Attached files
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| 8-K - 8-K - WILLIAMS PARTNERS L.P. | d875603d8k.htm |
Exhibit 99.1
| News Release | Williams Partners L.P. (NYSE: WPZ) |
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| One Williams Center | ||||||||
| Tulsa, OK 74172 | ||||||||
| 800-600-3782 | ||||||||
| www.williams.com |
DATE: Feb. 18, 2015
| MEDIA CONTACT: | INVESTOR CONTACTS: | |||
| Tom Droege 918) 573-4034 |
John Porter (918) 573-0797 |
Brett Krieg (918) 573-4614 |
Williams Partners L.P. (Newly Merged Partnership) Reports 2014 Financial
Results for Pre-Merger Williams Partners and Pre-Merger Access
Midstream Partners, Updates Guidance
| • | Pre-Merger Williams Partners Generated 2014 Adjusted Segment Profit + DD&A of $2.6 Billion, Distributable Cash Flow (DCF) of $1.7 Billion |
| • | Pre-Merger Access Midstream Partners Generated 2014 Adjusted EBITDA of $1.2 Billion, Adjusted DCF of $853 Million |
| • | Newly Merged Williams Partners/Access Midstream Partners Creates Leading, Large-Cap Natural Gas Infrastructure-Focused MLP with Robust Growth Outlook and Major Positions in Key Basins |
| • | Updating Guidance to Reflect Sharply Lower Commodity Price Assumptions; 2015 Commodity Margins Lower by 44% (Assumes $55 WTI, $3 Henry Hub Gas) |
| • | Expect Adjusted EBITDA of Approximately $4.5 Billion in 2015, Increasing 34% to Approximately $6 Billion in 2017; 2015 Gross Margin Expected to be 88% Fee-Based |
| • | Expect Williams Partners Per Unit Distribution of $3.40 in 2015 with 7% to 11% Annual LP Unit Distribution Growth Rate through 2017 with Growing Coverage |
TULSA, Okla. – Williams Partners L.P. (NYSE: WPZ) today announced unaudited 2014 financial results for pre-merger Williams Partners L.P. and pre-merger Access Midstream Partners, L.P. The two master limited partnerships (MLP) merged on Feb. 2, 2015, creating a new MLP that adopted the name “Williams Partners” and the NYSE ticker symbol “WPZ.”
Throughout this news release, “Williams Partners” refers to the merged MLP on a go-forward basis while “pre-merger Williams Partners” and “pre-merger Access Midstream Partners” refers to the two MLPs and their separate financial results prior to the merger. The pre-merger Access Midstream Partners’ results do not reflect Williams’ basis of accounting.
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| Summary Financial Information |
Full Year | 4Q | ||||||||||||||
| Amounts in millions, except per-unit and coverage ratio amounts. All income amounts attributable to Williams Partners L.P. and Access Midstream Partners, L.P. |
2014 | 2013 | 2014 | 2013 | ||||||||||||
| (Unaudited) | ||||||||||||||||
| Pre-Merger Williams Partners |
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| Adjusted segment profit + DD&A (1) |
$ | 2,586 | $ | 2,589 | $ | 521 | $ | 691 | ||||||||
| DCF attributable to partnership operations (1) (A) |
$ | 1,719 | $ | 1,771 | $ | 266 | $ | 509 | ||||||||
| Cash distribution coverage ratio (1) |
NA | .90x | NA | .92x | ||||||||||||
| Net income |
$ | 1,094 | $ | 1,116 | $ | 293 | $ | 217 | ||||||||
| Pre-Merger Access Midstream Partners |
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| Adjusted EBITDA (1) |
$ | 1,161 | $ | 859 | $ | 317 | $ | 241 | ||||||||
| Adjusted DCF (1) (B) |
$ | 853 | $ | 635 | $ | 230 | $ | 180 | ||||||||
| Cash distribution coverage ratio (1) |
NA | 1.49x | NA | 1.48x | ||||||||||||
| Net income |
$ | 398 | $ | 336 | $ | 228 | $ | 129 | ||||||||
| Combined Pre-Merger WPZ/ACMP DCF (1) (A+B) |
$ | 2,572 | $ | 2,406 | $ | 496 | $ | 689 | ||||||||
| (1) | Distributable cash flow, cash distribution coverage ratio, adjusted segment profit + DD&A, adjusted EBITDA and adjusted distributable cash flow are non-GAAP measures. Cash distribution coverage ratio for full-year and fourth quarter 2014 is not applicable as the cash distribution paid for fourth quarter 2014 was paid to unitholders of the merged MLP. Reconciliations to the most relevant measures included in GAAP are attached to this news release. |
Pre-Merger Williams Partners
For full-year 2014, pre-merger Williams Partners reported adjusted segment profit + DD&A of $2.586 billion, compared with $2.589 billion for 2013. The results include a $199 million increase in fee-based revenues, offset by $56 million lower results at the Geismar olefins plant (including actual and assumed business interruption insurance proceeds of $123 million and $311 million for 2013 and 2014, respectively). Additionally, 2014 adjusted segment profit + DD&A was reduced by $181 million as a result of commodity price declines including $130 million lower NGL margins, and $51 million primarily related to unfavorable inventory adjustments.
