFE
|
DESCRIPTION
|
NA
|
LA-130014
|
RAIL CAR FALL PROTECTION
|
100000000000000007122018
|
NA
|
TANK GAUGING PH V
|
100000000000000013322018
|
NA
|
LAR CATHODIC PROTECTION PROGRAM
|
100000000000000014342018
|
NA
|
RP&S CONTROL SYSTEM MODERNIZATION
|
100000000000000020072018
|
NA
|
REPLACE EAST RAILCAR LOADING PLATFORM
|
100000000000000042922018
|
NA
|
Tank Gauging VII
|
100000000000000042822018
|
NA
|
UPR – LARW
|
NA
|
NA
|
Tank 11001 Double-Bottom Upgrade Project
|
NA
|
LA-120052
|
TANK GAUGING – PHASE III
|
NA
|
LA-160120
|
LARW FIREWATER UPGRADE NW TANK FARM – 5B
|
NA
|
LA-170005
|
2017 WIL TANK 80065 REBUILD
|
NA
|
LA-170010
|
TK-80081 REBUILD – CRUDE
|
NA
|
LA-170018
|
TK-080038 REBUILD
|
NA
|
LA-170038
|
2023 WIL TANK 80060 REBUILD – CRUDE
|
NA
|
TA-170031
|
2017 WIL TANK 80218 SHELL REPAIRS
|
NA
|
SC-189066 / TA-180016
|
TANK 80210 Unplanned Repairs (Revision No. WP 18044B)
|
2.
|
Los Angeles Refinery Carson -
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified:
|
IDEA #
|
AFE
|
DESCRIPTION
|
NA
|
LA-160102
|
70 SERIES BUTANE SPHERE LEVEL MEASUREMENT
|
NA
|
LA-180057
|
PROPANE LOADING ODORANT TRIP
|
NA
|
TA-170032
|
2018 CAR TANK 61 FLOOR/BOTTOM SHELL
|
3.
|
Mandan Refinery -
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified:
|
IDEA #
|
AFE
|
DESCRIPTION
|
NA
|
MN-170096
|
TANK FIELD MODERNIZATION - PHASE 4
|
100000000000000013852018
|
NA
|
FB-754 NEW CR & INTERNAL FLOATING ROOF CONVERSION
|
100000000000000013862018
|
NA
|
FB-706 NEW CR & INTERNAL FLOATING ROOF CONVERSION
|
NA
|
MN-180087
|
INSTALL SPARE GA-778 PROPANE LOADING PUMP
|
NA
|
MN-180084
|
TANK FIELD MODERNIZATION - PHASE 5
|
100000000000000020132018
|
NA
|
REPLACE OM PLC OR MOVE TO THE DCS
|
100000000000000020182018
|
NA
|
FB-724 - NEW INTERNAL FLOATING ROOF
|
NA
|
MN-180094
|
Firewater Line to Rail Switch Yard
|
NA
|
MN-180085
|
Oil Movements HPM Migration
|
100000000000000041422018
|
NA
|
FB-738 Foam Pipe and New Basin
|
NA
|
MN-170121
|
BUTANE TRUCK OFFLOADING
|
NA
|
TA-160011
|
FB-751 DOUBLE FLOOR REPLACEMENT
|
NA
|
TA-160013
|
FB-741 INTERNAL SHELL REPAIR
|
NA
|
TA-160014
|
FB-755 INSPECT AND REPAIR
|
100000000000000006842018
|
NA
|
FB-738 - BOTTOM REPAIRS AND BASIN ENHANCEMENT
|
100000000000000006852018
|
NA
|
FB-752 - BOTTOM REPAIRS AND BASIN ENHANCEMENT
|
100000000000000006862018
|
NA
|
FB-742 - BOTTOM REPLACEMENT
|
100000000000000006922018
|
NA
|
FB-710 Inspect and Repair
|
100000000000000006932018
|
NA
|
FB-726 Inspect and Repair
|
NA
|
TA-180109
|
FB-717 Repairs
|
100000000000000042412018
|
NA
|
Tank Field Modernization - Phase 6
|
NA
|
MN-180109 / NG-180069
|
Butane Sphere Valve Access Platforms
|
NA
|
MN-180100
|
Install Water Draw Systems on LPG Tanks
|
4.
|
Salt Lake Refinery -
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the Andeavor
|
5.
|
Delek Asphalt Terminals –
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified:
|
IDEA #
|
AFE
|
Location
|
DESCRIPTION
|
TBD
|
TBD
|
Fernley (50%)
|
Fall Protection – Truck
|
TBD
|
TBD
|
Fernley (50%)
|
Fall Protection – Rail
|
TBD
|
TBD
|
Fernley (50%)
|
Remove surface impoundment
|
TBD
|
TBD
|
Elk Grove
|
Fall Protection – Truck
|
TBD
|
TBD
|
Elk Grove
|
Fall Protection – Rail
|
TBD
|
TBD
|
Elk Grove
|
Replace CS RTO lines with SS
|
TBD
|
TBD
|
Elk Grove
|
Remove surface impoundment
|
TBD
|
TBD
|
Elk Grove
|
Piping debottleneck
|
TBD
|
TBD
|
Elk Grove
|
Refurbish PMA unit
|
TBD
|
TBD
|
Mojave
|
Fall Protection – Truck
|
TBD
|
TBD
|
Mojave
|
Fall Protection – Rail
|
TBD
|
TBD
|
Mojave
|
Hot oil booster pump
|
TBD
|
TBD
|
Bakersfield
|
Fall Protection – Truck
|
TBD
|
TBD
|
Bakersfield
|
Fall Protection – Rail
|
TBD
|
TBD
|
Bakersfield
|
Remove surface impoundment
|
TBD
|
TBD
|
Bakersfield
|
New Boiler/Steam Generator
|
TBD
|
TBD
|
Bakersfield
|
Hot Water tank
|
TBD
|
TBD
|
Bakersfield
|
New emission control unit
|
TBD
|
TBD
|
Phoenix
|
Fall Protection – Truck
|
TBD
|
TBD
|
Phoenix
|
Fall Protection – Rail
|
TBD
|
TBD
|
System
|
Spare emulsion mill/housing
|
TBD
|
TBD
|
System
|
Spare PMA mill tooling
|
6.
|
BakkenLink / Fryburg –
Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified:
|
IDEA #
|
AFE
|
DESCRIPTION
|
NA
|
NG-170034
|
FRYBURG RAIL TERMINAL T103 & T104 VALVE
|
NA
|
NG-180026
|
FRYBURG RAIL TERMINAL SECURITY IMPROVEMENT
|
NA
|
NG-180019
|
TGP METER SKID BUILDING UPGRADES
|
NA
|
NG-180020
|
ARC FLASH MITIGATION TGPM
|
NA
|
NG-180021
|
TANK LIGHTNING PROTECTION TGPM
|
NA
|
NG-180022
|
FLOWCAL IMPLEMENTATION BAKKENLINK
|
NA
|
NG-180017
|
TANK MIXERS T201 AND T301 AT WATFORD CIT
|
7.
|
Jal NGL Storage Facility
– Upon mutual consent on project scope between the applicable Andeavor Entities and the applicable members of the Partnership Group, the applicable Andeavor Entities shall reimburse the Partnership Group for all capital costs incurred for the execution of the following projects identified
|
IDEA #
|
AFE
|
DESCRIPTION
|
TBD
|
TBD
|
Dead leg removal project: Remove several dead legs SW of the pump house and reroute a brine water line to mitigate an existing ramp concern
|
99991944
|
NA
|
2019.SMT.Jal NGL Storage Facility. Brine Pond liner replacement and salt/sand disposal
|
TBD
|
TBD
|
2019.SMT.Jal. Inline filters for line coming in from MAPCO
|
TBD
|
TBD
|
2019.SMT.Jal NGL Storage Facility. Install a gas separator in the brine line
|
TBD
|
TBD
|
2019.SMT.Jal NGL Storage Facility. SDV upstream of product pumps & relocate discharge/suction valves outside of pump room
|
1.
|
The Parties agree that the following tanks relating to the LARW Refinery Unit included in the 2018 Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 36 months prior to the date hereof, or are deemed in compliance with API 653 through current risk-based management inspection (RBMI) standards and whose next API 653
|
Tank Number
|
776
|
777
|
778
|
779
|
780
|
1503
|
13502
|
50000
|
80035
|
80057
|
80092
|
80210
|
80219
|
125001
|
125002
|
2.
|
The Parties agree that the following tanks relating to the LARC Refinery Unit included in the 2018 Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 36 months prior to the date hereof, or are deemed in compliance with API 653 through current risk-based management inspection (RBMI) standards and whose next API 653 inspection is scheduled greater than 20 years after the Effective Date, and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of Andeavor.
|
Tank Number
|
74
|
350
|
351
|
352
|
353
|
354
|
355
|
681
|
3.
|
Upon mutual consent on project scope between the Andeavor Entities and the Partnership, the Andeavor Entities shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following miscellaneous projects at the LARW Refinery Unit or LARC Refinery Unit, identified in the table below.
|
4.
|
The Parties agree that the following tanks relating to the Mandan Refinery included in the 2018 Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 36 months prior to the date hereof, or are deemed in compliance with API 653 through current risk-based management inspection (RBMI) standards and whose next API 653 inspection is scheduled greater than 20 years after the Effective Date, and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of Andeavor.
|
Tank Number
|
FB-702
|
FB-708
|
FB-714
|
FB-715
|
FB-717
|
FB-721
|
FB-722
|
FB-725
|
FB-726
|
FB-728
|
FB-729
|
FB-731
|
FB-744
|
FB-747
|
FB-753
|
FB-758
|
FB-771
|
FB-774
|
5.
|
Upon mutual consent on project scope between Andeavor and the Partnership, the Andeavor Entities shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following miscellaneous projects at the Mandan Refinery, identified in the table below.
|
Expense Order #
|
Description
|
9074513
|
OTE – GA759 & GA759S Pump Foundation Replacement
|
9026500
|
OTE – Remove OM RV Pot & Modify Drain Piping
|
unknown
|
OTE – Resolve Wet Propane Issue
|
6.
|
The Parties agree that the following tanks relating to the Salt Lake Refinery included in the 2018 Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 36 months prior to the date hereof, or are deemed in compliance with API 653 through current risk-based management inspection (RBMI) standards and whose next API 653 inspection is scheduled greater than 20 years after the Effective Date, and are excluded
|
Tank Number
|
142
|
190
|
204
|
212
|
213
|
244
|
245
|
306
|
321
|
326
|
330
|
427C
|
7.
|
Upon mutual consent on project scope between Andeavor and the Partnership, the Andeavor Entities shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following project at the Salt Lake Refinery, identified in the table below.
|
IDEA #
|
Description
|
Unknown
|
Tank 297 – Lift and Level
|
Unknown
|
J-928D ATB Loading
|
8.
|
Upon mutual consent on project scope between Andeavor and the Partnership, the Andeavor Entities shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following miscellaneous projects identified in the table below.
|
Description
|
Location
|
Berm repair
|
Elk Grove
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
LAR Wilmington
|
LPG vessels 6000 and 6001 as well as the 700 series LPG vessels (7 total) do not have a back-flow check valve or thermal activated automatic shutdown valve in place as required per NFPA 58.
|
All costs for upgrades required to comply with NFPA 58 automatic shutdown requirements on tanks 6000 and 6001 and 700 series tanks
|
LAR Wilmington
|
Pressure relief devices on V-1700 series pressure vessels (gasoline) vent to atmosphere directly above vessel.
|
All costs to evaluate requirements and for any related projects required to reroute V-1700 series pressure vessels relief vents
|
LAR Wilmington
|
No cable type ground connection between the rack and rail car was observed.
|
All costs to evaluate grounding requirements at the LPG train car rack and for any related projects required to meet Andeavor standards
|
LAR Wilmington
|
The loading safety platforms need upgraded.
|
All costs to upgrade rail car loading racks to Andeavor Logistics standards
|
LAR Wilmington
|
The truck rack lacks a grounding assurance system.
|
All costs to install interlocks and grounding systems on Truck & Rail racks
|
LAR Wilmington
|
Arc flash labeling is incomplete.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
LAR Wilmington
|
The Honeywell DCS system for both the inline blending area and tank farm is no longer supported. A project has been identified to upgrade to the E300 system.
|
All costs related to any control system upgrades needed for the Honeywell inline blender
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
LAR Wilmington
|
The first phases of the project to upgrade tank gauging to radar type used a wireless system to report data to the control system. Current Andeavor practice is hard wire level transmitters. An evaluation of the security of the wireless system is being conducted.
|
All costs related to modifying wireless systems to hardwire to meet Andeavor standards.
|
LAR Wilmington
|
There is an ongoing, but incomplete project to upgrade the tank gauging system to radar type. Approximately 30 tanks still need to be completed.
|
All costs to upgrade tank gauging to radar types
|
LAR Wilmington
|
No operational cathodic protection exists to protect aboveground storage tanks with single bottom floors or buried facility piping in direct soil contact.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
LAR Wilmington
|
No fixed fire protection on tanks 13506, 13507, 13508, 7200.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
LAR Wilmington
|
The following observations were made related to secondary containment at LARW that will require additional investment:
• Erosion of roads and berms was observed (not only asphaltic covering, but the underlying soil starting to show shear, erosion, signs of scouring).
