Attached files
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EX-99.1 - EX-99.1 - WILLIAMS PARTNERS L.P. | wpz_20180630xer.htm |
8-K - 8-K - WILLIAMS PARTNERS L.P. | wpz_20180630x8kxer.htm |
EXHIBIT 99.2
Non-GAAP Reconciliations, | ||
Financial Highlights, and Operating Statistics | ||
(UNAUDITED) | ||
Final | ||
June 30, 2018 | ||
Williams Partners L.P. | ||||||||||||||||||||||||||
Reconciliation of Non-GAAP Measures | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions, except coverage ratios) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Williams Partners L.P. | ||||||||||||||||||||||||||
Reconciliation of "Net Income (Loss)" to "Modified EBITDA", Non-GAAP "Adjusted EBITDA" and "Distributable cash flow" | ||||||||||||||||||||||||||
Net income (loss) | $ | 660 | $ | 348 | $ | 284 | $ | (317 | ) | $ | 975 | $ | 384 | $ | 449 | $ | 833 | |||||||||
Provision (benefit) for income taxes | 3 | 1 | (1 | ) | 3 | 6 | — | — | — | |||||||||||||||||
Interest expense | 214 | 205 | 202 | 201 | 822 | 209 | 211 | 420 | ||||||||||||||||||
Equity (earnings) losses | (107 | ) | (125 | ) | (115 | ) | (87 | ) | (434 | ) | (82 | ) | (92 | ) | (174 | ) | ||||||||||
Other investing (income) loss - net | (271 | ) | (2 | ) | (4 | ) | (4 | ) | (281 | ) | (4 | ) | (67 | ) | (71 | ) | ||||||||||
Proportional Modified EBITDA of equity-method investments | 194 | 215 | 202 | 184 | 795 | 169 | 178 | 347 | ||||||||||||||||||
Depreciation and amortization expenses | 433 | 423 | 424 | 420 | 1,700 | 423 | 426 | 849 | ||||||||||||||||||
Accretion expense associated with asset retirement obligations for nonregulated operations | 6 | 11 | 8 | 8 | 33 | 8 | 10 | 18 | ||||||||||||||||||
Modified EBITDA | 1,132 | 1,076 | 1,000 | 408 | 3,616 | 1,107 | 1,115 | 2,222 | ||||||||||||||||||
Adjustments | ||||||||||||||||||||||||||
Estimated minimum volume commitments | 15 | 15 | 18 | (48 | ) | — | — | — | — | |||||||||||||||||
Severance and related costs | 9 | 4 | 5 | 4 | 22 | — | — | — | ||||||||||||||||||
Settlement charge from pension early payout program | — | — | — | 35 | 35 | — | — | — | ||||||||||||||||||
Regulatory adjustments resulting from Tax Reform | — | — | — | 713 | 713 | 4 | (20 | ) | (16 | ) | ||||||||||||||||
Share of regulatory charges resulting from Tax Reform for equity-method investments | — | — | — | 11 | 11 | 2 | — | 2 | ||||||||||||||||||
ACMP Merger and transition costs | — | 4 | 3 | 4 | 11 | — | — | — | ||||||||||||||||||
Constitution Pipeline project development costs | 2 | 6 | 4 | 4 | 16 | 2 | 1 | 3 | ||||||||||||||||||
Share of impairment at equity-method investment | — | — | 1 | — | 1 | — | — | — | ||||||||||||||||||
Geismar Incident adjustment | (9 | ) | 2 | 8 | (1 | ) | — | — | — | — | ||||||||||||||||
Gain on sale of Geismar Interest | — | — | (1,095 | ) | — | (1,095 | ) | — | — | — | ||||||||||||||||
Impairment of certain assets | — | — | 1,142 | 9 | 1,151 | — | — | — | ||||||||||||||||||
Ad valorem obligation timing adjustment | — | — | 7 | — | 7 | — | — | — | ||||||||||||||||||
Organizational realignment-related costs | 4 | 6 | 6 | 2 | 18 | — | — | — | ||||||||||||||||||
(Gain) loss related to Canada disposition | (3 | ) | (1 | ) | 4 | 4 | 4 | — | — | — | ||||||||||||||||
(Gain) loss on asset retirement | — | — | (5 | ) | 5 | — | — | — | — | |||||||||||||||||
Gains from contract settlements and terminations | (13 | ) | (2 | ) | — | — | (15 | ) | — | — | — | |||||||||||||||
Accrual for loss contingency | 9 | — | — | — | 9 | — | — | — | ||||||||||||||||||
(Gain) loss on early retirement of debt | (30 | ) | — | 3 | — | (27 | ) | 7 | — | 7 | ||||||||||||||||
Gain on sale of RGP Splitter | — | (12 | ) | — | — | (12 | ) | — | — | — | ||||||||||||||||
Expenses associated with Financial Repositioning | — | 2 | — | — | 2 | — | — | — | ||||||||||||||||||
Expenses associated with strategic asset monetizations | 1 | 4 | — | — | 5 | — | — | — | ||||||||||||||||||
WPZ Merger costs | — | — | — | — | — | — | 1 | 1 | ||||||||||||||||||
Total EBITDA adjustments | (15 | ) | 28 | 101 | 742 | 856 | 15 | (18 | ) | (3 | ) | |||||||||||||||