DCF for 2014 was $1.719 billion, compared with $1.771 billion for 2013. The primary drivers of DCF were the same as those that drove adjusted segment profit + DD&A. Additionally maintenance capital expenditures were also $97 million higher in the 2014 period, which includes $65 million of unusual Geismar-related expenditures.
Fourth quarter 2014 adjusted segment profit + DD&A was $521 million, compared with $691 million for fourth quarter 2013. The decrease for the quarter was primarily due to $137 million lower Geismar results (including actual and assumed business interruption insurance proceeds of $108 million for fourth quarter 2013). The partnership estimates that adjusted segment profit + DD&A would have been approximately $160 million higher had the expanded Geismar plant been in operation during fourth quarter 2014. Additionally, a $55 million increase in fee-based revenues was more than offset by $88 million of commodity price declines including $47 million primarily related to unfavorable inventory adjustments and $41 million lower NGL margins.
DCF for fourth quarter 2014 was $266 million, compared with $509 million for fourth quarter 2013. Again, the primary drivers for DCF were the same as those that drove adjusted segment profit + DD&A, however maintenance capital expenditures were $67 million higher for the 2014 period, including unusual Geismar-related expenditures.
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| Pre-Merger Williams Partners |
Full-Year 2014 | Full-Year 2013 | ||||||||||||||||||||||||||||||
| Amounts in millions (loss) | Segment Profit |
Adj.** | Adj. Segment Profit* |
Adj. Segment Profit + DD&A* |
Segment Profit |
Adj.** | Adj. Segment Profit* |
Adj. Segment Profit + DD&A* |
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| Northeast G&P |
$ | 212 | ($ | 119 | ) | $ | 93 | $ | 263 | ($24 | ) | $ | 32 | $ | 8 | $ | 140 | |||||||||||||||
| Atlantic-Gulf |
635 | 10 | 645 | 1,024 | 614 | (8 | ) | 606 | 969 | |||||||||||||||||||||||
| West |
631 | 8 | 639 | 878 | 741 | 0 | 741 | 977 | ||||||||||||||||||||||||
| NGL & Petchem Services |
265 | 89 | 354 | 421 | 346 | 97 | 443 | 503 | ||||||||||||||||||||||||
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| Total |
$ | 1,743 | ($12 | ) | $ | 1,731 | $ | 2,586 | $ | 1,677 | $ | 121 | $ | 1,798 | $ | 2,589 | ||||||||||||||||
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| 4Q 2014 | 4Q 2013 | |||||||||||||||||||||||||||||||
| Segment Profit |
Adj.** | Adj. Segment Profit* |
Adj. Segment Profit + DD&A* |
Segment Profit |
Adj.** | Adj. Segment Profit* |
Adj. Segment Profit + DD&A* |
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| Northeast G&P |
$ | 156 | ($ | 130 | ) | $ | 26 | $ | 76 | ($26 | ) | $ | 23 | ($3 | ) | $ | 35 | |||||||||||||||
| Atlantic-Gulf |
140 | 10 | 150 | 253 | 166 | (2 | ) | 164 | 255 | |||||||||||||||||||||||
| West |
139 | 2 | 141 | 202 | 186 | 0 | 186 | 245 | ||||||||||||||||||||||||
| NGL & Petchem Services |
39 | (66 | ) | (27 | ) | (10 | ) | 19 | 122 | 141 | 156 | |||||||||||||||||||||
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| Total |
$ | 474 | ($ | 184 | ) | $ | 290 | $ | 521 | $ | 345 | $ | 143 | $ | 488 | $ | 691 | |||||||||||||||
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| * | Schedules reconciling segment profit to adjusted segment profit and adjusted segment profit + DD&A are attached to this news release. |
| ** | Adjustments consist primarily of assumed business interruption insurance related to the Geismar plant and the removal of a contingency gain. |
Pre-Merger Access Midstream Partners
For full-year 2014, pre-merger Access Midstream’s adjusted EBITDA was $1.161 billion, an increase of $302 million, or 35.2 percent, compared with $859 million for 2013. DCF for 2014 was $725 million, up 14.2 percent over 2013 DCF of $635 million. After excluding the impact of one-time Williams transaction related costs, adjusted 2014 DCF totaled $853 million, an increase of $218 million, or 34.3 percent, from 2013 DCF.