• Integrity of sidewalls, cracks observed in concrete around west side tanks (north wall). • Weak and uncoated points in berms. • Tank dike floor has been excavated to below the berm wall substrate in South tank farm, which may compromise the berm integrity. • Piping interconnections between berms should be reviewed as part of the SPCC Plan renewal efforts. |
All costs to complete SPCC plan review and to make any necessary repairs to improve tank farm berms and roadways at LAR-Wilmington
|
LAR Wilmington
|
LPG Rail and Truck loading racks lack the following safe guards:
• No driver card system, • Loading operation is manual, • No predetermined load volume capacity, • No automated gauge/level monitoring, • functional fire detection UV/IR with automatic water deluge (system is installed, but has not been commissioned). |
All costs for initial review of safe guards and for any resulting improvements required to bring the LPG rail and truck rack up to Andeavor standards
|
LAR Wilmington
|
Four clusters of four 80,000 bbl. tanks containing crude, slop, transmix or VGO have comingled secondary containment dikes. An event of loss of primary containment (LOPC) in one tank would spread to the entire surface of the common dike floor, creating a large spill area. If the event is ignited (pool fire) the consequence would be more severe and lead to potential escalation to neighboring tanks. Construction of additional segregation berms would be required for tank segregation containment.
|
All costs to conduct fire risk study, to determine risks associated with shared containment dikes, and for any related projects required to address NFPA deficiencies
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
LAR Wilmington
|
Butane spheres and propane bullets near to the road tanker loading/unloading area are not equipped with flammable or fire detection.
|
All costs to evaluate fire protection systems to ensure compliance with NFPA, local city regulations and Andeavor fire protection standards; and for any resulting modifications required to comply with above regulations and standards
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Mandan
|
No document control for P&ID updates or revisions. Work history on pumps is only available for the past year due to the new system for tracking pump maintenance.
|
All costs to evaluate document controls and determine if appropriate P&ID's, plot plans, isometric and electrical one-line drawings and maintenance records are in place, as well as to prepare any required documents.
|
Mandan
|
The rail car loading stations on track 8 have catch basins for spill collection. The catch basins are piped to a sump with integrity of buried pipe unknown.
|
All costs of recommended underground piping replacements, as a result of initial catch basin inspections. Inspections are being implemented into refinery inspection programs for rail car loading stations.
|
Mandan
|
Cable tray and conduit has failed at many locations due to being exposed to snow loads, or due to settling/heaving or failure of pipe supports. Failed conduit may be located in classified areas, with internal wiring exposed.
|
All costs to perform a survey of the tank farm and identify any failed trays and conduits and implement projects to repair.
|
Mandan
|
Fire and Gas detection is typical of this type of facility and consists of direct observation by field personnel.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
Mandan
|
35 storage tanks do not have fixed fire protection systems for delivery of foam to the tank interior.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
Mandan
|
Fire foam piping within the tank farm is poorly supported due to support failure. Supports have jacked or settled and, in several locations, are no longer supporting the piping.
|
All costs to conduct a survey of the tank farm, to determine if there are failed fire foam piping supports, and for any resulting projects required to make repairs
|
Mandan
|
Storage tank level monitoring varies throughout tank farm. Some tanks do not have independent high-level switches. Some tanks do not have levels that report to the control room - level is monitored at the tank using the gauge board. Lack of high level switches increases potential for overfill.
|
All costs to conduct a survey of the Andeavor requirement for high level switches, and for any resulting projects to address deficiencies
|
Mandan
|
No lightning protection system was observed on storage tanks with EFRs.
|
All costs to evaluate requirements for lightning protection on storage tanks and to address any deficiencies to Andeavor standards
|
Mandan
|
Cathodic protection of the buried product facility piping could not be verified as CP monitoring is not being performed on an annual basis.
|
All costs related to conduct an initial cathodic protection survey and for addressing any cathodic protection deficiencies discovered
|
Mandan
|
Cathodic protection of the tank bottoms could not be verified as perimeter readings are being obtained and the data is suspect.
|
All costs related to conduct an initial cathodic protection survey and for addressing any cathodic protection deficiencies discovered
|
Mandan
|
Tracks have significant settlement at decanted oil, diesel and jet, and LPG transfer areas.
|
All costs for one-time 3rd party rail integrity assessment and any repair recommendations identified
|
Mandan
|
Rail electrical isolation between mainline and spurs to decanted oil, diesel and jet, and LPG transfer areas appears to be compromised.
|
All costs for one-time 3rd party rail integrity assessment and any repair recommendations identified
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Salt Lake
|
Tanks sharing a dike cell lack intermediate berms and do not provide 100% separation with the other tanks in such that they could inundate the adjacent tank if a spill occurred. A spill fire would be contained within the main diked area.
|
All costs to conduct fire risk study, to determine risks associated with shared containment dikes, and for any related projects required to address NFPA deficiencies
|
Salt Lake
|
Many dike walls contain open culverts for communication between containment cells, or unsealed casings between cells. As a result, containment dike walls do not provide 100% separation with the other tanks in such that they could inundate the adjacent tank if a spill occurred. A spill fire would be contained within the main diked area.
|
All costs to conduct fire risk study, to determine risks associated with shared containment dikes, and for any related projects required to address NFPA deficiencies
|
Salt Lake
|
Tank 325 was modified with 6 vertical channel stiffeners at the north side of the tank to maintain the shape of the tank due to a reported fire in 1989. Refinery staff indicated issues with the floating roof snagging on the shell.
|
All costs to conduct an inspection of tank 325 and to address repairs through refinery tank repair program
|
Salt Lake
|
The shell at the bottom two courses of Tank 322 appears to be bulging, and the inspections group has been notified.
|
All costs to conduct an inspection of tank 322 and to address repairs through refinery tank repair program
|
Salt Lake
|
Dents or shell wall distortion is present at the 3rd and 4th course at the east side of tank 297, and at the base course of tank 308.
|
All costs to conduct inspections of tanks 297 and 308 and to address repairs through refinery tank repair program
|
Salt Lake
|
Riveted tanks are notes as weeping, resulting in staining on the ground.
|
All costs to conduct inspections of applicable riveted tanks and to address repairs and or replacement through refinery tank repair program
|
Salt Lake
|
Tank 204 containment area has hydrocarbon product seeping from underground around the perimeter of the tank with oil staining at the gravel directly beneath the tank chime and throughout the containment dike areas.
|
All costs for managing Tank 204 asphalt contamination remediation and clean up, including any required tank inspections or related repairs or modifications
|
Salt Lake
|
Floating oil at surface water present at tank 247 due to storm water backup to oily waste system during rain event.
|
All costs to clean up tank 247 containment due to stormwater backups
|
Salt Lake
|
Out of service and dead leg piping in the tank farm is not actively managed.
|
All costs to conduct a study to identify out of service and dead leg piping in the tank farm and for any projects required to address recommendations per Andeavor standards
|
Salt Lake
|
Some grounding operations at loading/unloading racks do not have ground proving (Scully) systems in place.
|
All costs to conduct an evaluation of the potential need for ground proving interlocks on truck racks and for any resulting upgrades required per Andeavor Standards
|
Salt Lake
|
The butane loading rack building's concrete column and roof girders are heavily spalled with exposed reinforcing steel throughout.
|
All costs to conduct an evaluation of the butane loading rack building concrete columns and roof girders, and for any projects required to address resulting recommendations
|
Salt Lake
|
No automated fire or gas detection systems were observed; however this is typical for this type of facility.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Salt Lake
|
27 storage tanks do not have fixed fire protection systems for delivery of foam to the tank interior.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
Salt Lake
|
The fire foam piping at 5 of the tanks with fire foam chambers extend down the shell with a flanged connection near grade. The fire foam piping does not extend to the edge of the containment dike. In the event of a fire, fire department would not have access to the foam piping connection without entering the dike and bolting up a flange. Connection to the existing flanged connection at the tank shell is unlikely to occur in the event of a fire event.
|
All costs to perform a study to determine if facility is in compliance with NFPA codes and for any related projects to comply with fire codes or Andeavor standards
|
Salt Lake
|
The software controlling the gasoline blender pumps is outdated and no longer supported.
|
All costs related to upgrading the automation controls at the blender per Andeavor standards
|
Salt Lake
|
Storage tank level high-high level switches are not independently hardwired back to the DCS.
|
All costs related to installing High-High level switches to comply with NFPA 30 Chapter 21.7.1.1 and Andeavor standards
|
Salt Lake
|
Tank level alarms set higher than currently recommended by API 2350 resulting in recent overfill of one of the vessels.
|
All costs to conduct an alarm rationalization study on tank level alarm settings and to make required revisions in control systems per Andeavor standards
|
Salt Lake
|
Cathodic protection levels could not be verified for select aboveground storage tank bottoms and the buried facility piping.
|
All costs related to conduct an initial cathodic protection survey and for addressing any cathodic protection deficiencies discovered
|
Salt Lake
|
Asphalt seeps were observed within the bermed area at Tank 204. The seeps cover areas around Tank 204 and can impact operations within the containment area.
|
All costs for managing Tank 204 asphalt contamination remediation and clean up, including any required tank inspections or related repairs or modifications
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Salt Lake
|
The following issues with secondary containment and stormwater/wastewater management were identified at the Site:
1) a survey of secondary containment volumes was completed during 2018 to confirm adequacy with respect to SPCC requirements; the report identified that Tanks 244 and 245 have inadequate secondary containment capacity and redesign is anticipated by the environmental representative. 2) The manual drain valve for the secondary containment berm around Tank 157 was reported by site personnel to be maintained open to allow general stormwater drainage from the depressed (low-area), exterior roadway to drain water from the road into the bermed area for storage/evaporation in an effort to reduce flooding; however, this is contrary to SPCC requirements. 3) Free phase oil mixed with water was observed within the secondary containment berm for Tank 247. The site representative reported that the wastewater treatment facility capacity can be overwhelmed following heavy precipitation events, as occurred the day before the site visit. The backup of hydrocarbon containing wastewater into the tank berms reduces the secondary containment capacity and could result (temporarily) in noncompliance with the SPCC requirements as well as additional H&S and remediation activities. |
All costs related to addressing improvements to SPCC plan containment and stormwater related deficiencies, as well as all costs related to wastewater cleanup
|
Salt Lake
|
Site is in the process of completing a Baker Risk facility siting evaluation. Based on visual evidence and interviews with site personnel, major equipment relocation costs are anticipated.
|
All costs for repairs or projects to address risk reduction recommendations from Baker Risk Siting evaluation
|
Salt Lake
|
Eleven tanks have been identified that will require equipment upgrades in 2025 for compliance with the Refinery Sector Rules (RSR) provisions for tank seal and fitting vapor controls. The Refinery cost estimates are presented in the plant Ten Year Tank and Boiler Plan 2017.
|
All costs for tank seal and fitting vapor controls projects required for compliance with Refinery Sector Rules
|
Salt Lake
|
All costs for venting and emission controls projects required for compliance with Refinery Sector Rules
|
|
Salt Lake
|
The OMD (Oil Movements Division) PHA included the tank farm and remote tank farm. This PHA is currently in draft and under Site review. The PSM coordinator specifically indicated two recommendations will need to be corrected and are likely to be material:
(1) A corrosion study needs to be completed and recommendations implemented.
(2) More than 20 deadlegs were identified that potentially would need to be removed from service throughout the tank farm.
|
All costs to finalize PHA study and obtain related recommendations and then to address findings
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Salt Lake
|
Three railcar derailments have occurred at the Site in the last 8 months, with one major derailment that required third party intervention to upright the cars. Facility representatives stated that one derailment was caused by ice and the other two derailments were caused by a rail integrity issue. The portion of the rail that was causing the issue was not identified during routine rail inspections. Representatives reported that the root cause of the rail integrity issue has not been identified. This rail section has since been replaced. Without understanding the integrity issue failure, the Site is not able to proactive address other sections of rail that may have similar integrity issues.
|
All costs for one-time 3rd party rail integrity assessment and any repair recommendations identified
|
Salt Lake
|
No hydrocarbon detection and alarm systems exist in the LPG truck loading area that could notify operations of a continuous release. An LPG release in close proximity to loading trucks accessing the rack could result in a high consequence event.
|
All costs to evaluate the potential need to install hydrocarbon detection and alarms at the LPG truck loading rack and to ensure compliance with NFPA and Andeavor Fire Standards, and then to address any deficiencies discovered
|
Salt Lake
|
There are >20 tanks that will require foam injection capabilities to be added to meet Andeavor standards requirements.
|
All costs to conduct a study of fire protection systems and identify tanks needing modification to comply with NFPA or Andeavor fire protection standards, and then to address any deficiencies discovered
|
Salt Lake
|
A 2011 Hydraulic Model Study identified the blending facility lacks potential firefighting infrastructure.
|
All costs for upgrading the firefighting infrastructure at the blending facility per Andeavor standards
|
Salt Lake
|
Five pressure relief devices (PRD) within the tank farm are anticipated to be subject to the RSR PRD standards. The Site has not yet completed the regulatory evaluation and the final applicability determination. PRD monitoring systems are required for systems to be in compliance with the rule.
|
All costs to conduct a regulatory evaluation to determine if PRD monitoring systems are required to comply with Refinery Sector Rules, and then to address any deficiencies identified
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Conan
|
Pipe traps may not have proper dimension to support ILI tools. Oversize pipe segment (barrel) appears to be too short. Also, no flanges are provided to allow for extending the barrel length.