Adjusted EBITDA | 1,117 | 1,104 | 1,101 | 1,150 | 4,472 | 1,122 | 1,097 | 2,219 | ||||||||||||||||||
Maintenance capital expenditures (1) | (53 | ) | (100 | ) | (136 | ) | (154 | ) | (443 | ) | (100 | ) | (152 | ) | (252 | ) | ||||||||||
Interest expense - net (2) | (224 | ) | (216 | ) | (207 | ) | (208 | ) | (855 | ) | (212 | ) | (215 | ) | (427 | ) | ||||||||||
Cash taxes | (5 | ) | (1 | ) | (4 | ) | (2 | ) | (12 | ) | (1 | ) | (1 | ) | (2 | ) | ||||||||||
Income attributable to noncontrolling interests (3) | (27 | ) | (32 | ) | (27 | ) | (27 | ) | (113 | ) | (25 | ) | (24 | ) | (49 | ) | ||||||||||
WPZ restricted stock unit non-cash compensation | 2 | 1 | 1 | 1 | 5 | — | — | — | ||||||||||||||||||
Amortization of deferred revenue associated with certain 2016 contract restructurings (4) | (58 | ) | (58 | ) | (59 | ) | (58 | ) | (233 | ) | — | — | — | |||||||||||||
Distributable cash flow attributable to Partnership Operations | 752 | 698 | 669 | 702 | 2,821 | 784 | 705 | 1,489 | ||||||||||||||||||
Total cash distributed (5) | $ | 567 | $ | 574 | $ | 574 | $ | 574 | $ | 2,289 | $ | 588 | $ | 603 | $ | 1,191 | ||||||||||
Coverage ratios: | ||||||||||||||||||||||||||
Distributable cash flow attributable to partnership operations divided by Total cash distributed | 1.33 | 1.22 | 1.17 | 1.22 | 1.23 | 1.33 | 1.17 | 1.25 | ||||||||||||||||||
Net income (loss) divided by Total cash distributed | 1.16 | 0.61 | 0.49 | (0.55 | ) | 0.43 | 0.65 | 0.74 | 0.70 | |||||||||||||||||
(1) Includes proportionate share of maintenance capital expenditures of equity investments. | ||||||||||||||||||||||||||
(2) Includes proportionate share of interest expense of equity investments. | ||||||||||||||||||||||||||
(3) Excludes allocable share of certain EBITDA adjustments. | ||||||||||||||||||||||||||
(4) Beginning first quarter 2018, as a result of the extended deferred revenue amortization period under the new GAAP revenue standard, we have discontinued the adjustment associated with these 2016 contract restructuring payments. The adjustments would have been $32 million and $31 million for the first and second quarters of 2018, respectively. | ||||||||||||||||||||||||||
(5) Cash distributions for the first quarter of 2017 have been decreased by $6 million to reflect the amount paid by WMB to WPZ pursuant to the January 2017 Common Unit Purchase Agreement. |
Williams Partners L.P. | ||||||||||||||||||||||||||
Reconciliation of “Modified EBITDA” to Non-GAAP “Adjusted EBITDA” | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Modified EBITDA: | ||||||||||||||||||||||||||
Northeast G&P | $ | 226 | $ | 247 | $ | 115 | $ | 231 | $ | 819 | $ | 250 | $ | 255 | $ | 505 | ||||||||||
Atlantic-Gulf | 450 | 454 | 430 | (96 | ) | 1,238 | 451 | 475 | 926 | |||||||||||||||||
West | 385 | 356 | (615 | ) | 286 | 412 | 413 | 389 | 802 | |||||||||||||||||
NGL & Petchem Services | 51 | 30 | 1,084 | (4 | ) | 1,161 | — | — | — | |||||||||||||||||
Other | 20 | (11 | ) | (14 | ) | (9 | ) | (14 | ) | (7 | ) | (4 | ) | (11 | ) | |||||||||||
Total Modified EBITDA | $ | 1,132 | $ | 1,076 | $ | 1,000 | $ | 408 | $ | 3,616 | $ | 1,107 | $ | 1,115 | $ | 2,222 | ||||||||||
Adjustments: | ||||||||||||||||||||||||||
Northeast G&P | ||||||||||||||||||||||||||
Share of impairment at equity-method investments | $ | — | $ | — | $ | 1 | $ | — | $ | 1 | $ | — | $ | — | $ | — | ||||||||||
Impairment of certain assets | — | — | 121 | — | 121 | — | — | — | ||||||||||||||||||
Ad valorem obligation timing adjustment | — | — | 7 | — | 7 | — | — | — | ||||||||||||||||||
Settlement charge from pension early payout program | — | — | — | 7 | 7 | — | — | — | ||||||||||||||||||
Organizational realignment-related costs | 1 | 1 | 2 | — | 4 | — | — | — | ||||||||||||||||||
Total Northeast G&P adjustments | 1 | 1 | 131 | 7 | 140 | — | — | — | ||||||||||||||||||
Atlantic-Gulf | ||||||||||||||||||||||||||
Constitution Pipeline project development costs | 2 | 6 | 4 | 4 | 16 | 2 | 1 | 3 | ||||||||||||||||||
Settlement charge from pension early payout program | — | — | — | 15 | 15 | — | — | — | ||||||||||||||||||