For fourth quarter 2014, pre-merger Access Midstream’s adjusted EBITDA totaled $317 million, an increase of $76 million, or 31.5 percent, from fourth quarter 2013 adjusted EBITDA of $241 million. DCF for fourth quarter 2014 totaled $225 million, an increase of $45 million, or 25 percent, from fourth quarter 2013 DCF of $180 million. After excluding the impact of one-time Williams transaction related costs, adjusted DCF for fourth quarter 2014 totaled $230 million, an increase of $50 million, or 27.8 percent, from fourth quarter 2013 DCF.
Access Midstream experienced record volume performance throughout 2014, including generating a daily gross throughput record of more than 6.5 billion cubic feet in December 2014.
CEO Commentary
Alan Armstrong, chief executive officer of the general partner of Williams Partners (the newly merged MLP), made the following comments:
“In the fourth quarter, our fee-based revenues continued to grow and we began commissioning major new assets including Gulfstar One, Keathley Canyon Connector and our Geismar plant. These large-scale assets are ramping up in the first quarter of 2015 and are expected to deliver strong contributions for the balance of the year and beyond. However, the sharp decline in commodity prices, the delay in the startup of Geismar and higher costs associated with the commissioning of these large-scale assets, reduced our overall results.
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“The merger of Williams Partners and Access Midstream created a leading large-cap MLP focused on natural gas infrastructure, and further positions us to take advantage of long-term natural gas demand growth for power generation, manufacturing and exports. We expect the new Williams Partners to generate approximately $4.5 billion of adjusted EBITDA in 2015 from a gross margin that is about 88 percent fee-based, the majority of which consists of contracts with demand payments, cost-of-service rates or minimum volume commitments.
“Over the next three years, we’re deploying 99 percent of Williams Partners’ planned $9.3 billion of growth capital toward fully-contracted, fee-based projects. As a result, we’re confident in our ability to deliver one of the highest rates of distribution growth amongst our large-cap peers, despite lower commodity prices.”
Guidance for Williams Partners (newly merged MLP)
Earnings and cash flow guidance for Williams Partners (the newly merged MLP), reflects the following key assumptions:
| a. | Substantially lower commodity price assumptions (see accompanying table) |
| b. | Lower expected fee-based volumes in certain areas as a result of the lower commodity price environment |
| c. | Our Geismar plant, which restarted in February 2015, will continue to ramp up to expanded capacity through March. Production during February and March is expected to be intermittent, resulting in limited financial contribution for the first quarter. |
| d. | Deferral of the planned dropdown of Williams’ remaining NGL & Petchem Services projects in order to reduce Williams Partners’ near-term capital requirements |
Updated guidance for the new Williams Partners’ 2015 common unit cash distributions is $3.40 per unit with an annual growth rate of 7 percent to 11 percent through 2017 with growing coverage.
Current guidance assumes approximately $600 million of Williams Partners’ equity financing for 2015. We anticipate meeting these equity needs through Williams Partners’ at-the-market program. Additional financing needs are expected to be met primarily through the use of commercial paper, revolver borrowing and the issuance of new debt. Williams Partners expects to maintain investment-grade credit ratings.