# Receivers: 85 (assuming only receivers at CTB’s, TUL’s and Conan Terminal in scope) # Launchers: 79 (assuming only launchers at CTB’s and TUL’s in scope). It appears the launchers/receivers could be prepared for ILI using a replacement barrel and additional pipe spools (sharing of the replacement barrel and piping is dependent on diameter; system contains piping with diameter 6”, 8”, 10, 12” and 16”). Estimated cost for 10 extended barrels (launcher and receiver) and associated piping: $500k. |
All costs related to correcting design issues with receivers and launchers.
|
Conan
|
Currently the leak detection system is mass balance system and is scheduled to be upgraded to ATMOS (quote was provided to project manager). Andeavor typically uses CPM through ATMOS.
Total 91 Coriolis meters installed. Price to upgrade to ATMOS CPM is approx. $500k. |
All costs to evaluate if ATMOS system is needed and for any resulting upgrade of the leak detection systems.
|
Conan
|
Fire Suppression - A modification to the tank fire protection system at Conan Terminal was ordered by EOG and is scheduled (Protect-O-Burn Self Expanding Foam System for rim seal protection on (3) tanks). Allocation of additional $1.2MM quoted cost for entire system is unknown.
|
All required costs to upgrade the fire system for rim seal protection on 3 tanks as ordered by EOG after determination of Andeavor Entity/Partnership Group allocation
|
Conan
|
Although the facilities are exempt from industrial stormwater permitting requirements by rule, it is not clear whether the design of the facilities is adequate to prevent discharges of contaminants that could otherwise trigger individual permit requirements.
• Division berms and grading design may be insufficient to control drainage across the facilities (Hercules TUL in particular) and prevent stormwater from coming in contact with pollutants associated with process and truck unloading areas prior to off-site discharge • Stormwater tanks associated with the truck unloading areas should be assessed for adequate capacity for the amount of received drainage Improved stormwater management/diversion practices are likely to be material. |
All costs related to conduct an engineering design study for addressing containment of storm water within the property and for any resulting required projects to address deficiencies in storm water containment.
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Midland Terminals: Geneva/Zurich/Rio Pipeline
|
Rio Pipeline & Midland Short Haul Pipelines - CIS has not been performed to evaluate stray current interference from foreign operators.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys.
|
Midland Terminals: Geneva/Zurich/Rio Pipeline
|
Rio Pipeline – Rectifier #2 and #3 do not have AC power installed.
|
All costs related to projects required to install power to rectifiers #2 and #3
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Geneva
|
The following issues related to secondary containment were noted:
- Facility off-loading lacks secondary containment. - No design basis for secondary containment berm around tanks (e.g., survey and geotechnical data on construction materials); - Blowing sand has filled part of secondary containment and berm erosion has occurred. - Additional concerns with containment capacity based on tank manifolding (three tanks are manifolded such that failure from one tank results in release from all three). |
All costs related to conducting a containment survey and for any resulting projects required to address deficiencies found
|
Geneva
|
The following issues related to secondary containment were identified:
-Inadequate secondary containment capacity for H2S scavenger stored in unloading area. |
All costs related to conducting a containment survey and validating SPCC plan and for any resulting projects required to address deficiencies found
|
Stateline
|
Crude release (24.4 Bbls) occurred on March 8, 2018 due to power outage, which flowed across property and off-site onto a neighboring. Remedial actions are in process. Additional information is required to ensure that the cleanup meets Texas cleanup requirements.
|
All costs related to indemnify for long term subsurface liability, if warranted, and to ensure remedial efforts meet the TCEQ Standards
|
Stateline
|
Lack of documentation indicating if retention pond has adequate capacity to prevent uncontrolled discharge from facility.
|
All costs related to conducting a study to determine capacity of stormwater retention pond and for making any resulting upgrades to ensure compliance with permits
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Bobcat & Wink Short Haul Pipelines - The pipelines do not exhibit adequate levels of cathodic protection at multiple test point locations.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys.
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Bobcat & Wink Short Haul Pipelines - CIS has not been performed to evaluate stray current interference from foreign operators.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys.
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Consider appropriate measures for leak detection including CPM systems such as ATMOS or Telvent.
|
All costs to conduct a study to determine if additional leak detection measures are needed and for any resulting projects required to address leak detection deficiencies
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
MCC Module panel boards, vendor modules and skids, and cathodic protection equipment lack Arc flash labels.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Kinder Morgan and Plains sites lack arc flash labels.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Tank 3513 - One test point location does not exhibit adequate levels of cathodic protection.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
Wink Station, Bobcat Pipeline, and Jack Rabbit Short Haul Pipelines
|
Jackrabbit Station - Cathodic protection levels of the buried facility piping could not be verified as CP monitoring is not being performed on an annual basis.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
Mason Station East
|
A study was conducted by Rooney Engineering after a flooding event occurred. Some upgrades were made based on the study, but similar rain events have not reoccurred yet to determine if the corrective measures were adequate. Further evaluation and additional upgrades could be required
|
All costs related to addressing any remaining Rooney Engineering recommendations deemed necessary for mitigation of facility flooding
|
Mason Station East
|
MCC Module, fire pump building, and warehouse building panel boards lack arc flash labels.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
Mason Station East
|
The aboveground storage tanks do not exhibit adequate levels of cathodic protection at some test point locations.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
Mason Station East
|
Cathodic protection levels of the buried facility piping could not be verified as CP monitoring is not being performed on an annual basis.
|
All costs related to conduct an initial cathodic protection survey and for addressing any cathodic protection deficiencies discovered
|
TexNewMexX: Yucca & Mesquite
|
Mesquite & Yucca – Some MCC Module panel boards and cathodic protection equipment lack arc flash labels.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
TexNewMexX: Yucca & Mesquite
|
Mesquite & Yucca – Cathodic protection levels of the buried facility piping could not be verified as CP monitoring is not being performed on an annual basis.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Jal
|
Out-of-service fractionator equipment has been abandoned in place with heat exchanger heads open, vessel manways open, open-ended piping. There is no HazCom signage (i.e. regarding confined spaces, ACM, lead-based paint) and the volume/quantity of lead based paint and ACM has not been quantified.
|
All costs related to conduct study to determine if tanks should be demolished and associated costs to demolish tanks, if needed
|
Jal
|
The facility siting study required under PSM is not based on the current site layout.
|
All costs related to evaluation of facility siting based on current site layout and for any resulting modifications required
|
Jal NGL Storage Facility
|
A number of concrete piping supports are cracked or completely broken away exposing the rebar.
|
All costs related to repairing identified broken concrete pipe supports
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Jal NGL Storage Facility
|
The rail access platform was constructed in the late 1950’s with the construction of the fractionation plant and currently would be unable to support the weight of a new safe rack gate system if future safety upgrades are required.
|
All costs to conduct a study of the rail access platform and for any resulting projects required to make safety improvements to meet Andeavor standards
|
Jal NGL Storage Facility
|
The LGP rail access platforms have no overhead tie-in safety system for the operators to use when accessing the top of the rail cars.
|
All costs related to projects to upgrade rail car racks loading platforms to ensure safe access to meet Andeavor standards
|
Jal NGL Storage Facility
|
Well-degasser needed for facility. A casing leak could lead to butane in water which settles into storage ponds for a large flashing to atmosphere scenario. If ignition source is found near pond this could lead to a vapor cloud explosion.
|
All costs related to evaluation of potential casing leak scenario and costs to implement recommended safe practices
|
Jal NGL Storage Facility
|
T-825 does not have a U-Stamp affixed to the vessel and will require replacement of the vessel.
|
All costs related to installation of a new vessel or to provide certification and U-stamp for
T-825. |
Jal NGL Storage Facility
|
Arc flash labeling is not provided on any of the electrical equipment.
|
All costs for installation of required Arc Flash labels, discovered through initial evaluation
|
Jal NGL Storage Facility
|
Area classification drawings are not available.
|
All costs to create and stamp facility electrical area classification drawings
|
Jal NGL Storage Facility
|
No on-site water or foam supply for fire protection. Fire protection is provided by volunteer fire department with limited resources for water supply.
|
All costs related to making required water or foam supply modifications to comply with Andeavor fire protection standards
|
Jal NGL Storage Facility
|
No fire or gas detection is provided. Operations is particularly concerned with the lack of fire and gas detection in the pumphouse.
|
All costs related to performing an evaluation to determine if additional fire or gas detection is needed and for installing fixed gas detection monitors and or ESD at the pumphouse as per Andeavor standards
|
Jal NGL Storage Facility
|
A SCADA control system is not installed. All controls and interlocks are directly hardwired, and remote monitoring is not provided for operators.
|
All costs for installation of remote monitoring or SCADA control systems to meet Andeavor standards
|
Jal NGL Storage Facility
|
Consideration should be given to performing a PHA and evaluating the need for additional ESD valves for the wells.
|
All costs related to conducting a PHA study and for any required projects to address deficiencies
|
Jal NGL Storage Facility
|
Tank 825 is not equipped with any pressure instrumentation, temperature instrumentation, or automated valves. Recommend evaluating the need for additional monitoring and protection for the tank.
|
All costs to perform automation study and for any resulting projects to install automation instrumentation for tank 825 to meet Andeavor standards
|
Jal NGL Storage Facility
|
The booster pump and Tank 825 are not equipped with bonding jumpers.
|
All costs to survey facility and identify any conduit fittings missing bonding jumpers and to address deficiencies
|
Jal NGL Storage Facility
|
Some liquid-tight fittings are not installed with bonding jumpers.
|
All costs to survey facility and identify any conduit fittings missing bonding jumpers and to address deficiencies
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursement
|
Jal NGL Storage Facility
|
Tank ground indication is not provided at the rail rack.
|
All costs related to installation of pump interlocks and ground proving (Scully) systems on rail rack to meet Andeavor standards
|
Jal NGL Storage Facility
|
Pump interlocks with the truck rack and rail rack grounding systems are not provided.
|
All costs to install pump interlocks and ground proving (Scully) systems on truck rack to meet Andeavor standards
|
Jal NGL Storage Facility
|
Two truck loading spots are not provided with ground indication.
|
All costs to install ground proving (Scully) systems on truck racks to meet Andeavor standards
|
Jal NGL Storage Facility
|
No active CP systems or monitoring program is in place for the buried facility piping. A foreign CP system is adjacent to the facility which could be cause stray current interference.
|
All costs related to addressing cathodic protection deficiencies after verification of cathodic protection surveys
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Elk Grove Terminal
|
An unsupported vent pipe span at the polymer modified asphalt blending area is experiencing excessive movement and deflection.
|
All costs to conduct an engineering review of unsupported piping spans at the polymer modified asphalt blending area and to address any deficiencies identified
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Elk Grove Terminal
|
Rail rack piping has no expansion loops for piping flexibility. Offload pumps are located at both ends of the rail rack which act as anchors and pump nozzles could be overstressed.
|
All costs to conduct an engineering review of unsupported piping spans at the rail rack and address any deficiencies identified
|
Elk Grove Terminal
|
The condensate return tank (adjacent to the hot oil heaters) is vibrating excessively.
|
All costs to conduct an engineering review of the condensate return tank, to determine root cause of excessive vibration, and to address any deficiencies identified
|
Elk Grove Terminal
|
The retractable landings do not provide fall protection on all sides.
|
All costs to Implement interim mitigations to reduce risk of falls to personnel and undertake projects to address tank fall protection concerns at the truck offloading stations.
|
Elk Grove Terminal
|
No fall protection is present for personnel accessing the tops of rail cars.
|
All costs to Implement interim mitigations to reduce risk of falls to personnel and undertake projects to address tank fall protection concerns at the rail car.
|
Elk Grove Terminal
|
Existing vapor collection piping is reportedly plugging regularly, and the system is not adequately functioning.
|
All costs to investigate root cause of plugging in the vapor collection piping and for any projects required to repair
|
Elk Grove Terminal
|
The vapor collection system piping is not finished.
|
All costs to evaluate and complete prior project for Phase 2 installation of vapor collection systems, if required
|
Elk Grove Terminal
|
Although the site is equipped with seven cameras, the image quality is poor, and they are frequently non-functional.