Regulatory adjustments resulting from Tax Reform | — | — | — | 493 | 493 | 11 | (20 | ) | (9 | ) | ||||||||||||||||
Share of regulatory charges resulting from Tax Reform for equity-method investments | — | — | — | 11 | 11 | 2 | — | 2 | ||||||||||||||||||
Organizational realignment-related costs | 1 | 2 | 2 | 1 | 6 | — | — | — | ||||||||||||||||||
(Gain) loss on asset retirement | — | — | (5 | ) | 5 | — | — | — | — | |||||||||||||||||
Total Atlantic-Gulf adjustments | 3 | 8 | 1 | 529 | 541 | 15 | (19 | ) | (4 | ) | ||||||||||||||||
West | ||||||||||||||||||||||||||
Estimated minimum volume commitments | 15 | 15 | 18 | (48 | ) | — | — | — | — | |||||||||||||||||
Impairment of certain assets | — | — | 1,021 | 9 | 1,030 | — | — | — | ||||||||||||||||||
Settlement charge from pension early payout program | — | — | — | 13 | 13 | — | — | — | ||||||||||||||||||
Regulatory adjustments resulting from Tax Reform | — | — | — | 220 | 220 | (7 | ) | — | (7 | ) | ||||||||||||||||
Organizational realignment-related costs | 2 | 3 | 2 | 1 | 8 | — | — | — | ||||||||||||||||||
Gains from contract settlements and terminations | (13 | ) | (2 | ) | — | — | (15 | ) | — | — | — | |||||||||||||||
Total West adjustments | 4 | 16 | 1,041 | 195 | 1,256 | (7 | ) | — | (7 | ) | ||||||||||||||||
NGL & Petchem Services | ||||||||||||||||||||||||||
(Gain) loss related to Canada disposition | (3 | ) | (1 | ) | 4 | 4 | 4 | — | — | — | ||||||||||||||||
Expenses associated with strategic asset monetizations | 1 | 4 | — | — | 5 | — | — | — | ||||||||||||||||||
Geismar Incident adjustments | (9 | ) | 2 | 8 | (1 | ) | — | — | — | — | ||||||||||||||||
Gain on sale of Geismar Interest | — | — | (1,095 | ) | — | (1,095 | ) | — | — | — | ||||||||||||||||
Gain on sale of RGP Splitter | — | (12 | ) | — | — | (12 | ) | — | — | — | ||||||||||||||||
Accrual for loss contingency | 9 | — | — | — | 9 | — | — | — | ||||||||||||||||||
Total NGL & Petchem Services adjustments | (2 | ) | (7 | ) | (1,083 | ) | 3 | (1,089 | ) | — | — | — | ||||||||||||||
Other | ||||||||||||||||||||||||||
Severance and related costs | 9 | 4 | 5 | 4 | 22 | — | — | — | ||||||||||||||||||
ACMP Merger and transition costs | — | 4 | 3 | 4 | 11 | — | — | — | ||||||||||||||||||
Expenses associated with Financial Repositioning | — | 2 | — | — | 2 | — | — | — | ||||||||||||||||||
(Gain) loss on early retirement of debt | (30 | ) | — | 3 | — | (27 | ) | 7 | — | 7 | ||||||||||||||||
WPZ Merger costs | — | — | — | — | — | — | 1 | 1 | ||||||||||||||||||
Total Other adjustments | (21 | ) | 10 | 11 | 8 | 8 | 7 | 1 | 8 | |||||||||||||||||
Total Adjustments | $ | (15 | ) | $ | 28 | $ | 101 | $ | 742 | $ | 856 | $ | 15 | $ | (18 | ) | $ | (3 | ) | |||||||
Adjusted EBITDA: | ||||||||||||||||||||||||||
Northeast G&P | $ | 227 | $ | 248 | $ | 246 | $ | 238 | $ | 959 | $ | 250 | $ | 255 | $ | 505 | ||||||||||
Atlantic-Gulf | 453 | 462 | 431 | 433 | 1,779 | 466 | 456 | 922 | ||||||||||||||||||
West | 389 | 372 | 426 | 481 | 1,668 | 406 | 389 | 795 | ||||||||||||||||||
NGL & Petchem Services | 49 | 23 | 1 | (1 | ) | 72 | — | — | — | |||||||||||||||||
Other | (1 | ) | (1 | ) | (3 | ) | (1 | ) | (6 | ) | — | (3 | ) | (3 | ) | |||||||||||
Total Adjusted EBITDA | $ | 1,117 | $ | 1,104 | $ | 1,101 | $ | 1,150 | $ | 4,472 | $ | 1,122 | $ | 1,097 | $ | 2,219 | ||||||||||
Williams Partners L.P. | ||||||||||||||||||||||||||
Consolidated Statement of Income (Loss) | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions, except per-unit amounts) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Revenues: | ||||||||||||||||||||||||||
Service revenues | $ | 1,256 | $ | 1,277 | $ | 1,304 | $ | 1,455 | $ | 5,292 | $ | 1,346 | $ | 1,335 | $ | 2,681 | ||||||||||
Service revenues - commodity consideration | — | — | — | — | — | 101 | 94 | 195 | ||||||||||||||||||
Product sales | 727 | 642 | 581 | 768 | 2,718 | 636 | 657 | 1,293 | ||||||||||||||||||
Total revenues | 1,983 | 1,919 | 1,885 | 2,223 | 8,010 | 2,083 | 2,086 | 4,169 | ||||||||||||||||||