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Current guidance is provided in the following table:
| Williams Partners (newly merged MLP) financial outlook and commodity price assumptions |
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| 2015 | 2016 | 2017 | ||||||||||||||||||||||||||||||||||
| (amounts in millions) | Low | Mid | High | Low | Mid | High | Low | Mid | High | |||||||||||||||||||||||||||
| Adjusted EBITDA |
$ | 4,300 | $ | 4,465 | $ | 4,630 | $ | 5,120 | $ | 5,315 | $ | 5,510 | $ | 5,750 | $ | 5,965 | $ | 6,180 | ||||||||||||||||||
| Distributable Cash Flow (1) |
$ | 2,845 | $ | 3,010 | $ | 3,175 | $ | 3,475 | $ | 3,675 | $ | 3,875 | $ | 3,960 | $ | 4,185 | $ | 4,410 | ||||||||||||||||||
| Total Cash Distributions |
$ | 3,010 | $ | 3,005 | $ | 2,995 | $ | 3,380 | $ | 3,440 | $ | 3,515 | $ | 3,770 | $ | 3,925 | $ | 4,090 | ||||||||||||||||||
| Cash Distributions per LP Unit |
$ | 3.40 | $ | 3.40 | $ | 3.40 | $ | 3.64 | $ | 3.71 | $ | 3.78 | $ | 3.89 | $ | 4.04 | $ | 4.19 | ||||||||||||||||||
| Cash Distribution Coverage Ratio (1) |
.95x | 1.00x | 1.06x | 1.03x | 1.07x | 1.10x | 1.05x | 1.07x | 1.08x | |||||||||||||||||||||||||||
| Pro Forma Cash Distribution Coverage Ratio (2) |
1.05x | NA | NA | |||||||||||||||||||||||||||||||||
| Capital & Investment Expenditures |
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| Growth |
$ | 3,250 | $ | 3,525 | $ | 3,800 | $ | 2,650 | $ | 2,925 | $ | 3,200 | $ | 2,550 | $ | 2,850 | $ | 3,150 | ||||||||||||||||||
| Maintenance |
$ | 430 | $ | 430 | $ | 430 | $ | 430 | $ | 430 | $ | 430 | $ | 430 | $ | 430 | $ | 430 | ||||||||||||||||||
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| Total Capital & Investment Expenditures |
$ | 3,680 | $ | 3,955 | $ | 4,230 | $ | 3,080 | $ | 3,355 | $ | 3,630 | $ | 2,980 | $ | 3,280 | $ | 3,580 | ||||||||||||||||||
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| Commodity Price Assumptions |
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| Crude Oil - WTI ($ per barrel) |
$ | 45.00 | $ | 55.00 | $ | 65.00 | $ | 53.75 | $ | 65.00 | $ | 76.25 | $ | 57.50 | $ | 70.00 | $ | 82.50 | ||||||||||||||||||
| Natural Gas - Henry Hub ($/MMBtu) |
$ | 2.50 | $ | 3.00 | $ | 3.50 | $ | 2.75 | $ | 3.25 | $ | 3.75 | $ | 3.25 | $ | 3.75 | $ | 4.25 | ||||||||||||||||||
| Composite NGL Barrel ($ per gallon) |
$ | 0.360 | $ | 0.450 | $ | 0.520 | $ | 0.410 | $ | 0.490 | $ | 0.560 | $ | 0.460 | $ | 0.550 | $ | 0.620 | ||||||||||||||||||
| Crack Spread ($ per pound) (3) |
$ | 0.297 | $ | 0.350 | $ | 0.411 | $ | 0.323 | $ | 0.376 | $ | 0.443 | $ | 0.346 | $ | 0.395 | $ | 0.466 | ||||||||||||||||||
| Ethylene spot - ($ per pound) |
$ | 0.360 | $ | 0.430 | $ | 0.500 | $ | 0.395 | $ | 0.465 | $ | 0.540 | $ | 0.430 | $ | 0.500 | $ | 0.580 | ||||||||||||||||||
| Ethane- ($ per gallon) |
$ | 0.150 | $ | 0.190 | $ | 0.210 | $ | 0.170 | $ | 0.210 | $ | 0.230 | $ | 0.200 | $ | 0.250 | $ | 0.270 | ||||||||||||||||||
| Propane ($ per gallon) |
$ | 0.500 | $ | 0.600 | $ | 0.700 | $ | 0.550 | $ | 0.650 | $ | 0.750 | $ | 0.600 | $ | 0.700 | $ | 0.800 | ||||||||||||||||||
| Propylene Spot ($ per pound) |
$ | 0.405 | $ | 0.475 | $ | 0.545 | $ | 0.415 | $ | 0.485 | $ | 0.555 | $ | 0.430 | $ | 0.500 | $ | 0.570 | ||||||||||||||||||
| (1) | Distributable cash flow and cash distribution coverage ratio are non-GAAP measures. Reconciliations to the most relevant measures included in GAAP are attached to this news release. |
| (2) | We estimate the 2015 cash distribution coverage ratio would have been approximately 1.05x, assuming Geismar, Keathley Canyon Connector and Gulfstar One were in service at expected capacity for full-year 2015. |
| (3) | Crack spread is based on delivered U.S. Gulf Coast ethylene and Mont Belvieu ethane. |
Year-End 2014 Materials to Be Posted Shortly; Conference Call Scheduled for Tomorrow