|
All costs to conduct a security assessment to ensure compliance with Andeavor security standards and to address any gaps through a security upgrade project and to update security cameras.
|
Elk Grove Terminal
|
No arc-flash studies have been conducted and the electrical distribution equipment is not equipped with arc-flash warning labels.
|
All costs for installation of required Arc Flash labels and other recommendations per Andeavor standards, discovered through initial evaluation
|
Elk Grove Terminal
|
Electrical drawings (One-Lines, Area Plans) and documentation are not available for the terminal. Limited project specific documents may be available.
|
All costs to determine if appropriate P&ID's, plot plans, isometric and electrical one-line drawings and maintenance records are in place, as well as to prepare any required documents.
|
Elk Grove Terminal
|
No automated fire or gas detection systems were observed; however, this is typical for this type of facility. Manual alarm pushbuttons are installed, but are not functional.
|
All costs related to performing an evaluation to determine if additional fire or gas detection is needed and for addressing any identified deficiencies in compliance with NFPA codes and Andeavor fire safety standards
|
Elk Grove Terminal
|
A control panel is available for the PMA and tank wetting systems, but no other SCADA controls are available at the terminal for remote monitoring or automated shutdowns.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Elk Grove Terminal
|
A control panel is available for the SAAB tank gauging, but it was only operational for a short period.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Elk Grove Terminal
|
The emulsion tanks are not equipped with either radar or site gauges.
|
All costs to conduct a study to evaluate need for SCADA or similar controls for the emulsion tanks and to implement findings as per Andeavor standards
|
Elk Grove Terminal
|
Asphalt tanks are equipped with Rosemount SAAB level radar gauges, but do not have Varec local site gauges for back-up. Reportedly, there is a project to install Varec gauges. The SAAB level radar gauges are not currently able to be remotely monitored.
|
All costs to conduct a study to evaluate need for SCADA or similar controls on the asphalt tanks and for installation of remote monitoring or SCADA control systems, Sabb Radar gauges, Varec local gauges and remote monitoring systems per Andeavor standards
|
Elk Grove Terminal
|
Cathodic protection systems do not exist to protect select aboveground storage tank bottoms and buried facility piping in direct soil contact.
|
All costs to conduct a Cathodic Protection survey and to make recommended repairs to address deficiencies as per Andeavor standards
|
Elk Grove Terminal
|
The Stairs/landings/walkways at the south end of the tank farm do not include a kick plate or center guardrail, and the guardrail members are not adequately sized to resist code applied live loads. The grating and support structure appears to be undersized since the grating surface is bouncy. In addition, piping running along the landings present a tripping hazard.
|
All costs
to
for projects required to address deficiencies with stairs, landings and walkways in the emulsion tank farm including kick plates and undersized gratings.
|
Elk Grove Terminal
|
The Stairs/landings/walkways at the Emulsion tank farm do not include a kick plate or center guardrail, and the guardrail members are not adequately sized to resist code applied live loads. The grating and support structure appears to be undersized since the grating surface is bouncy. In addition, piping running along the landings present a tripping hazard.
|
All costs to for projects required to address deficiencies with stairs, landings and walkways in the emulsion tank farm.
|
Elk Grove
|
The site has experienced numerous spills of asphalt. The spilled material was observed throughout the emulsion plant and the site. The non-recoverable asphalt storage area is full, and the site has begun a practice of placing non-recoverable asphalt materials onto the soil near the non-recoverable asphalt storage area.
|
All costs to perform initial clean up and disposal of non-recoverable asphalt as a result of historical spills across the site
|
Elk Grove
|
The on-site pre-fabricated fire pump is not compliant with NFPA 20 and the 2016 California Fire Code. The following issues were identified:
• The expose cables and battery constitute an electrical hazard; • The condition of the pump is not adequate - leaking oil is potentially providing an additional fire hazard; • The pump is feed by liquefied petroleum gas (LPG) which provides additional fire hazard, conditions of the electrical cables could lead to ignition. Are drive by diesel or electricity, LPG is not an acceptable medium to run a fire pump; and • Exhaust is release inside the room allowing for the accumulation of accumulating carbon monoxide. |
All costs to conduct an inspection of the fire water pump, to determine if any potential areas of non- compliance with NFPA 20 and California Fire Code exist, and for any projects required to address deficiencies
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Elk Grove
|
The following issues related to SPCC were identified.
A 26-inch wall surrounds the emulsion plant on three sides. The fourth side is the emulsion plant building; piping penetrations through the wall do not appear sealed, which reduces the actual containment volume. Additionally, ERM noted the following issues with containment at the asphalt plant: • Squirrels and burrowing owls are nesting in the containment walls, affecting berm integrity (the burrowing owl is a protected species). • Rainwater is pumped into the containment areas during times of heavy rainfall, limiting containment capacity. |
All costs to evaluate SPCC issues identified and to address any deficiencies
|
Elk Grove
|
The site has experienced numerous asphalt spills. Most notable, in 2017, 125 tons of product from tank 100-M2 was released due to a tank bottom failure. The majority of the spilled materials were removed Clean Harbors. The removal of spilled material was ceased to allow for the tank to be repaired. During warm weather, asphalt seeps are observed in the former spill area. In general, spilled asphalt materials were observed on the ground throughout the emulsion plant and the site. The non-recoverable asphalt jersey barriers is overfilled and the site has begun a practice of placing non-recoverable asphalt materials onto the soil near the barriers.
|
All costs to perform initial clean up asphalt seeping from the area around Tank 100-M2
|
Elk Grove
|
The site has installed a RTO, with some of the piping replaced with stainless steel. The remainder of the piping needs to be replaced to allow the RTO to properly operate. Estimated cost
s
for this upgrade is $400K.
|
All costs to complete stainless steel piping replacement on RTO
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Mojave Terminal
|
The listed API 650 name plate on tanks TK-1, TK-2, TK-3, and TK-4 state the maximum operating temperature at 180 Deg. F. The current operating temperatures of all four tanks are 350 Deg F. Documentation does not exist to support the current operating temperature which is beyond the stamped tank design.
|
All costs to conduct engineering reviews and management of change (MOC) reviews for TK-1, TK-2, TK-3, and TK-4, to verify the maximum allowable temperature of the asphalt tanks, and to make any required updates to tank nameplates and provide documentation of change
|
Mojave Terminal
|
High level alarms for storage tanks do not exist. Tank gauging equipment and infrastructure are in place.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Mojave Terminal
|
Active below ground lines are present in facility (rail offload rack). No existing cathodic protection systems in place or inspection programs.
|
All costs to conduct a Cathodic Protection survey and to make recommended repairs to address deficiencies as per Andeavor standards
|
Mojave Terminal
|
The retractable landings do not provide fall protection on all sides.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns at the truck offloading stations.
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Phoenix
|
Underground vaults and drains are located at the site. Reportedly, the vaults discharge to the stormwater pond. However, piping was not observed at this discharge location. A piping drawing for underground lines does not exist according to site personnel. Facility personnel are unaware where the stormwater is discharging.
|
All costs to conduct a study to determine whether underground vaults are connected to the stormwater retention basin, to understand stormwater permitting requirements, and to address any deficiencies identified
|
Phoenix
|
According to the information provided, the on-site sewer may require cleaning due to blockage from calcium carbonate buildup and potentially need to be repaired or replaced. Previous estimates to replace the sewer line were approximately $250,000.
|
All costs to evaluate condition of underground sewer and to repair or replace, if required at the boiler area.
|
Phoenix
|
The site has installed a covered storage area for hazardous materials. The storage area is still in the process of being fully permitted and a sprinkler system is required by the local fire marshal. The site is actively using the storage area for hazardous materials storage.
|
All costs to install sprinkler system in the new storage building if required by building permit, local fire standards, or Andeavor hazardous materials storage management practices
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Bakersfield Terminal
|
Some tanks share a common stair to access the roofs with no walkways, guardrails, or tie-off points for fall protection to access vent hoods, gage hatches, etc. In particular, operators must access tanks 17-20 gauge hatches on a daily basis. Access to the gauge hatches requires operators to leave the rooftop walkway system and work near tank edges with no guardrails or fall protection present.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns from stair access and tops of tanks.
|
Bakersfield Terminal
|
High level alarms for storage tanks do not exist. Tank gauging equipment and infrastructure are in place.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Bakersfield Terminal
|
Heat exchanger for asphalt product is not functioning properly and needs to be evaluated.
|
All costs to conduct an engineering study to determine if heat exchanger is operating per design and to address recommended upgrades if any are required
|
Bakersfield Terminal
|
Steam piping at rail rack shows signs of movement from thermal expansion. Additional shoes have been added to avoid pipe from dropping off support. Expansion loops should be considered in steam piping.
|
All costs to review piping at the rail rack to ensure there are adequate supports to prevent the piping from falling off the rack and to address deficiencies identified
|
Bakersfield Terminal
|
Active below ground lines are present in facility (rail offload rack). No existing cathodic protection systems in place or inspection programs.
|
All costs to conduct a Cathodic Protection survey and to make recommended repairs to address deficiencies as per Andeavor standards
|
Bakersfield Terminal
|
The retractable landing at emulsion rack 1 is heavily damaged with broken/bent rails. The landing is currently being used for accessing tops of trucks.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns at emulsion tank 1.
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Bakersfield Terminal
|
The retractable landings at lanes 1, 4 & 5 include a scaffold system for personnel fall protection tie-off. The scaffold system does not appear to be adequately sized to support minimum OSHA load requirements, and is not inspected on a frequent basis by certified scaffold inspectors.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns at truck rack lanes
|
Bakersfield Terminal
|
No fall protection is present for personnel accessing the tops of rail cars.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns from tops of rail cars.
|
Bakersfield Terminal
|
The vapor recovery and control system is inadequate to recover emissions from the asphalt tanks to prevent nuisance odor complaints from the community. Some tanks are not piped to the vapor recovery system.
|
All costs to conduct an engineering review of the vapor recovery piping and thermal oxidizer to ensure adequacy to capture all emissions from the tanks and to make any repairs needed
|
Bakersfield Terminal
|
No arc-flash studies have been conducted and the electrical distribution equipment is not equipped with arc-flash warning labels.
|
All costs for installation of required Arc Flash labels and other recommendations per Andeavor standards, discovered through initial evaluation
|
Bakersfield Terminal
|
Electrical drawings (One-Lines, Area Plans) and documentation are not available for the terminal. Limited project specific documents may be available.
|
All costs to determine if appropriate P&ID's, plot plans, isometric and electrical one-line drawings and maintenance records are in place, as well as to prepare any required documents.
|
Bakersfield Terminal
|
No automated fire or gas detection systems were observed, however this is typical for this type of facility.
|
All costs related to performing an evaluation to determine if additional fire or gas detection is needed and for addressing any identified deficiencies in compliance with NFPA codes and Andeavor fire safety standards
|
Bakersfield Terminal
|
A SCADA control system does not exist for the terminal.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Bakersfield Terminal
|
Tanks are not equipped with any remote monitoring, alarms, or interlocks to prevent tank overfill.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Bakersfield Terminal
|
Only one emulsion tank is equipped with a visual gauge. The asphalt tanks are only equipped with SAAB radar and no site gauges are available for comparison.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
Bakersfield Terminal
|
Cathodic protection systems do not exist to protect select aboveground storage tank bottoms and buried facility piping in direct soil contact.
|
All costs to conduct a Cathodic Protection survey and to make recommended repairs to address deficiencies as per Andeavor standards
|
Bakersfield Terminal
|
The guardrail of the stairs accessing the south side of truck loading lanes 4 & 5 is broken, presenting a fall hazard. In addition, no midrail is present at the stair and kick plate are missing.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns on lanes 4 & 5 guardrails, midrails and stairways.
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
All Sites
|
Inadequate fall protection at the truck loading racks as well as other areas within the sites. It should be noted that the Fernley truck rack is equipped with cages.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns per Andeavor standards
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
All Sites
|
The sites lack a comprehensive fire safety program. Fire safety issues identified included:
• No fire detection systems are in place and facility personnel rely on fire extinguishers for fire protection. • No active or adequate fire suppression systems are in place. • No response agreements are in place with local fire departments, nor do the facilities actively engage, or exercise, with emergency responders. • With the exception of Phoenix, fire hydrants fed by municipal water are not inspected on a regular basis. The facility representative indicated that inspections are conducted, but that documentation is not maintained regarding the inspections. • Hazardous area classification assessments have not been conducted at the sites and numerous ignition sources are present. • Manual call points installed on-sites are disabled and not functioning. Therefore the call points will not activate any general alarm in the event of an emergency. No provisions have been implemented to fix the system. |
All costs related to performing an evaluation to determine if additional fire or gas detection is needed and for addressing any identified deficiencies in compliance with NFPA codes and Andeavor fire safety standards
|
All Sites
|
With limited exceptions, operations are performed manually, with no automation (e.g. MOVs, high level alarms, automated shut down devices, etc.).