Costs and expenses: | ||||||||||||||||||||||||||
Product costs | 579 | 537 | 504 | 680 | 2,300 | 613 | 636 | 1,249 | ||||||||||||||||||
Processing commodity expenses | — | — | — | — | — | 35 | 26 | 61 | ||||||||||||||||||
Operating and maintenance expenses | 361 | 384 | 396 | 421 | 1,562 | 351 | 383 | 734 | ||||||||||||||||||
Depreciation and amortization expenses | 433 | 423 | 424 | 420 | 1,700 | 423 | 426 | 849 | ||||||||||||||||||
Selling, general, and administrative expenses | 156 | 154 | 140 | 160 | 610 | 138 | 136 | 274 | ||||||||||||||||||
Impairment of certain assets | 1 | 2 | 1,142 | 11 | 1,156 | — | — | — | ||||||||||||||||||
Gain on sale of Geismar Interest | — | — | (1,095 | ) | — | (1,095 | ) | — | — | — | ||||||||||||||||
Regulatory charges resulting from Tax Reform | — | — | — | 674 | 674 | — | — | — | ||||||||||||||||||
Other (income) expense - net | 3 | 7 | 22 | 38 | 70 | 31 | (1 | ) | 30 | |||||||||||||||||
Total costs and expenses | 1,533 | 1,507 | 1,533 | 2,404 | 6,977 | 1,591 | 1,606 | 3,197 | ||||||||||||||||||
Operating income (loss) | 450 | 412 | 352 | (181 | ) | 1,033 | 492 | 480 | 972 | |||||||||||||||||
Equity earnings (losses) | 107 | 125 | 115 | 87 | 434 | 82 | 92 | 174 | ||||||||||||||||||
Other investing income (loss) - net | 271 | 2 | 4 | 4 | 281 | 4 | 67 | 71 | ||||||||||||||||||
Interest incurred | (221 | ) | (214 | ) | (210 | ) | (210 | ) | (855 | ) | (218 | ) | (224 | ) | (442 | ) | ||||||||||
Interest capitalized | 7 | 9 | 8 | 9 | 33 | 9 | 13 | 22 | ||||||||||||||||||
Other income (expense) - net | 49 | 15 | 14 | (23 | ) | 55 | 15 | 21 | 36 | |||||||||||||||||
Income (loss) before income taxes | 663 | 349 | 283 | (314 | ) | 981 | 384 | 449 | 833 | |||||||||||||||||
Provision (benefit) for income taxes | 3 | 1 | (1 | ) | 3 | 6 | — | — | — | |||||||||||||||||
Net income (loss) | 660 | 348 | 284 | (317 | ) | 975 | 384 | 449 | 833 | |||||||||||||||||
Less: Net income attributable to noncontrolling interests | 26 | 28 | 25 | 25 | 104 | 24 | 23 | 47 | ||||||||||||||||||
Net income (loss) attributable to controlling interests | $ | 634 | $ | 320 | $ | 259 | $ | (342 | ) | $ | 871 | $ | 360 | $ | 426 | $ | 786 | |||||||||
Allocation of net income (loss) for calculation of earnings per common unit: | ||||||||||||||||||||||||||
Net income (loss) attributable to controlling interests | $ | 634 | $ | 320 | $ | 259 | $ | (342 | ) | $ | 871 | $ | 360 | $ | 426 | $ | 786 | |||||||||
Allocation of net income (loss) to Class B units (1) | 11 | 6 | 4 | (6 | ) | 15 | 7 | 8 | 15 | |||||||||||||||||
Allocation of net income (loss) to common units (1) | $ | 623 | $ | 314 | $ | 255 | $ | (336 | ) | $ | 856 | $ | 353 | $ | 418 | $ | 771 | |||||||||
Diluted earnings (loss) per common unit: | ||||||||||||||||||||||||||
Net income (loss) per common unit (1) | $ | 0.68 | $ | 0.33 | $ | 0.27 | $ | (0.35 | ) | $ | 0.90 | $ | 0.37 | $ | 0.44 | $ | 0.81 | |||||||||
Weighted-average number of common units outstanding (thousands) | 920,250 | 955,986 | 956,365 | 956,558 | 947,485 | 957,336 | 957,965 | 957,652 | ||||||||||||||||||
Cash distributions per common unit | $ | 0.600 | $ | 0.600 | $ | 0.600 | $ | 0.600 | $ | 2.400 | $ | 0.614 | $ | 0.629 | $ | 1.243 | ||||||||||
(1) The sum for the quarters may not equal the total for the year due to timing of unit issuances. | ||||||||||||||||||||||||||
Williams Partners L.P. | ||||||||||||||||||||||||||
Northeast G&P | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 (1) | 2018 | |||||||||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Revenues: (1) | ||||||||||||||||||||||||||
Service revenues: | ||||||||||||||||||||||||||
Nonregulated gathering and processing fee-based revenue | $ | 182 | $ | 183 | $ | 182 | $ | 191 | $ | 738 | $ | 189 | $ | 196 | $ | 385 | ||||||||||
Other fee revenues | 35 | 34 | 31 | 33 | 133 | 39 | 36 | 75 | ||||||||||||||||||
Nonregulated commodity consideration | — | — | — | — | — | 4 | 4 | 8 | ||||||||||||||||||
Product sales: | ||||||||||||||||||||||||||
NGL sales from gas processing | 4 | 4 | 2 | 4 | 14 | 4 | 5 | 9 | ||||||||||||||||||