Year-end 2014 financial materials for pre-merger Williams Partners and pre-merger Access Midstream Partners will be posted shortly at www.williams.com. The materials include the data book and analyst package for pre-merger Williams Partners, as well as financial highlights and operating statistics for pre-merger Access Midstream Partners.
Williams Partners and Williams plan to jointly host a conference call and live webcast on Thursday, Feb. 19, at 9:30 a.m. EST. A limited number of phone lines will be available at (800) 768-6570. International callers should dial (785) 830-1942. A link to the webcast, as well as replays of the webcast in both streaming and downloadable podcast formats, will be available for two weeks following the event at www.williams.com.
Form 10-K
Williams Partners’ 2014 Form 10-K, which will contain the pre-merger results of Access Midstream Partners, is expected to be filed with the Securities and Exchange Commission next week. Once filed, the document will be available on both the SEC and Williams’ websites.
Williams Partners also anticipates filing a Form 8-K next week including supplemental financial statements for the post-merger partnership, which will present the results for pre-merger Williams Partners and pre-merger Access Midstream Partners at Williams’ basis in both partnerships, combined for the periods under common control since the July 1 acquisition of Access Midstream Partners by Williams. Periods prior to that date will primarily reflect only pre-merger Williams Partners at Williams’ accounting basis.
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Definitions and Non-GAAP Measures
This news includes certain financial measures – adjusted EBITDA, adjusted segment profit and adjusted segment profit + DD&A, distributable cash flow and cash distribution coverage ratio – that are non-GAAP financial measures as defined under the rules of the Securities and Exchange Commission. For the following definitions, depreciation and amortization (DD&A) includes amortization of basis differences related to equity-method investments.
Adjusted EBITDA is defined as net income (loss) before income tax expense, net interest expense, depreciation and amortization expense (including amortization of basis differences related to equity-method investments) and equity earnings from investments, adjusted for certain other items management believes affect the comparability of operating results. We also add our proportional ownership share of net income (loss) before income tax expense, net interest expense, depreciation and amortization expense of equity investments.
Adjusted segment profit excludes items of income or loss that we characterize as unrepresentative of our ongoing operations and may include assumed business interruption insurance related to the Geismar plant. Adjusted segment profit + DD&A is adjusted to add back depreciation and amortization expense. Management believes these measures provide investors meaningful insight into results from ongoing operations.
For the newly merged-MLP, Williams Partners L.P., we define distributable cash flow as adjusted EBITDA less maintenance capital expenditures, cash paid for interest expense, distributions to noncontrolling interests and cash income taxes.
For the newly merged-MLP, Williams Partners L.P., we also calculate the ratio of distributable cash flow to the total cash distributed (cash distribution coverage ratio). This measure reflects the amount of distributable cash flow relative to our cash distribution. We have also provided this ratio calculated using the most directly comparable GAAP measure, net income.
This news release is accompanied by a reconciliation of these non-GAAP financial measures to their nearest GAAP financial measures. Management uses these financial measures because they are accepted financial indicators used by investors to compare company performance. In addition, management believes that these measures provide investors an enhanced perspective of the operating performance of the Partnership’s assets and the cash that the business is generating.