Overfill prevention is based on correct calculation of loading time based on the level before loading. The operator is required to perform level monitoring with manual gauges on top while loading is performed. Numerous tanks showed evidence of previous overfill events. |
All costs to conduct a study to evaluate need for SCADA or similar controls and to implement findings as per Andeavor standards
|
All Sites
|
No arc flash studies have been performed at the sites.
|
All costs for installation of required Arc Flash labels and other recommendations per Andeavor standards, discovered through initial evaluation
|
All Sites
|
According to information provided, over 90 tanks are past tank inspection due dates. With few exceptions, all tanks are single bottomed without means of detecting a tank bottom failure.
|
All costs to address overdue tank inspections as per API 653 and to address any deficiencies identified
|
All Sites
|
With the exception of Mojave, the following issues have been identified with respect to secondary containment with the exception of Mojave:
-capacity of secondary containment areas appears inadequate at many locations -tanks were observed without secondary containment -secondary berms are eroding and do not have preventative maintenance programs -spill pans are not used during rail car unloading |
All costs to conduct a review of SPCC plans and to address any deficiencies identified which are required to comply with SPCC requirements
|
All Sites
|
Boiler blow down at the sites is discharged to the ground or an impoundment. The sites are unaware of permitting requirements for this activity. Additionally, boiler blow down discharge on bare ground could lead to subsurface contamination.
|
All costs to review boiler blowdown permitting requirements, to obtain permits required to discharge boiler blowdown water to the stormwater pond if required, or to make other modifications needed for safe, compliant blowdown practices
|
Site
|
3
rd
Party Contractor Identified Risk
|
Andeavor Reimbursements
|
Fernley Terminal
|
A SCADA system is available for the storage tanks, but it is only visible from the local HMI located on the PLC at the terminal and not in the main office.
|
All costs to conduct a study to evaluate need for SCADA or similar controls on storage tanks and to implement findings as per Andeavor standards
|
Fernley Terminal
|
Tanks are not equipped with any remote monitoring, alarms, or interlocks to prevent tank overfill. Tank levels are displayed locally on a PLC HMI, but only text appears when a tank level is high. No shutdowns or audible alarms are in place.
|
All costs to conduct a study to evaluate need for SCADA or similar controls and for installation of remote monitoring or SCADA control systems, as needed.
|
Fernley Terminal
|
Cathodic protection systems do not exist to protect select aboveground storage tank bottoms and buried facility piping in direct soil contact.
|
All costs to conduct a Cathodic Protection survey and to make recommended repairs to address deficiencies as per Andeavor standards
|
Fernley Terminal
|
The stair styles and landings at the rail loading rack do not have guardrail on all sides. Landings are greater than 30" above adjacent grade and require rails for personnel fall protection.
|
All costs to implement interim mitigations to reduce the risk to personnel and undertake projects to address fall protection concerns at the rail loading rack.
|
Fernley
|
The facility does not have a general alarm system to warn personnel on an incident. The emergency response plan indicates that the facility has a general alarm, but this is not accurate based on a review of the site.
|
All costs for review of Emergency Response Plan and for any modifications needed to comply with Andeavor standards and requirements of Emergency Response Plan including installation of emergency alarm systems
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement, dated as April 26, 2011, among the Partnership, the General Partner, the Operating Company, Andeavor, Tesoro Alaska, TRMC and Tesoro High Plains Pipeline Company LLC
|
April 26, 2011
|
April 26, 2013
|
April 26, 2016
|
TRMC and Tesoro Alaska
|
TRMC
|
April 26, 2021
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement dated as of April 1, 2012, among the Partnership, the General Partner, the Operating Company, Tesoro and TRMC
|
April 1, 2012
|
April 1, 2014
|
April 1, 2017
|
TRMC
|
TRMC
|
April 1, 2022
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement executed as of September 14, 2012, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC
|
Execution Date is September 14, 2012, and various Effective Times are upon receipt of the Long Beach Approval, the CDFG Approval and the Other Approvals as set forth in the agreement, as applicable
|
September 14, 2014
|
September 14, 2017
|
TRMC
|
TRMC
|
September 14, 2022
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement executed as of November 15, 2012, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC
|
November 15, 2012
|
November 15, 2014
|
November 15, 2017
|
TRMC
|
TRMC
|
November 15, 2022
|
No
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement executed as of May 17, 2013, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC
|
June 1, 2013
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
No
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement executed as of November 18, 2013, among the Partnership, the General Partner, the Operating Company, Andeavor, TRMC and Carson Cogeneration Company
|
December 6, 2013
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
Not Applicable
|
No
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement executed as of June 23, 2014, among the Partnership, the General Partner, the Operating Company, Tesoro Logistics Pipelines LLC, Andeavor, TRMC and Tesoro Alaska
|
First Closing Date: July 1, 2014
Second Closing Date has the meaning set forth in the Contribution Agreement
|
The second (2
nd
) anniversary of the First Closing Date or the Second Closing Date, as applicable
|
With respect to Section 3.1(a): Not applicable
With respect to Section 3.2: The fifth (5
th
) anniversary of the First Closing Date or the Second Closing Date, as applicable
|
Andeavor, TRMC, Tesoro Alaska
|
Andeavor, TRMC, Tesoro Alaska
|
The tenth (10
th
) anniversary of the First Closing Date or the Second Closing Date, as applicable.
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of November 12, 2015, among the Partnership, the General Partner, the Operating Company, Tesoro SoCal Pipeline Company LLC, Andeavor, TRMC and Carson Cogeneration Company
|
November 12, 2015
|
November 12, 2017
|
November 12, 2020
|
Andeavor, TRMC, Carson Cogen
|
Andeavor, TRMC, Carson Cogen
|
November 12, 2025
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of July 1, 2016, among the Partnership, the General Partner, the Operating Company, Tesoro Alaska Company LLC, and Andeavor
KENAI TANKAGE
|
July 1, 2016
|
July 1, 2018
|
July 1, 2021
|
Tesoro Alaska Company LLC
|
Not applicable
|
July 1, 2026
|
Yes
|
Contribution, Conveyance and Assumption Agreement effective as of July 1, 2016, among the Partnership, the General Partner, the Operating Company, Tesoro Alaska Company LLC, and Andeavor
ANCHORAGE AND FAIRBANKS TERMINALS
|
September 16, 2016
|
September 16, 2018
|
September 16, 2023
|
Tesoro Alaska Company LLC
|
Not applicable
|
September 16, 2026
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of November 21, 2016, among the Partnership, the General Partner, the Operating Company, TRMC and Andeavor
|
November 21, 2016
|
November 21, 2018
|
November 21, 2021
|
TRMC
|
Not applicable
|
November 21, 2026
|
Yes
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of November 8, 2017, among the Partnership, the Operating Company, TRMC and Andeavor
|
November 8, 2017
|
November 8, 2019
|
November 8, 2022
|
TRMC
|
Not applicable
|
November 8, 2027
|
Yes
|
Refinery storage, rail, truck, Legacy Western Permian/4-Corners, Clearbrook tankage, Great Plains/BakkenLink
|
|||||||
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of August 6, 2018 (the “2018 Assets Contribution Agreement”), among the Partnership, the Operating Company, TRMC, Western Refining Southwest, Inc. (“WRSW”), Andeavor and the other parties thereto, insofar as it covers the Group B Assets [Bobcat Pipeline, Benny Pipeline, Mesquite Truck Station, Yucca Truck Station, Mason East Station, Wink Station], Group C [Wingate Terminal], Group D Assets [Clearbrook Tankage], Group E [assets associated with Mandan Refinery, Salt Lake Refinery, LARC Refinery Unit and LARW Refinery Unit], and TGPM Units (as such terms are defined in the 2018 Assets Contribution Agreement)
|
August 6, 2018
|
August 6, 2020
|
August 6, 2023
|
TRMC
WRSW Western Refining Company, L.P. (“WRCLP”) |
Not applicable
|
August 6, 2028
|
Yes
|
Aranco Pipeline, Jal NGL Storage Facility
|
|
|
|
|
|
|
|
Contribution Agreement
|
Closing Date
|
First Deadline Date
|
Second Deadline Date
|
Andeavor Indemnifying Parties
|
Andeavor Indemnified Parties
|
Third Deadline Date
|
Omnibus Section 5.1(b) Applies
|
Contribution, Conveyance and Assumption Agreement effective as of August 6, 2018, among the Partnership, the Operating Company, TRMC, WRSW, Andeavor and the other parties thereto, insofar as it covers the Group A Assets [Jal NGL Storage Facility] and the Group G Assets [Aranco Pipeline]
|
August 6, 2018
|
Not applicable
|
Not applicable
|
Not applicable
|
Not applicable
|
August 6, 2028
|
No
|
1.
|
Amendments to the Original Agreement
.
Schedule B
(Dedicated Tanks) shall be amended and restated in its entirety as set forth in
Schedule B
attached hereto.
|
2.
|
Miscellaneous.
|
Customer:
Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Tesoro Logistics Operations LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Tesoro Logistics Operations LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Tesoro Logistics Operations LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Tesoro Great Plains Gathering & Marketing LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
Western Refining Southwest, Inc.
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Western Refining Terminals, LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
Western Refining Company, L.P., by Western Refining GP, LLC, its general partner
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Western Refining Terminals, LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Customer:
St. Paul Park Refining Co. LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
|
Provider:
Tesoro Logistics Operations LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
|
Terminal
|
Associated Refinery
|
Customer
|
Provider
|
Mandan
|
Mandan Refinery
|
Tesoro Refining & Marketing Company LLC
|
Tesoro Logistics Operations LLC
|
Salt Lake City
|
Salt Lake City Refinery
|
Tesoro Refining & Marketing Company LLC
|
Tesoro Logistics Operations LLC
|
LAR – Carson
|
Los Angeles Refinery (Carson)
|
Tesoro Refining & Marketing Company LLC
|
Tesoro Logistics Operations LLC
|
LAR – Wilmington
|
Los Angeles Refinery (Wilmington)
|
Tesoro Refining & Marketing Company LLC
|
Tesoro Logistics Operations LLC
|
Fryburg
|
N/A
|
Tesoro Refining & Marketing Company LLC
|
Tesoro Great Plains Gathering & Marketing LLC
|
Wingate
|
N/A
|
Western Refining Southwest, Inc.