Marketing sales | 64 | 48 | 60 | 106 | 278 | 89 | 65 | 154 | ||||||||||||||||||
Tracked product sales | — | — | — | — | — | 5 | 5 | 10 | ||||||||||||||||||
Total revenues | 285 | 269 | 275 | 334 | 1,163 | 330 | 311 | 641 | ||||||||||||||||||
Segment costs and expenses: (1) | ||||||||||||||||||||||||||
NGL cost of goods sold | 4 | 1 | 2 | 1 | 8 | 4 | 5 | 9 | ||||||||||||||||||
Marketing cost of goods sold | 65 | 48 | 59 | 106 | 278 | 90 | 65 | 155 | ||||||||||||||||||
Processing commodity expenses | — | — | — | — | — | 2 | 2 | 4 | ||||||||||||||||||
Operating and administrative costs | 86 | 88 | 99 | 109 | 382 | 85 | 92 | 177 | ||||||||||||||||||
Other segment costs and expenses | — | 1 | (1 | ) | 4 | 4 | 2 | — | 2 | |||||||||||||||||
Impairment of certain assets | 1 | 1 | 121 | 1 | 124 | — | — | — | ||||||||||||||||||
Tracked cost of goods sold | — | — | — | — | — | 5 | 7 | 12 | ||||||||||||||||||
Total segment costs and expenses | 156 | 139 | 280 | 221 | 796 | 188 | 171 | 359 | ||||||||||||||||||
Proportional Modified EBITDA of equity-method investments | 97 | 117 | 120 | 118 | 452 | 108 | 115 | 223 | ||||||||||||||||||
Modified EBITDA | 226 | 247 | 115 | 231 | 819 | 250 | 255 | 505 | ||||||||||||||||||
Adjustments | 1 | 1 | 131 | 7 | 140 | — | — | — | ||||||||||||||||||
Adjusted EBITDA | $ | 227 | $ | 248 | $ | 246 | $ | 238 | $ | 959 | $ | 250 | $ | 255 | $ | 505 | ||||||||||
NGL margin | $ | — | $ | 3 | $ | — | $ | 3 | $ | 6 | $ | 2 | $ | 2 | $ | 4 | ||||||||||
Statistics for Operated Assets | ||||||||||||||||||||||||||
Gathering and Processing | ||||||||||||||||||||||||||
Gathering volumes (Bcf per day) - Consolidated (2) | 3.32 | 3.28 | 3.28 | 3.37 | 3.31 | 3.38 | 3.44 | 3.41 | ||||||||||||||||||
Gathering volumes (Bcf per day) - Non-consolidated (3) | 3.55 | 3.58 | 3.48 | 3.61 | 3.55 | 3.82 | 3.59 | 3.71 | ||||||||||||||||||
Plant inlet natural gas volumes (Bcf per day) (2) | 0.39 | 0.40 | 0.45 | 0.50 | 0.43 | 0.49 | 0.55 | 0.52 | ||||||||||||||||||
Ethane equity sales (Mbbls/d) | 2 | 2 | 2 | 1 | 2 | 1 | 3 | 2 | ||||||||||||||||||
Non-ethane equity sales (Mbbls/d) | 1 | 1 | 1 | 1 | 1 | 1 | 1 | 1 | ||||||||||||||||||
NGL equity sales (Mbbls/d) | 3 | 3 | 3 | 2 | 3 | 2 | 4 | 3 | ||||||||||||||||||
Ethane production (Mbbls/d) | 17 | 22 | 17 | 22 | 20 | 23 | 27 | 25 | ||||||||||||||||||
Non-ethane production (Mbbls/d) | 15 | 17 | 19 | 22 | 18 | 21 | 21 | 21 | ||||||||||||||||||
NGL production (Mbbls/d) | 32 | 39 | 36 | 44 | 38 | 44 | 48 | 46 | ||||||||||||||||||
(1) Revenues and costs are now reflected net of eliminations. | ||||||||||||||||||||||||||
(2) Includes gathering volumes associated with Susquehanna Supply Hub, Ohio Valley Midstream, and Utica Supply Hub, all of which are consolidated. | ||||||||||||||||||||||||||
(3) Includes 100% of the volumes associated with operated equity-method investments, including the Laurel Mountain Midstream partnership; and the Bradford Supply Hub and a portion of the Marcellus South Supply Hub within the Appalachia Midstream Services partnership. Volumes handled by Blue Racer Midstream (gathering and processing) and UEOM (processing only), which we do not operate, are not included. |
Williams Partners L.P. | ||||||||||||||||||||||||||
Atlantic-Gulf | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Revenues: (1) | ||||||||||||||||||||||||||
Service revenues: | ||||||||||||||||||||||||||
Nonregulated gathering & processing fee-based revenue | $ | 127 | $ | 136 | $ | 133 | $ | 132 | $ | 528 | $ | 138 | $ | 128 | $ | 266 | ||||||||||
Regulated transportation revenue | 354 | 358 | 380 | 408 | 1,500 | 413 | 406 | 819 | ||||||||||||||||||
Other fee revenues | 34 | 34 | 30 | 32 | 130 | 32 | 34 | 66 | ||||||||||||||||||
Tracked service revenue | 21 | 19 | 20 | 19 | 79 | 26 | 22 | 48 | ||||||||||||||||||
Nonregulated commodity consideration | — | — | — | — | — | 15 | 12 | 27 | ||||||||||||||||||
Product sales: | ||||||||||||||||||||||||||
NGL sales from gas processing | 27 | 16 | 13 | 14 | 70 | 15 | 10 | 25 | ||||||||||||||||||