Neither adjusted EBITDA, adjusted segment profit, adjusted segment profit + DD&A, nor distributable cash flow are intended to represent cash flows for the period, nor are they presented as an alternative to net income or cash flow from operations. They should not be considered in isolation or as substitutes for a measure of performance prepared in accordance with United States generally accepted accounting principles.
About Williams Partners (newly merged partnership)
Williams Partners (NYSE: WPZ) is an industry-leading, large-cap natural gas infrastructure master limited partnership with a strong growth outlook and substantial positions across key U.S. supply basins and also in Canada. Williams Partners has operations across the natural gas value chain from gathering, processing and interstate transportation of natural gas and natural gas liquids to petchem production of ethylene, propylene and other olefins. Williams Partners owns and operates more than 33,000 miles of pipelines system wide – including the nation’s largest volume and fastest growing pipeline – moving approximately 20 percent of U.S. natural gas for clean-power generation, home heating and industrial use. Tulsa, Okla.-based Williams (NYSE: WMB), a premier provider of large-scale North American natural gas infrastructure, owns 60 percent of Williams Partners, including the general-partner interest. www.williams.com
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Forward Looking Statements
The reports, filings, and other public announcements of The Williams Companies, Inc. (Williams) and Williams Partners L.P. (WPZ) may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. You typically can identify forward-looking statements by various forms of words such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” “assumes,” “guidance,” “outlook,” “in service date” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:
| • | Expected levels of cash distributions by WPZ with respect to general partner interests, incentive distribution rights, and limited partner interests; |
| • | The levels of dividends to Williams stockholders; |
| • | Future credit ratings of Williams and WPZ; |
| • | Amounts and nature of future capital expenditures; |
| • | Expansion and growth of our business and operations; |
| • | Financial condition and liquidity; |
| • | Business strategy; |
| • | Cash flow from operations or results of operations; |
| • | Seasonality of certain business components; |
| • | Natural gas, natural gas liquids, and olefins prices, supply, and demand; and |
| • | Demand for our services. |
Forward-looking statements are based on numerous assumptions, uncertainties and risks that could cause future events or results to be materially different from those stated or implied in this presentation. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:
| • | Whether WPZ will produce sufficient cash flows to provide the level of cash distributions we expect; |
| • | Whether Williams is able to pay current and expected levels of dividends; |
| • | Availability of supplies, market demand, and volatility of prices; |
| • | Inflation, interest rates, and fluctuation in foreign exchange rates and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers); |
| • | The strength and financial resources of our competitors and the effects of competition; |
| • | Whether we are able to successfully identify, evaluate and execute investment opportunities; |
| • | Our ability to acquire new businesses and assets and successfully integrate those operations and assets into our existing businesses as well as successfully expand our facilities; |
| • | Development of alternative energy sources; |
| • | The impact of operational and developmental hazards and unforeseen interruptions; |
| • | The ability to recover expected insurance proceeds related to the Geismar plant; |
| • | Costs of, changes in, or the results of laws, government regulations (including safety and environmental regulations), environmental liabilities, litigation, and rate proceedings; |
| • | Williams’ costs and funding obligations for defined benefit pension plans and other postretirement benefit plans; |
| • | WPZ’s allocated costs for defined benefit pension plans and other postretirement benefit plans sponsored by its affiliates; |
| • | Changes in maintenance and construction costs; |
| • | Changes in the current geopolitical situation; |
| • | Our exposure to the credit risk of our customers and counterparties; |
| • | Risks related to financing, including restrictions stemming from debt agreements, future changes in credit ratings as determined by nationally-recognized credit rating agencies and the availability and cost of capital; |
| • | The amount of cash distributions from and capital requirements of our investments and joint ventures in which we participate; |
| • | Risks associated with weather and natural phenomena, including climate conditions; |
| • | Acts of terrorism, including cybersecurity threats and related disruptions; and |
| • | Additional risks described in our filings with the Securities and Exchange Commission (SEC). |
Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to and do not intend to update the above list or announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.
In addition to causing our actual results to differ, the factors listed above may cause our intentions to change from those statements of intention set forth in this presentation. Such changes in our intentions may also cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.
7
Investors are urged to closely consider the disclosures and risk factors in Williams’ and WPZ’s annual reports on Form 10-K filed with the SEC on Feb. 26, 2014, and each of our quarterly reports on Form 10-Q available from our offices or from our website at www.williams.com.