|
Western Refining Terminals, LLC
|
JAL NGL
|
N/A
|
Western Refining Company, L.P.;
Tesoro Refining & Marketing Company LLC
|
Western Refining Terminals, LLC
|
Clearbrook
|
N/A
|
St. Paul Park Refining Co. LLC
|
Tesoro Logistics Operations LLC
|
LOCATION
|
TANK NUMBER
|
RESERVED CAPACITY (in Barrels)
|
Mandan
|
FB-701
|
96,000
|
Mandan
|
FB-702
|
96,000
|
Mandan
|
FB-703
|
96,000
|
Mandan
|
FB-705
|
96,000
|
Mandan
|
FB-706
|
96,000
|
Mandan
|
FB-707
|
32,900
|
Mandan
|
FB-708
|
30,000
|
Mandan
|
FB-709
|
30,000
|
Mandan
|
FB-710
|
30,000
|
Mandan
|
FB-711
|
30,000
|
Mandan
|
FB-712
|
30,000
|
Mandan
|
FB-714
|
30,000
|
Mandan
|
FB-715
|
20,000
|
Mandan
|
FB-716
|
15,000
|
Mandan
|
FB-717
|
43,000
|
Mandan
|
FB-718
|
30,000
|
Mandan
|
FB-719
|
30,000
|
Mandan
|
FB-720
|
30,000 (OOS)*
|
Mandan
|
FB-721
|
10,000
|
Mandan
|
FB-722
|
10,000
|
Mandan
|
FB-723
|
96,000
|
Mandan
|
FB-724
|
96,000 (OOS)**
|
Mandan
|
FB-725
|
96,000
|
Mandan
|
FB-726
|
96,000
|
Mandan
|
FB-727
|
96,000
|
Mandan
|
FB-728
|
96,000
|
Mandan
|
FB-729
|
96,000
|
Mandan
|
FB-730
|
96,000
|
Mandan
|
FB-731
|
96,000
|
Mandan
|
FB-732
|
30,000
|
Mandan
|
FB-733
|
96,000
|
Mandan
|
FB-734
|
96,000
|
Mandan
|
FB-737
|
20,000 (OOS)
|
Mandan
|
FB-738
|
43,000
|
Mandan
|
FB-740
|
20,000
|
Mandan
|
FB-741
|
15,000
|
Mandan
|
FB-742
|
30,000 (OOS)
|
Mandan
|
FB-743
|
20,000
|
Mandan
|
FB-744
|
24,000
|
Mandan
|
FB-745
|
20,000
|
Mandan
|
FB-746
|
700
|
Mandan
|
FB-747
|
96,000
|
Mandan
|
FB-748
|
96,000
|
Mandan
|
FB-749
|
300 (OOS)
|
Mandan
|
FB-750
|
96,000
|
Mandan
|
FB-751
|
96,000
|
Mandan
|
FB-752
|
96,000
|
Mandan
|
FB-753
|
96,000
|
Mandan
|
FB-754
|
96,000
|
Mandan
|
FB-755
|
96,000
|
Mandan
|
FB-756
|
24,000
|
Mandan
|
FB-758
|
5,000
|
Mandan
|
FB-764
|
96,000
|
Mandan
|
FB-766
|
22,000
|
Mandan
|
FB-767
|
8,000
|
Mandan
|
FB-768
|
1,000 (OOS)
|
Mandan
|
FB-771
|
96,000
|
Mandan
|
FB-773
|
12
|
Mandan
|
FB-774
|
21
|
|
|
|
Salt Lake City
|
141
|
14,896
|
Salt Lake City
|
142
|
14,323
|
|
|
|
Salt Lake City
|
155
|
10,313
|
Salt Lake City
|
157
|
19,915
|
Salt Lake City
|
158
|
19,915
|
Salt Lake City
|
186
|
58,748
|
Salt Lake City
|
188
|
58,748
|
Salt Lake City
|
190
|
48,348
|
Salt Lake City
|
204
|
55,094
|
Salt Lake City
|
206
|
62,091
|
Salt Lake City
|
209
|
(OOS)
|
Salt Lake City
|
212
|
56,627
|
Salt Lake City
|
213
|
56,627
|
Salt Lake City
|
236
|
56,627
|
Salt Lake City
|
242
|
55,688
|
Salt Lake City
|
243
|
55,209
|
Salt Lake City
|
244
|
15,484
|
Salt Lake City
|
245
|
24,071
|
Salt Lake City
|
246
|
11,190
|
Salt Lake City
|
247
|
11,190
|
Salt Lake City
|
248
|
60,000***
|
Salt Lake City
|
252
|
55,688
|
|
|
|
Salt Lake City
|
291
|
15,107
|
Salt Lake City
|
294
|
(OOS)
|
Salt Lake City
|
297
|
3,275
|
Salt Lake City
|
298
|
3,575
|
Salt Lake City
|
305
|
5,117
|
Salt Lake City
|
306
|
5,117
|
Salt Lake City
|
307
|
6,714
|
Salt Lake City
|
308
|
6,714
|
Salt Lake City
|
309
|
(OOS)
|
Salt Lake City
|
310
|
(OOS)
|
Salt Lake City
|
312
|
(OOS)
|
Salt Lake City
|
314
|
(OOS)
|
Salt Lake City
|
315
|
(OOS)
|
Salt Lake City
|
321
|
24,171
|
Salt Lake City
|
322
|
37,871
|
Salt Lake City
|
323
|
37,871
|
Salt Lake City
|
324
|
54,974
|
Salt Lake City
|
325
|
54,974
|
Salt Lake City
|
326
|
54,974
|
Salt Lake City
|
327
|
54,974
|
Salt Lake City
|
328
|
54,974
|
Salt Lake City
|
329
|
10,313
|
Salt Lake City
|
330
|
24,071
|
Salt Lake City
|
331
|
33,105
|
Salt Lake City
|
848
|
2,800
|
Salt Lake City
|
849
|
2,800
|
Salt Lake City
|
427A
|
606
|
Salt Lake City
|
427B
|
606
|
Salt Lake City
|
427C
|
905
|
Salt Lake City
|
427D
|
905
|
LAR - Carson
|
14
|
358,162
|
LAR - Carson
|
16
|
96,247
|
LAR - Carson
|
17
|
95,649
|
LAR - Carson
|
31
|
82,396
|
LAR - Carson
|
61
|
100,965
|
LAR - Carson
|
62
|
100,312
|
LAR - Carson
|
63
|
100,600
|
LAR - Carson
|
64
|
100,220
|
LAR - Carson
|
73
|
30,570
|
LAR - Carson
|
74
|
15,021
|
LAR - Carson
|
75
|
14,972
|
LAR - Carson
|
76
|
30,570
|
LAR - Carson
|
78
|
10,239
|
LAR - Carson
|
959
|
163,366
|
LAR - Carson
|
350
|
1,770
|
LAR - Carson
|
351
|
1,770
|
LAR - Carson
|
352
|
1,770
|
LAR - Carson
|
353
|
1,770
|
LAR - Carson
|
354
|
1,770
|
LAR - Carson
|
355
|
1,770
|
LAR - Carson
|
398
|
6,910
|
LAR - Carson
|
399
|
6,910
|
LAR - Carson
|
677
|
16,671 (OOS)
|
LAR - Carson
|
678
|
16,690 (OOS)
|
LAR - Carson
|
679
|
16,307 (OOS)
|
LAR - Carson
|
680
|
16,279 (OOS)
|
LAR - Carson
|
681
|
30,000
|
LAR - Carson
|
682
|
30,000
|
LAR - Carson
|
683
|
30,000
|
LAR - Carson
|
684
|
30,000
|
LAR - Carson
|
773
|
97,844
|
LAR - Wilmington
|
476
|
400
|
LAR - Wilmington
|
776
|
700
|
LAR - Wilmington
|
777
|
700
|
LAR - Wilmington
|
778
|
700
|
LAR - Wilmington
|
779
|
700
|
LAR - Wilmington
|
780
|
700
|
LAR - Wilmington
|
1501
|
985
|
LAR - Wilmington
|
1502
|
985
|
LAR - Wilmington
|
1503
|
985
|
LAR - Wilmington
|
6000
|
6,000
|
LAR - Wilmington
|
6001
|
6,000
|
LAR - Wilmington
|
7201
|
7,156
|
LAR - Wilmington
|
7501
|
8,395
|
LAR - Wilmington
|
11000
|
11,567 (OOS)
|
LAR - Wilmington
|
11001
|
11,567 (OOS)
|
LAR - Wilmington
|
11002
|
11,567 (OOS)
|
LAR - Wilmington
|
11003
|
11,567 (OOS)
|
LAR - Wilmington
|
11004
|
11,567 (OOS)
|
LAR - Wilmington
|
13500
|
13,818 (OOS)
|
LAR - Wilmington
|
13501
|
13,818 (OOS)
|
LAR - Wilmington
|
13502
|
13,818
|
LAR - Wilmington
|
13503
|
13,818
|
LAR - Wilmington
|
13504
|
13,818
|
LAR - Wilmington
|
13505
|
13,818
|
LAR - Wilmington
|
13506
|
13,818
|
LAR - Wilmington
|
13507
|
13,818 (OOS)
|
LAR - Wilmington
|
13508
|
13,818
|
LAR - Wilmington
|
13509
|
13,818 (OOS)
|
LAR - Wilmington
|
13510
|
13,818
|
LAR - Wilmington
|
13511
|
13,818
|
LAR - Wilmington
|
13512
|
13,818 (OOS)
|
LAR - Wilmington
|
20426
|
20,144
|
LAR - Wilmington
|
36001
|
36,612
|
LAR - Wilmington
|
36002
|
36,612
|
LAR - Wilmington
|
50000
|
50,000
|
LAR - Wilmington
|
76000
|
76,158
|
LAR - Wilmington
|
80033
|
81,383
|
LAR - Wilmington
|
80034
|
81,383
|
LAR - Wilmington
|
80035
|
81,383
|
LAR - Wilmington
|
80036
|
81,383
|
LAR - Wilmington
|
80037
|
81,383
|
LAR - Wilmington
|
80038
|
81,383
|
LAR - Wilmington
|
80039
|
81,383
|
LAR - Wilmington
|
80042
|
81,383
|
LAR - Wilmington
|
80044
|
81,383
|
LAR - Wilmington
|
80045
|
81,383
|
LAR - Wilmington
|
80049
|
81,383
|
LAR - Wilmington
|
80050
|
81,383
|
LAR - Wilmington
|
80051
|
81,383
|
LAR - Wilmington
|
80055
|
81,383
|
LAR - Wilmington
|
80057
|
82,340
|
LAR - Wilmington
|
80058
|
81,383
|
LAR - Wilmington
|
80061
|
81,383
|
LAR - Wilmington
|
80062
|
81,383
|
LAR - Wilmington
|
80063
|
81,383
|
LAR - Wilmington
|
80064
|
81,383
|
LAR - Wilmington
|
80065
|
81,383
|
LAR - Wilmington
|
80066
|
81,383
|
LAR - Wilmington
|
80067
|
81,383
|
LAR - Wilmington
|
80068
|
81,383
|
LAR - Wilmington
|
80069
|
81,383
|
LAR - Wilmington
|
80070
|
81,383
|
LAR - Wilmington
|
80071
|
81,383
|
LAR - Wilmington
|
80072
|
81,383
|
LAR - Wilmington
|
80075
|
78,511
|
LAR - Wilmington
|
80076
|
81,383
|
LAR - Wilmington
|
80077
|
81,383
|
LAR - Wilmington
|
80078
|
81,383
|
LAR - Wilmington
|
80079
|
81,383
|
LAR - Wilmington
|
80080
|
81,383
|
LAR - Wilmington
|
80081
|
81,383
|
LAR - Wilmington
|
80082
|
81,383
|
LAR - Wilmington
|
80083
|
81,383
|
LAR - Wilmington
|
80084
|
81,383
|
LAR - Wilmington
|
80085
|
81,383
|
LAR - Wilmington
|
80087
|
81,383
|
LAR - Wilmington
|
80089
|
81,383
|
LAR - Wilmington
|
80090
|
81,383
|
LAR - Wilmington
|
80091
|
81,383
|
LAR - Wilmington
|
80092
|
81,383
|
LAR - Wilmington
|
80209
|
85,610
|
LAR - Wilmington
|
80210
|
85,610
|
LAR - Wilmington
|
80211
|
85,610
|
LAR - Wilmington
|
80212
|
85,610
|
LAR - Wilmington
|
80213
|
85,610
|
LAR - Wilmington
|
80214
|
85,610
|
LAR - Wilmington
|
80215
|
85,610
|
LAR - Wilmington
|
80216
|
85,610
|
LAR - Wilmington
|
80217
|
85,610
|
LAR - Wilmington
|
80218
|
80,000
|
LAR - Wilmington
|
80219
|
85,610
|
LAR - Wilmington
|
80220
|
85,610
|
LAR - Wilmington
|
80221
|
81,239
|
LAR - Wilmington
|
96000
|
96,689
|
LAR - Wilmington
|
96059
|
96,689
|
LAR - Wilmington
|
118066
|
117,477
|
LAR - Wilmington
|
125000
|
123,278
|
LAR - Wilmington
|
125001
|
123,278
|
LAR - Wilmington
|
125002
|
125,897
|
LAR - Wilmington
|
125003
|
125,897
|
LAR - Wilmington
|
125004
|
125,897
|
Fryburg Terminal
|
Tk-102
|
150,000
|
Fryburg Terminal
|
Tk-103
|
175,000
|
Fryburg Terminal
|
Tk-104
|
175,000
|
Wingate Terminal
|
V-500 - V-505
|
8,004
|
Wingate Terminal
|
V-506 - V-510
|
8,521
|
Wingate Terminal
|
V-516 - V-518
|
5,450
|
Wingate Terminal
|
V-511 - V515
|
12,413
|
Wingate Terminal
|
V-200 - V-207
|
9,941
|
Wingate Terminal
|
V-208
|
1,243
|
Wingate Terminal
|
V-400 - V-407
|
10,652
|
Wingate Terminal
|
V-209 - V-214
|
10,291
|
Wingate Terminal
|
V-215
|
7,676
|
Wingate Terminal
|
V-216
|
10,313
|
Wingate Terminal
|
V-100 - V-101
|
12,390
|
Wingate Terminal
|
V-102 - V-103
|
20,791
|
Wingate Terminal
|
V-104
|
10,313
|
Wingate Terminal
|
V-519
|
95
|
JAL Terminal
|
NA
|
212,000
|
Clearbrook
|
Tk-6014
|
300,000
|
Clearbrook
|
Tk-6015
|
300,000
|
1.
|
Amendments to the Original Agreement
.