Marketing sales | 90 | 75 | 66 | 81 | 312 | 45 | 57 | 102 | ||||||||||||||||||
Other sales | 4 | 3 | 3 | 2 | 12 | 2 | 2 | 4 | ||||||||||||||||||
Tracked product sales | 13 | 31 | 25 | 23 | 92 | 31 | 36 | 67 | ||||||||||||||||||
Total revenues | 670 | 672 | 670 | 711 | 2,723 | 717 | 707 | 1,424 | ||||||||||||||||||
Segment costs and expenses: (1) | ||||||||||||||||||||||||||
NGL cost of goods sold | 13 | 7 | 5 | 3 | 28 | 15 | 12 | 27 | ||||||||||||||||||
Marketing cost of goods sold | 89 | 73 | 65 | 81 | 308 | 44 | 57 | 101 | ||||||||||||||||||
Other cost of goods sold | 1 | — | — | — | 1 | — | — | — | ||||||||||||||||||
Tracked cost of goods sold | 15 | 33 | 27 | 24 | 99 | 33 | 38 | 71 | ||||||||||||||||||
Processing commodity expenses | — | — | — | — | — | 5 | 2 | 7 | ||||||||||||||||||
Operating and administrative costs | 154 | 166 | 190 | 221 | 731 | 175 | 179 | 354 | ||||||||||||||||||
Other segment costs and expenses | (1 | ) | — | (3 | ) | 14 | 10 | — | (14 | ) | (14 | ) | ||||||||||||||
Regulatory charges resulting from Tax Reform | — | — | — | 493 | 493 | 11 | (20 | ) | (9 | ) | ||||||||||||||||
Tracked operating and administrative costs | 21 | 19 | 20 | 19 | 79 | 26 | 22 | 48 | ||||||||||||||||||
Total segment costs and expenses | 292 | 298 | 304 | 855 | 1,749 | 309 | 276 | 585 | ||||||||||||||||||
Proportional Modified EBITDA of equity-method investments | 72 | 80 | 64 | 48 | 264 | 43 | 44 | 87 | ||||||||||||||||||
Modified EBITDA | 450 | 454 | 430 | (96 | ) | 1,238 | 451 | 475 | 926 | |||||||||||||||||
Adjustments | 3 | 8 | 1 | 529 | 541 | 15 | (19 | ) | (4 | ) | ||||||||||||||||
Adjusted EBITDA | $ | 453 | $ | 462 | $ | 431 | $ | 433 | $ | 1,779 | $ | 466 | $ | 456 | $ | 922 | ||||||||||
NGL Margins | $ | 14 | $ | 9 | $ | 7 | $ | 11 | $ | 41 | $ | 10 | $ | 8 | $ | 18 | ||||||||||
Statistics for Operated Assets | ||||||||||||||||||||||||||
Gathering, Processing and Crude Oil Transportation | ||||||||||||||||||||||||||
Gathering volumes (Bcf per day) - Consolidated (2) | 0.32 | 0.29 | 0.31 | 0.30 | 0.31 | 0.30 | 0.25 | 0.27 | ||||||||||||||||||
Gathering volumes (Bcf per day) - Non-consolidated (3) | 0.55 | 0.54 | 0.39 | 0.28 | 0.44 | 0.24 | 0.25 | 0.25 | ||||||||||||||||||
Plant inlet natural gas volumes (Bcf per day) - Consolidated (2) | 0.56 | 0.57 | 0.52 | 0.54 | 0.55 | 0.54 | 0.43 | 0.49 | ||||||||||||||||||
Plant inlet natural gas volumes (Bcf per day) - Non-consolidated (3) | 0.54 | 0.53 | 0.39 | 0.27 | 0.43 | 0.24 | 0.25 | 0.25 | ||||||||||||||||||
Crude transportation volumes (Mbbls/d) | 131 | 135 | 137 | 136 | 134 | 142 | 132 | 137 | ||||||||||||||||||
Consolidated (2) | ||||||||||||||||||||||||||
Ethane margin ($/gallon) | $ | .02 | $ | .03 | $ | .04 | $ | .09 | $ | .04 | $ | .03 | $ | .16 | $ | .08 | ||||||||||
Non-ethane margin ($/gallon) | $ | .42 | $ | .36 | $ | .53 | $ | .72 | $ | .47 | $ | .66 | $ | .74 | $ | .69 | ||||||||||
NGL margin ($/gallon) | $ | .26 | $ | .23 | $ | .26 | $ | .46 | $ | .28 | $ | .40 | $ | .48 | $ | .43 | ||||||||||
Ethane equity sales (Mbbls/d) | 6 | 4 | 4 | 2 | 4 | 3 | 2 | 2 | ||||||||||||||||||
Non-ethane equity sales (Mbbls/d) | 9 | 6 | 3 | 3 | 5 | 4 | 2 | 3 | ||||||||||||||||||
NGL equity sales (Mbbls/d) | 15 | 10 | 7 | 5 | 9 | 7 | 4 | 5 | ||||||||||||||||||
Ethane production (Mbbls/d) | 14 | 14 | 13 | 14 | 14 | 12 | 12 | 12 | ||||||||||||||||||
Non-ethane production (Mbbls/d) | 20 | 19 | 18 | 19 | 19 | 19 | 17 | 18 | ||||||||||||||||||
NGL production (Mbbls/d) | 34 | 33 | 31 | 33 | 33 | 31 | 29 | 30 | ||||||||||||||||||
Non-consolidated (3) | ||||||||||||||||||||||||||
NGL equity sales (Mbbls/d) | 5 | 4 | 5 | 4 | 5 | 2 | 5 | 4 | ||||||||||||||||||
NGL production (Mbbls/d) | 21 | 22 | 22 | 19 | 21 | 18 | 20 | 19 | ||||||||||||||||||
Transcontinental Gas Pipe Line | ||||||||||||||||||||||||||
Throughput (Tbtu) | 939.1 | 887.6 | 938.5 | 1,017.5 | 3,782.7 | 1,099.9 | 965.5 | 2,065.4 | ||||||||||||||||||
Avg. daily transportation volumes (Tbtu) | 10.4 | 9.8 | 10.2 | 11.1 | 10.4 | 12.2 | 10.6 | 11.4 | ||||||||||||||||||
Avg. daily firm reserved capacity (Tbtu) | 12.8 | 13.2 | 14.1 | 14.9 | 13.8 | 15.4 | 15.0 | 15.2 | ||||||||||||||||||