# # #
8
PRE-MERGER
Financial Highlights and Operating Statistics
(UNAUDITED)
Final
December 31, 2014
Pre-merger Williams Partners L.P.
Reconciliation of Non-GAAP Measures
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions, except coverage ratios) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Williams Partners L.P. |
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| Reconciliation of Non-GAAP “Distributable cash flow” to GAAP “Net income” |
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| Net income |
$ | 344 | $ | 272 | $ | 285 | $ | 218 | $ | 1,119 | $ | 352 | $ | 234 | $ | 218 | $ | 300 | $ | 1,104 | ||||||||||||||||||||
| Income attributable to noncontrolling interests |
— | — | — | (3 | ) | (3 | ) | — | (2 | ) | (1 | ) | (7 | ) | (10 | ) | ||||||||||||||||||||||||
| Depreciation and amortization |
196 | 191 | 201 | 203 | 791 | 208 | 207 | 209 | 231 | 855 | ||||||||||||||||||||||||||||||
| Non-cash amortization of debt issuance costs included in interest expense |
3 | 4 | 4 | 3 | 14 | 4 | 3 | 4 | 4 | 15 | ||||||||||||||||||||||||||||||
| Equity earnings from investments |
(18 | ) | (35 | ) | (31 | ) | (20 | ) | (104 | ) | (23 | ) | (32 | ) | (36 | ) | (41 | ) | (132 | ) | ||||||||||||||||||||
| Allocated reorganization-related costs |
2 | — | — | — | 2 | — | — | — | — | — | ||||||||||||||||||||||||||||||
| Impairment of certain materials and equipment |
— | — | — | — | — | — | 17 | — | 23 | 40 | ||||||||||||||||||||||||||||||
| Loss related to Geismar Incident |
— | 6 | 4 | 4 | 14 | — | — | 5 | 5 | 10 | ||||||||||||||||||||||||||||||
| Geismar Incident adjustment for insurance and timing |
— | — | (35 | ) | 118 | 83 | 54 | 96 | — | (71 | ) | 79 | ||||||||||||||||||||||||||||
| Contingency (gain) loss, net of legal costs |
— | — | 9 | 16 | 25 | — | — | — | (143 | ) | (143 | ) | ||||||||||||||||||||||||||||
| Reimbursements from Williams under omnibus agreements |
4 | 4 | 2 | 3 | 13 | 3 | 4 | 1 | 3 | 11 | ||||||||||||||||||||||||||||||
| Loss related to Opal incident |
— | — | — | — | — | — | 6 | — | 2 | 8 | ||||||||||||||||||||||||||||||
| Plymouth incident adjustment |
— | — | — | — | — | — | 3 | 3 | 6 | 12 | ||||||||||||||||||||||||||||||
| Canadian income tax |
— | — | — | — | — | — | 4 | 8 | 28 | 40 | ||||||||||||||||||||||||||||||
| Income related to partial acreage dedication release |
— | — | — | — | — | — | — | (12 | ) | — | (12 | ) | ||||||||||||||||||||||||||||
| Maintenance capital expenditures |
(44 | ) | (76 | ) | (79 | ) | (59 | ) | (258 | ) | (36 | ) | (90 | ) | (103 | ) | (126 | ) | (355 | ) | ||||||||||||||||||||
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| Distributable cash flow excluding equity investments |
487 | 366 | 360 | 483 | 1,696 | 562 | 450 | 296 | 214 | 1,522 | ||||||||||||||||||||||||||||||
| Plus: Equity investments cash distributions to Williams Partners L.P. |
38 | 41 | 34 | 41 | 154 | 43 | 54 | 71 | 52 | 220 | ||||||||||||||||||||||||||||||
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| Distributable cash flow |
525 | 407 | 394 | 524 | 1,850 | 605 | 504 | 367 | 266 | 1,742 | ||||||||||||||||||||||||||||||
| Less: Pre-partnership distributable cash flow |
28 | 20 | 16 | 15 | 79 | 23 | — | — | — | 23 | ||||||||||||||||||||||||||||||
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| Distributable cash flow attributable to partnership operations |
$ | 497 | $ | 387 | $ | 378 | $ | 509 | $ | 1,771 | $ | 582 | $ | 504 | $ | 367 | $ | 266 | $ | 1,719 | ||||||||||||||||||||
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| Total cash distributed |
$ | 473 | $ | 489 | $ | 442 | $ | 556 | $ | 1,960 | $ | 566 | $ | 577 | $ | 587 | $ | — | $ | 1,730 | ||||||||||||||||||||
| Coverage ratios: |
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| Distributable cash flow attributable to partnership operations divided by Total cash distributed |
1.05 | 0.79 | 0.86 | 0.92 | 0.90 | 1.03 | 0.87 | 0.63 | NA | NA | ||||||||||||||||||||||||||||||
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| Net income divided by Total cash distributed |
0.73 | 0.56 | 0.64 | 0.39 | 0.57 | 0.62 | 0.41 | 0.37 | NA | NA | ||||||||||||||||||||||||||||||
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Pre-merger Williams Partners L.P.