Schedule 4.1
(Minimum Asphalt Commitments),
Schedule 4.2
(Dedicated Tanks), and
Schedule 22.2
(Stipulated Commitment) are amended and restated in their entirety as set forth in revised
Schedule 4.1
,
Schedule 4.2
, and
Schedule 22.2
attached hereto, respectively.
|
2.
|
Miscellaneous.
|
Terminal
|
Asphalt Minimum Storage
Commitment (Barrels)
|
Bakersfield, CA
|
123,556
|
Mojave, CA
|
240,000
|
Elk Grove, CA
|
322,433
|
Phoenix, AZ
|
172,050
|
|
|
Description
|
Minimum Asphalt Throughput Commitment (tons/Month)
|
Bakersfield, CA
|
2,833
|
Mojave, CA
|
3,542
|
Elk Grove, CA
|
4,250
|
Phoenix, AZ
|
12,396
|
Tank Number
|
Tank Capacity
|
PMA-1
|
800
|
PMA-2
|
800
|
PMA-3
|
800
|
PMA-4
|
1,900
|
T-1
|
500
|
T-10
|
400
|
T-11
|
520
|
T-1101
|
1,285
|
T-1102
|
1,285
|
T-12
|
520
|
T-14
|
300
|
T-15
|
215
|
T-16
|
260
|
T-17
|
85
|
T-18
|
85
|
T-19
|
85
|
T-2
|
240
|
T-20
|
85
|
T-21
|
120
|
T-22
|
120
|
T-23
|
90
|
T-24
|
650
|
T-25
|
112
|
T-25001
|
24,170
|
T-3
|
4,200
|
T-4
|
550
|
T-5
|
520
|
T-5901
|
5,963
|
T-5902
|
5,963
|
T-5903
|
5,963
|
T-6
|
520
|
T-60001
|
61,250
|
T-601RS
|
600
|
T-602RS
|
600
|
T-603RS
|
600
|
T-7
|
520
|
T-8
|
520
|
T-9
|
360
|
Total
|
184,806
|
Tank Number
|
Tank Capacity
|
142
|
155 (OOS)*
|
180
|
143
|
201
|
200
|
1000
|
45
|
1101
|
1,200
|
1401
|
1,300
|
1402
|
1,300
|
2000
|
143
|
100001
|
100,000
|
100002
|
100,000
|
10001
|
10,000
|
10002
|
10,000
|
10003
|
10,000
|
1B
|
94 (OOS)
|
3001
|
3,000
|
3002
|
3,000
|
50001
|
50,000
|
5001
|
5,000
|
5002
|
5,000
|
5003
|
5,000
|
5004
|
5,000
|
5005
|
5,000
|
501
|
500
|
502
|
500
|
503
|
500
|
504
|
500
|
505
|
500
|
506
|
500
|
507
|
500
|
508
|
500
|
509
|
500
|
5W
|
149
|
761
|
750
|
762
|
750
|
763
|
750
|
PMA Mix Tank
|
60
|
QTS1
|
143
|
Total
|
322,433
|
Tank Number
|
Tank Capacity
|
25
|
786
|
26
|
944
|
27
|
266
|
28
|
266
|
29
|
604
|
30
|
604
|
49
|
403
|
50
|
242
|
60
|
242
|
70
|
242
|
80
|
242
|
1
|
1,678
|
100
|
419
|
10001
|
9,865
|
10002
|
9,865
|
101
|
486
|
102
|
336
|
1501
|
786
|
1502
|
786
|
1503
|
786
|
1504
|
786
|
1505
|
786
|
1506
|
786
|
1507
|
786
|
1515
|
786
|
18
|
507
|
19
|
507
|
20
|
1,449
|
200
|
419
|
201
|
486
|
202
|
288
|
21
|
1,449
|
22
|
1,678
|
23
|
1,933
|
31
|
5,480
|
32
|
5,480
|
33
|
1,212
|
34
|
1,212
|
4
|
486
|
420
|
700
|
440
|
786
|
460
|
786
|
480
|
786
|
5
|
1,118
|
50001
|
50,793
|
50002
|
50,793
|
8
|
272
|
9
|
541
|
A
|
1,699
|
E
|
484
|
E-2
|
725
|
E-3
|
725
|
E-5
|
725
|
E6
|
725
|
G
|
484
|
H
|
484
|
J
|
486
|
K
|
486
|
L
|
483
|
M
|
483
|
PMA mix
|
1,118
|
PPA
|
179 (OOS)
|
Total
|
172,050
|
Tank Number
|
Tank Capacity
|
T-2
|
60,000
|
T-4
|
60,000
|
T-6
|
60,000
|
T-8
|
60,000
|
Total
|
240,000
|
Terminal
|
Asphalt Tankage Reserved Capacity (Barrels)
|
Bakersfield, CA
|
123,556
|
Mojave, CA
|
240,000
|
Elk Grove, CA
|
322,433
|
Phoenix, AZ
|
172,050
|
Terminal
|
Stipulated Asphalt Throughput (tons/Month)
|
Bakersfield, CA
|
2,833
|
Mojave, CA
|
3,542
|
Elk Grove, CA
|
4,250
|
Phoenix, AZ
|
12,396
|
3.
|
SERVICES PROVIDED BY TGP
|
a.
|
At the Receipt Locations, subject to individual Receipt Location capabilities as set forth in
Exhibit B
and available capacity at the Fryburg Rail Terminal, TGP shall receive, by pipeline and/or truck, volumes of Customer's Crude Petroleum properly nominated, tendered and delivered by Customer, or third parties on Customer's behalf, at the Receipt Locations. Volumes delivered by Customer or on Customer's behalf to TGP at any Receipt Locations (other than at the Fryburg Rail Terminal) shall subsequently be delivered by TGP into the custody of BakkenLink, for Customer's sole account, for transportation by the BakkenLink Pipeline System to the Fryburg Rail Terminal.
|
b.
|
TGP shall: (i) receive at the Fryburg Rail Terminal, from the Railway, Rail Cars provided by or at the direction of Customer; (ii) visually inspect the Rail Cars prior to loading, to reasonably determine that hatches, valves, fittings, placards and other safety appurtenances are in proper order, and detain Rail Cars which do not comply with Railway requirements or applicable regulations; (iii) secure each Rail Car for shipment in compliance with federal regulations; (iv) coordinate with the Railway the receipt of Rail Cars to, and the removal of Rail Cars from the Fryburg Rail Terminal; and (v) provide to Customer destination bills of lading, or such other documentation reasonably requested by Customer.
|
c.
|
At the Fryburg Rail Terminal, TGP shall receive Customer's Crude Petroleum from BakkenLink's custody or from properly nominated trucks, and TGP will temporarily store, and then load Customer's Crude Petroleum to Rail Cars.
|
d.
|
TGP will perform the services in a prudent and workmanlike manner consistent
|
4.
|
PIPELINE TARIFFS
|
5.
|
TERMINAL FEES
|
Receipt Locations
|
Fee per Barrel
|
Service
|
Fryburg Rail Terminal
|
$0.50
|
Truck Unload
|
Watford City Terminal
|
$0.15
|
Truck Unload
|
Dunn Terminal
|
$0.15
|
Truck Unload
|
Fryburg Rail Terminal
|
$0.35
|
Unit Train Loading
|
6.
|
INTENTIONALLY OMITTED
|
8.
|
STATEMENTS AND INVOICING
|
9.
|
CRUDE PETROLEUM QUALITY
|
10.
|
MEASUREMENT AND DEDUCTIONS
|
a.
|
For deliveries by Customer to TGP by tanker truck at a Receipt Location, as applicable, the quantities shall be measured by the metering equipment provided by TGP. Custody transfer at Receipt Locations (other than the Fryburg Rail Terminal) for tanker truck deliveries will occur at the inlet flange of TGP's meter. Custody transfer at the Fryburg Rail Terminal for tanker truck deliveries will occur at the inlet flange of TGP's booster pump.
|
b.
|
For deliveries to Customer's Rail Cars across the rail rack, the quantities shall be measured by the metering equipment provided by TGP. Custody transfer from TGP to Customer will occur at the moment the loaded Rail Car is returned to the Railway.
|
c.
|
Measurement and custody transfers applicable to deliveries from pipelines at the Receipt Locations, as applicable, shall be as mutually agreed in writing between the Parties.
|
d.
|
The quantities of Crude Petroleum received and delivered shall be determined in accordance with appropriate American Petroleum Institute (API) standards, latest revision, and adjusted to base (reference or standard) conditions. Corrections will be made for temperature from observed degrees Fahrenheit to sixty (60) degrees Fahrenheit and standard pressure. Deduction will be made for the full
|
e.
|
Crude Petroleum received or delivered shall, in each instance, be evidenced by a ticket showing quantity received or delivered, as the case may be, temperature, sediment and water, and any other data essential to the determination of quality, including all quality measures defined in the Specifications. Unless otherwise agreed, such tickets shall be signed by a representative of the other Party, as appropriate, and shall constitute full receipt of the Crude Petroleum received or delivered.
|
f.
|
Prior to construction of a new metering connection, each Party shall have the right to approve, in its reasonable discretion, of the arrangement and the specific equipment to be used in the metering facilities provided by the other Party. The Parties shall mutually agree as to the specific practices and procedures governing the operation and maintenance of the metering facilities, prior to initial service and on a continuing basis thereafter.
|
g.
|
Each Party shall be afforded the reasonable opportunity to witness the taking of ticket data and the calibration of metering equipment of the other Party.
|
11.
|
FRYBURG RAIL TERMINAL INVENTORY REQUIREMENTS
|
12.
|
NOMINATIONS AND SCHEDULING
|
13.
|
TERMINAL OPERATIONS
|
a.
|
TGP shall have the exclusive right and obligation to control and operate and maintain the Fryburg Rail Terminal, and all portions thereof. Customer's utilization of the terminalling services will at all times be subject to TGP's Fryburg Rail Terminal operating procedures. TGP will be an independent contractor with respect to all services it provides under this Agreement. TGP may suspend operations at the Fryburg Rail Terminal if TGP reasonably believes that any person, equipment or the environment is at imminent risk of injury or damage. In no event will TGP's services hereunder be deemed to be those of a public utility or common carrier.
If
any Governmental Authority declares TGP's services those of a public utility or common carrier, TGP may by notice to Customer terminate this Agreement on the effective date of such action.
|
b.
|
TGP may, in its reasonable determination, take any tanks out of service during the Term in order to perform inspections, routine maintenance, or repairs. If TGP determines that it is necessary or advisable to perform inspections, routine maintenance, or repairs pursuant to this
Section 13
, to the extent practicable, TGP shall give Customer at least thirty (30) Days' written notice of its intention to suspend performance for such purpose and the estimated down time resulting from such suspension and, to the extent practicable, TGP will provide Customer with comparable alternative storage at the Fryburg Rail Terminal, if such is available. Any costs associated with the foregoing shall be borne by TGP; however, in the event that such maintenance or repairs are being performed as a result of Customer's negligence or breach of this Agreement, Customer shall reimburse TGP for the actual out-of-pocket costs incurred from such maintenance and/or repairs.
|
c.
|
At any time during the Term, TGP may determine it is necessary or advisable to clean the Fryburg Rail Terminal for maintenance purposes, to conduct an inspection, to perform cleanup as required by an environmental law, or to address an emergency, and, to the extent practicable, TGP shall give Customer at least thirty (30) Days' written notice of its intention to suspend performance for such purposes and the estimated down time resulting from such suspension and, to the extent practicable, TGP will provide Customer with comparable alternative storage at the Fryburg Rail Terminal, if such is available. Any costs associated with the foregoing shall be borne by TGP; however, in the event that such cleaning is being performed as a result of Customer's negligence or breach of this Agreement, Customer shall reimburse TGP for the actual out-of-pocket costs incurred with such cleaning.
|
d.
|
Notwithstanding anything in this Agreement to the contrary, TGP shall not be responsible for gains or losses of Crude Petroleum caused for any reason other than the negligence or willful misconduct of TGP.
|
14.
|
TAXES
|
15.
|
TITLE TO CRUDE PETROLEUM
|
16.
|
INDEMNITY
|
a.
|
Notwithstanding anything else contained in this Agreement, TGP shall release, defend, protect, indemnify, and hold harmless Customer, and each of its respective Affiliates, officers, directors, shareholders, agents, employees, successors-in-interest, and assignees from and against any and all demands, claims (including third-party claims), losses, costs, suits, or causes of action (including any judgments, losses, liabilities, fines, penalties, expenses, interest, reasonable legal fees, costs of suit, and damages, whether in law or equity and whether in contract, tort or otherwise) for or relating to (i) personal or bodily injury to, or death of the employees of Customer and, as applicable, its carriers, customers, representatives, and agents; (ii) loss of or damage to any property, products, material, or equipment belonging to Customer and, as applicable, its carriers, customers, representatives, and agents, and each of their respective Affiliates, contractors, and subcontractors; (iii) loss of or damage to any other property, products, material, or equipment of any other description, or personal or bodily injury to, or death of any other person or persons; (iv) any liabilities under applicable environmental law resulting from TGP's prior or future operations (including loading and unloading activities) at the Receipt Locations or Fryburg Rail Terminal, except to the extent such liabilities are caused by Customer's failure to comply with this Agreement (including in respect to any tender of Crude Petroleum not meeting the Specifications contained herein); and with respect to clauses (i) through (iii) above, to the extent it is caused by or results from the negligent or otherwise wrongful acts or omissions of TGP in connection with the ownership or operation of the Receipt Locations or Fryburg Rail
|
b.