(1) Revenues and costs are now reflected net of eliminations. | ||||||||||||||||||||||||||
(2) Excludes volumes associated with equity-method investments that are not consolidated in our results. | ||||||||||||||||||||||||||
(3) Includes 100% of the volumes associated with operated equity-method investments. |
Williams Partners L.P. | ||||||||||||||||||||||||||
West | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Revenues: (1) | ||||||||||||||||||||||||||
Service revenues: | ||||||||||||||||||||||||||
Nonregulated gathering & processing fee-based revenue | $ | 363 | $ | 382 | $ | 398 | $ | 502 | $ | 1,645 | $ | 386 | $ | 398 | $ | 784 | ||||||||||
Regulated transportation revenue | 117 | 112 | 113 | 118 | 460 | 109 | 104 | 213 | ||||||||||||||||||
Other fee revenues | 38 | 33 | 33 | 37 | 141 | 36 | 32 | 68 | ||||||||||||||||||
Nonregulated commodity consideration | — | — | — | — | — | 82 | 78 | 160 | ||||||||||||||||||
Tracked service revenues | — | — | — | — | — | — | 1 | 1 | ||||||||||||||||||
Product sales: | ||||||||||||||||||||||||||
NGL sales from gas processing | 64 | 61 | 68 | 82 | 275 | 85 | 76 | 161 | ||||||||||||||||||
Olefin sales | 1 | — | — | — | 1 | — | — | — | ||||||||||||||||||
Marketing sales | 387 | 368 | 408 | 534 | 1,697 | 419 | 465 | 884 | ||||||||||||||||||
Other sales | 4 | 5 | 9 | 20 | 38 | 10 | 9 | 19 | ||||||||||||||||||
Tracked product sales | — | 1 | — | 1 | 2 | 16 | 10 | 26 | ||||||||||||||||||
Total revenues | 974 | 962 | 1,029 | 1,294 | 4,259 | 1,143 | 1,173 | 2,316 | ||||||||||||||||||
Segment costs and expenses: (1) | ||||||||||||||||||||||||||
NGL cost of goods sold | 27 | 31 | 31 | 32 | 121 | 85 | 81 | 166 | ||||||||||||||||||
Marketing cost of goods sold | 386 | 375 | 397 | 527 | 1,685 | 418 | 458 | 876 | ||||||||||||||||||
Other cost of goods sold | 3 | 3 | 9 | 18 | 33 | 7 | 8 | 15 | ||||||||||||||||||
Tracked cost of goods sold | — | — | — | — | — | 16 | 10 | 26 | ||||||||||||||||||
Processing commodity expenses | — | — | — | — | — | 30 | 20 | 50 | ||||||||||||||||||
Operating and administrative costs | 210 | 216 | 204 | 217 | 847 | 194 | 216 | 410 | ||||||||||||||||||
Tracked operating and administrative costs | — | — | 1 | 1 | 2 | — | 1 | 1 | ||||||||||||||||||
Other segment costs and expenses | (12 | ) | (2 | ) | (1 | ) | 1 | (14 | ) | 5 | 9 | 14 | ||||||||||||||
Impairment of certain assets | — | 1 | 1,021 | 10 | 1,032 | — | — | — | ||||||||||||||||||
Regulatory charges resulting from Tax Reform | — | — | — | 220 | 220 | (7 | ) | — | (7 | ) | ||||||||||||||||
Total segment costs and expenses | 614 | 624 | 1,662 | 1,026 | 3,926 | 748 | 803 | 1,551 | ||||||||||||||||||
Proportional Modified EBITDA of equity-method investments | 25 | 18 | 18 | 18 | 79 | 18 | 19 | 37 | ||||||||||||||||||
Modified EBITDA | 385 | 356 | (615 | ) | 286 | 412 | 413 | 389 | 802 | |||||||||||||||||
Adjustments | 4 | 16 | 1,041 | 195 | 1,256 | (7 | ) | — | (7 | ) | ||||||||||||||||
Adjusted EBITDA | $ | 389 | $ | 372 | $ | 426 | $ | 481 | $ | 1,668 | $ | 406 | $ | 389 | $ | 795 | ||||||||||
NGL margin | $ | 37 | $ | 30 | $ | 37 | $ | 50 | $ | 154 | $ | 52 | $ | 53 | $ | 105 | ||||||||||
Statistics for Operated Assets | ||||||||||||||||||||||||||
Gathering and Processing | ||||||||||||||||||||||||||
Gathering volumes (Bcf per day) | 4.23 | 4.40 | 4.62 | 4.86 | 4.53 | 4.58 | 4.60 | 4.59 | ||||||||||||||||||
Plant inlet natural gas volumes (Bcf per day) | 1.99 | 2.01 | 2.11 | 2.17 | 2.07 | 2.16 | 2.12 | 2.14 | ||||||||||||||||||
Ethane equity sales (Mbbls/d) | 3 | 11 | 11 | 12 | 9 | 19 | 10 | 15 | ||||||||||||||||||
Non-ethane equity sales (Mbbls/d) | 20 | 20 | 20 | 21 | 20 | 20 | 19 | 19 | ||||||||||||||||||
NGL equity sales (Mbbls/d) | 23 | 31 | 31 | 33 | 29 | 39 | 29 | 34 | ||||||||||||||||||
Ethane margin ($/gallon) | $ | .04 | $ | .00 | $ | .02 | $ | .02 | $ | .02 | $ | .01 | $ | .07 | $ | .03 | ||||||||||
Non-ethane margin ($/gallon) | $ | .49 | $ | .40 | $ | .45 | $ | .61 | $ | .49 | $ | .69 | $ | .71 | $ | .70 | ||||||||||
NGL margin ($/gallon) | $ | .43 | $ | .26 | $ | .30 | $ | .39 | $ | .34 | $ | .35 | $ | .48 | $ | .41 | ||||||||||
Ethane production (Mbbls/d) | 8 | 18 | 19 | 26 | 18 | 31 | 26 | 28 | ||||||||||||||||||
Non-ethane production (Mbbls/d) | 55 | 57 | 62 | 63 | 59 | 62 | 61 | 61 | ||||||||||||||||||
NGL production (Mbbls/d) | 63 | 75 | 81 | 89 | 77 | 93 | 87 | 89 | ||||||||||||||||||
Northwest Pipeline LLC | ||||||||||||||||||||||||||
Throughput (Tbtu) | 219.0 | 165.4 | 156.4 | 209.1 | 749.9 | 226.1 | 188.1 | 414.2 | ||||||||||||||||||
Avg. daily transportation volumes (Tbtu) | 2.4 | 1.8 | 1.7 | 2.3 | 2.1 | 2.5 | 2.1 | 2.3 | ||||||||||||||||||
Avg. daily firm reserved capacity (Tbtu) | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | ||||||||||||||||||
Overland Pass Pipeline Company LLC (equity investment) - 100% | ||||||||||||||||||||||||||
NGL Transportation volumes (Mbbls) | 18,338 | 20,558 | 21,015 | 21,424 | 81,335 | 21,263 | 21,334 | 42,597 | ||||||||||||||||||
(1) Revenues and costs are now reflected net of eliminations. |
Williams Partners L.P. | ||||||||||||||||||||||||||
Capital Expenditures and Investments | ||||||||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | Year | ||||||||||||||||||
Capital expenditures: | ||||||||||||||||||||||||||
Northeast G&P | $ | 58 | $ | 81 | $ | 173 | $ | 101 | $ | 413 | $ | 114 | $ | 104 | $ | 218 | ||||||||||
Atlantic-Gulf | 388 | 398 | 371 | 508 | 1,665 | 764 | 746 | 1,510 | ||||||||||||||||||
West | 57 | 58 | 94 | 76 | 285 | 69 | 74 | 143 | ||||||||||||||||||
NGL & Petchem Services | 6 | 1 | (1 | ) | — | 6 | — | — | — | |||||||||||||||||
Other | — | 2 | 1 | 2 | 5 | 1 | 1 | 2 | ||||||||||||||||||
Total (1) | $ | 509 | $ | 540 | $ | 638 | $ | 687 | $ | 2,374 | $ | 948 | $ | 925 | $ | 1,873 | ||||||||||
Purchases of investments: | ||||||||||||||||||||||||||
Northeast G&P | $ | 20 | $ | 26 | $ | 24 | $ | 29 | $ | 99 | $ | 20 | $ | 70 | $ | 90 | ||||||||||
Atlantic-Gulf | — | 1 | — | — | 1 | 1 | — | 1 | ||||||||||||||||||
West | 32 | — | — | — | 32 | — | — | — | ||||||||||||||||||
Total | $ | 52 | $ | 27 | $ | 24 | $ | 29 | $ | 132 | $ | 21 | $ | 70 | $ | 91 | ||||||||||
Summary: | ||||||||||||||||||||||||||
Northeast G&P | $ | 78 | $ | 107 | $ | 197 | $ | 130 | $ | 512 | $ | 134 | $ | 174 | $ | 308 | ||||||||||
Atlantic-Gulf | 388 | 399 | 371 | 508 | 1,666 | 765 | 746 | 1,511 | ||||||||||||||||||
West | 89 | 58 | 94 | 76 | 317 | 69 | 74 | 143 | ||||||||||||||||||
NGL & Petchem Services | 6 | 1 | (1 | ) | — | 6 | — | — | — | |||||||||||||||||
Other | — | 2 | 1 | 2 | 5 | 1 | 1 | 2 | ||||||||||||||||||
Total | $ | 561 | $ | 567 | $ | 662 | $ | 716 | $ | 2,506 | $ | 969 | $ | 995 | $ | 1,964 | ||||||||||
Capital expenditures incurred and purchases of investments: | ||||||||||||||||||||||||||
Increases to property, plant, and equipment | $ | 569 | $ | 586 | $ | 660 | $ | 824 | $ | 2,639 | $ | 925 | $ | 922 | $ | 1,847 | ||||||||||
Purchases of investments | 52 | 27 | 24 | 29 | 132 | 21 | 70 | 91 | ||||||||||||||||||
Total | $ | 621 | $ | 613 | $ | 684 | $ | 853 | $ | 2,771 | $ | 946 | $ | 992 | $ | 1,938 | ||||||||||
(1) Increases to property, plant, and equipment | $ | 569 | $ | 586 | $ | 660 | $ | 824 | $ | 2,639 | $ | 925 | $ | 922 | $ | 1,847 | ||||||||||
Changes in related accounts payable and accrued liabilities | (60 | ) | (46 | ) | (22 | ) | (137 | ) | (265 | ) | 23 | 3 | 26 | |||||||||||||
Capital expenditures | $ | 509 | $ | 540 | $ | 638 | $ | 687 | $ | 2,374 | $ | 948 | $ | 925 | $ | 1,873 | ||||||||||
Selected Financial Information | ||||||||||||||||||||
(UNAUDITED) | ||||||||||||||||||||
2017 | 2018 | |||||||||||||||||||
(Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | 1st Qtr | 2nd Qtr | ||||||||||||||
Cash and cash equivalents | $ | 625 | $ | 1,908 | $ | 1,165 | $ | 881 | $ | 1,268 | $ | 255 | ||||||||
Capital structure: | ||||||||||||||||||||
Debt: | ||||||||||||||||||||
Current | $ | — | $ | 1,951 | $ | 502 | $ | 501 | $ | 501 | $ | 2 | ||||||||
Noncurrent | $ | 17,065 | $ | 16,614 | $ | 16,000 | $ | 15,996 | $ | 17,011 | $ | 17,018 | ||||||||