|
Notwithstanding anything else contained in this Agreement, Customer shall release, defend, protect, indemnify, and hold harmless TGP, and each of its respective Affiliates, officers, directors, shareholders, agents, employees, successors-in-interest, and assignees from and against any and all demands, claims (including third-party claims), losses, costs, suits, or causes of action (including any judgments, losses, liabilities, fines, penalties, expenses, interest, reasonable legal fees, costs of suit, and damages, whether in law or equity and whether in contract, tort or otherwise) for or relating to (i) personal or bodily injury to, or death of the employees of TGP and, as applicable, its carriers, customers, representatives, and agents; (ii) loss of or damage to any property, products, material, or equipment belonging to TGP and, as applicable, its carriers, customers, representatives, and agents, and each of their respective Affiliates, contractors, and subcontractors (except for volume losses); (iii) loss of or damage to any other property, products, material, or equipment of any other description (except for volume losses), or personal or bodily injury to, or death of any other person or persons; and with respect to clauses (i) through (iii) above, to the extent it is caused by or results from the negligent or otherwise wrongful acts or omissions of Customer, in connection with Customer's and its customers' use of the Fryburg Rail Terminal and the services provided hereunder and Customer's Crude Petroleum stored hereunder, and, as applicable, its carriers, customers, contractors, subcontractors, representatives, and agents, or those of their employees with respect to such matters; and (v) any losses incurred by TGP due to violations of this Agreement by Customer, or, as applicable, its customers, carriers, contractors, subcontractors, representatives, and agents; PROVIDED THAT CUSTOMER SHALL NOT BE OBLIGATED TO INDEMNIFY OR HOLD HARMLESS TGP FROM AND AGAINST ANY CLAIMS TO THE EXTENT ANY SUCH CLAIM RESULTS FROM TGP'S BREACH OF THIS AGREEMENT, NEGLIGENCE OR VIOLATION OF APPLICABLE LAW.
|
c.
|
The indemnities expressed in this Agreement will survive the termination of this Agreement.
|
17.
|
LIMITATION OF LIABILITY
|
18.
|
INSURANCE REQUIREMENTS
|
a.
|
At all times during the Term of this Agreement and for a period of two (2) years after termination of this Agreement for any coverage maintained on a "claims-made" or "occurrence" basis, Customer and/or its carrier (if applicable) shall maintain at their expense the below listed insurance in the amounts specified below which are minimum requirements. Customer shall require that carrier cause all of its contractors providing authorized drivers or authorized vehicles, to carry such insurance, and Customer shall be liable to TGP for their failure to do so. Such insurance shall provide coverage to TGP and such policies, other than Worker's Compensation Insurance, shall include TGP as an Additional Insured. Each policy shall provide that it is primary to and not contributory with any other insurance, including any self insured retention, maintained by TGP (which shall be excess) and each policy shall provide the full coverage required by this Agreement. All such insurance shall be written with carriers and underwriters reasonably acceptable to TGP, and eligible to do business in the states where the Terminals are located and having and maintaining an A.M. Best financial strength rating of no less than "A-" and financial size rating no less than "VII", provided that Customer and/or the carrier may procure worker's compensation insurance from the state fund of the state where the Terminal(s) are located. All limits listed below are required MINIMUM LIMITS:
|
(i)
|
Workers Compensation and Occupational Disease Insurance which fully complies with Applicable Law of the state where each Terminal is 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 reasonably required by TGP 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 Customer;
|
(iv)
|
Automobile Liability Insurance covering all owned, non-owned and hired vehicles, with minimum limits of
$1,000,000
combined single limit per
|
(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;
|
(vi)
|
Pollution Legal Liability with limits not less than $25,000,000 per loss with an annual aggregate of $25,000,000. Coverage shall apply to bodily injury and property damage including loss of use of damaged property and property that has not been physically injured; clean-up costs, defense, including costs and expenses incurred in the investigation, defense or settlement of claim; and
|
(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 Customer's owned property; including personal property of others.
|
b.
|
All such policies must be endorsed with a Waiver of Subrogation endorsement, effectively waiving rights of recovery under subrogation or otherwise, against TGP, and shall contain where applicable, a severability of interest clause and a standard cross liability clause.
|
c.
|
Upon execution of this Agreement and prior to the operation of any equipment by Customer, carrier or its authorized drivers at the Receipt Locations, Customer and/or carrier will furnish to TGP, and at least annually thereafter (or at any other times upon request by TGP) during the Term of this Agreement (and for any coverage maintained on a "claims-made" basis, for two (2) years after the termination of this Agreement), insurance certificates and/or certified copies of the original policies to evidence the insurance required herein, including on behalf of carrier's contractors providing authorized vehicles or authorized drivers. Such certificates shall be in the form of the "Accord" Certificate of Insurance, and reflect that they are for the benefit of TGP and shall provide that there will be no material change in or cancellation of the policies unless TGP is given at least thirty (30) days prior written notice. Certificates providing evidence of renewal of coverage shall be furnished to TGP prior to policy expiration.
|
d.
|
Customer and/or carrier shall be solely responsible for any deductibles or self-insured retention.
|
19.
|
DEFAULT
|
21.
|
CONFIDENTIALITY
|
a.
|
Obligations.
Each Party shall use reasonable efforts to retain the other Parties' Confidential Information in confidence and not disclose the same to any third party nor use the same, except as authorized by the disclosing Party in writing or as expressly permitted in this
Section 21
. Each Party further agrees to take the same care with the other Party's Confidential Information as it does with its own, but in no event less than a reasonable degree of care. Excepted from these obligations of confidence and non use is that information which:
|
(i)
|
is available, or becomes available, to the general public without fault of the receiving Party;
|
(ii)
|
was in the possession of the receiving Party on a non-confidential basis prior to receipt of the same from the disclosing Party;
|
(iii)
|
is obtained by the receiving Party without an obligation of confidence from a third party who is rightfully in possession of such information and, to the receiving Party's knowledge, is under no obligation of confidentiality to the disclosing Party; or
|
(iv)
|
is independently developed by the receiving Party without reference to or use of the disclosing Party's Confidential Information.
|
b.
|
Required Disclosure
. Notwithstanding
Section 2 l (a)
above, if the receiving Party becomes legally compelled to disclose the Confidential Information by a court, Governmental Authority or Applicable Law, or is required to disclose by the listing standards of the New York Stock Exchange, any of the disclosing Party's Confidential Information, the receiving Party shall promptly advise the disclosing Party of such requirement to disclose Confidential Information as soon as the receiving Party becomes aware that such a requirement to disclose might become effective, in order that, where possible, the disclosing Party may seek a protective order or such other remedy as the disclosing Party may consider appropriate in the circumstances. The receiving Party shall disclose only that portion of the disclosing Party's Confidential Information that it is required to disclose and shall cooperate with the disclosing Party in allowing the disclosing Party to obtain such protective order or other relief.
|
c.
|
Return of Information
. Upon written request by the disclosing Party, all of the disclosing Party's Confidential Information in whatever form shall be returned to the disclosing Party upon termination of this Agreement or destroyed with destruction certified by the receiving Party, without the receiving Party retaining copies thereof except that one copy of all such Confidential Information may be retained by a Party's legal department solely to the extent that such Party is required to keep a copy of such Confidential Information pursuant to Applicable Law, and the receiving Party shall be entitled to retain any Confidential Information in the electronic form or stored on automatic computer back-up archiving systems during the period such backup or archived materials are retained under such Party's customary procedures and policies; provided, however, that any Confidential Information retained by the receiving Party shall be maintained subject to confidentiality pursuant to the terms of this
Section 21
, and such archived or back-up Confidential Information shall not be accessed except as required by Applicable Law.
|
d.
|
Receiving Party Personnel
. The receiving Party will limit access to the Confidential Information of the disclosing Party to those of its employees, attorneys and contractors that have a need to know such information in order for the receiving Party to exercise or perform its rights and obligations under this Agreement (the
"Receiving Party Personnel”).
The Receiving Party Personnel who have access to any Confidential Information of the disclosing Party will be made aware of the confidentiality provision of this Agreement, and will be required to abide by the terms thereof. Any third-party contractors that are given access to Confidential Information of a disclosing Party pursuant to the terms hereby shall be required to sign a written agreement pursuant to which such Receiving Party Personnel agree to be bound by confidentiality obligations consistent with the provisions of this Agreement.
|
e.
|
Survival
. The obligation of confidentiality under this
Section 21
shall survive the termination of this Agreement for a period of two (2) years.
|
22.
|
FORCE MAJEURE
|
24.
|
NOTICES
|
If to TGP:
|
|
If to Customer:
|
|
|
|
Logistics Contract Administration
|
|
Tesoro Refining & Marketing Company LLC
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19100 Ridgewood Parkway
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19100 Ridgewood Parkway
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San Antonio, Texas 78259
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San Antonio, TX 78259
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E-mail:
logcontractadmin@tsocorp.com
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Fax: 210-579-4517
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For Scheduling Notices:
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For Scheduling Notices:
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Attn: Dan Ruiz
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Attn: Anne Gonzales
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19100 Ridgewood Parkway
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1801 California Street
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San Antonio, Texas 78259
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Suite 1200
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Daniel.Ruiz@tsocorp.com
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Denver, CO 80202
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Banie.A.Gonzales@tsocorp.com
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For legal notices:
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For legal notices:
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Attention: General Counsel
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Attention: Commercial Legal Dept.
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Email:
Commercial-Legal@tsocorp.com
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Fax: 210-745-4649
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With a copy to: logisticslegal@tsocorp. com
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25.
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ASSIGNABILITY
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26.
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GOVERNING LAW
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27.
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COUNTERPARTS
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28.
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WAIVER OF JURY TRIAL
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29.
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SEVERABILITY
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TESORO GREAT PLAINS GATHERING & MARKETING LLC
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TESORO REFINING & MARKETING COMPANY LLC
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By:
/s/ KEITH M. CASEY
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By:
/s/ GREGORY J. GOFF
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Name:
Keith M. Casey
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Name:
Gregory J. Goff
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Title:
Executive Vice President, Marketing & Commercial
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Title:
Chairman, President and Chief Executive
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2.
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Rail Car Orientation.
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3.
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Nominations and Scheduling.
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4.
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Ratability and Priority.
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5.
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Hours of Operation.
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6.
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Compliance.
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7.
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Damaged Rail Cars.
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8.
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Additional Services.
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9.
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Rotating Rail Cars or Locomotives.
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Receipt Locations
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Location
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Connections
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Dry Creek
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McKenzie County, ND
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Pipeline Receipts From Arrow Midstream
Pipeline Deliveries to BakkenLink Pipeline
No Trucking
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Three Forks
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McKenzie County, ND
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Pipeline Receipts From Targa Badlands
Pipeline Deliveries to BakkenLink Pipeline
No Trucking
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Watford City
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McKenzie County, ND
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Pipeline Receipts From Enable Midstream
Pipeline Deliveries to BakkenLink Pipeline
3 TGP Truck Unloading Spots to BakkenLink Pipeline
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Dunn
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McKenzie County, ND
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3 TGP Truck Unloading Spots to BakkenLink Pipeline
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Fryburg
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Billings County, ND
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Pipeline Receipts From BakkenLink Pipeline
3 TGP Truck Unloading Spots to Fryburg Rail Terminal
Unit Train Loading
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1.
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Amendments to the Original Agreement
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Receipt Locations
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Fee per Barrel
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Service
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Fryburg Rail Terminal
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$0.5079
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Truck Unload
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Watford City Terminal
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$0.1524
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Truck Unload
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Dunn Terminal
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$0.1524
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Truck Unload
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Fryburg Rail Terminal
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$0.5000
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Unit Train Loading
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2.
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Miscellaneous.
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Tesoro Refining & Marketing Company LLC
By:
/s/ Gregory J. Goff
Name: Gregory J. Goff
Title: President and Chief Executive Officer
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Tesoro Logistics Operations LLC
By:
/s/ Steven M. Sterin
Name: Steven M. Sterin
Its: President and Chief Financial Officer
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1.
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I have reviewed this
Quarterly
Report on Form
10-Q
of Andeavor Logistics LP;
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2.
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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;
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3.
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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;
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4.
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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:
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(a)
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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;
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(b)
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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;
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(c)
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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
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(d)
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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
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5.
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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):
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(a)
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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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November 7, 2018
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/s/ GARY R. HEMINGER
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Gary R. Heminger
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Chief Executive 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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I have reviewed this
Quarterly
Report on Form
10-Q
of Andeavor Logistics LP;
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2.
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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;
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3.
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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;
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4.
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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:
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(a)
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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;
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(b)
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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;
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(c)
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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
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(d)
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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
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5.
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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):
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(a)
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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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November 7, 2018
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/s/ D. ANDREW WOODWARD
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D. Andrew Woodward
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Principal 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/ GARY R. HEMINGER
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|||
Gary R. Heminger
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Chief Executive Officer of Tesoro Logistics GP, LLC
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(the general partner of Andeavor Logistics LP)
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|||
November 7, 2018
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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/ D. ANDREW WOODWARD
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|||
D. Andrew Woodward
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Principal Financial Officer of Tesoro Logistics GP, LLC
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(the general partner of Andeavor Logistics LP)
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November 7, 2018
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