Reconciliation of GAAP “Segment Profit (Loss)” to Non-GAAP “Adjusted Segment Profit (Loss)” and “Adjusted Segment Profit (Loss) + DD&A”
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Segment profit (loss): |
||||||||||||||||||||||||||||||||||||||||
| Northeast G&P |
$ | (9 | ) | $ | 12 | $ | (1 | ) | $ | (26 | ) | $ | (24 | ) | $ | 6 | $ | 15 | $ | 35 | $ | 156 | $ | 212 | ||||||||||||||||
| Atlantic-Gulf |
159 | 152 | 137 | 166 | 614 | 165 | 168 | 162 | 140 | 635 | ||||||||||||||||||||||||||||||
| West |
186 | 162 | 207 | 186 | 741 | 165 | 152 | 175 | 139 | 631 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
158 | 101 | 68 | 19 | 346 | 167 | 58 | 1 | 39 | 265 | ||||||||||||||||||||||||||||||
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| Total segment profit (loss) |
$ | 494 | $ | 427 | $ | 411 | $ | 345 | $ | 1,677 | $ | 503 | $ | 393 | $ | 373 | $ | 474 | $ | 1,743 | ||||||||||||||||||||
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| Segment adjustments: |
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| Northeast G&P |
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| Share of impairments at equity method investee |
$ | — | $ | — | $ | — | $ | 7 | $ | 7 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||||||||||
| Contingency (gain) loss, net of legal costs |
— | — | 9 | 16 | 25 | — | — | — | (143 | ) | (143 | ) | ||||||||||||||||||||||||||||
| Loss related to compressor station fire |
— | — | — | — | — | 6 | — | — | — | 6 | ||||||||||||||||||||||||||||||
| Net gain related to partial acreage dedication release |
— | — | — | — | — | — | — | (12 | ) | — | (12 | ) | ||||||||||||||||||||||||||||
| Impairment of certain materials and equipment |
— | — | — | — | — | — | 17 | — | 13 | 30 | ||||||||||||||||||||||||||||||
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| Total Northeast G&P adjustments |
— | — | 9 | 23 | 32 | 6 | 17 | (12 | ) | (130 | ) | (119 | ) | |||||||||||||||||||||||||||
| Atlantic-Gulf |
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| Impairment of certain equipment |
— | — | — | — | — | — | — | — | 10 | 10 | ||||||||||||||||||||||||||||||
| Litigation settlement gain |
(6 | ) | — | — | — | (6 | ) | — | — | — | — | — | ||||||||||||||||||||||||||||
| Net loss (recovery) related to Eminence storage facility leak |
— | (5 | ) | 5 | (2 | ) | (2 | ) | — | — | — | — | — | |||||||||||||||||||||||||||
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| Total Atlantic-Gulf adjustments |
(6 | ) | (5 | ) | 5 | (2 | ) | (8 | ) | — | — | — | 10 | 10 | ||||||||||||||||||||||||||
| West |
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| Loss related to Opal incident |
— | — | — | — | — | — | 6 | — | 2 | 8 | ||||||||||||||||||||||||||||||
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| Total West adjustments |
— | — | — | — | — | — | 6 | — | 2 | 8 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
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| Loss related to Geismar Incident |
— | 6 | 4 | 4 | 14 | — | — | 5 | 5 | 10 | ||||||||||||||||||||||||||||||
| Geismar Incident adjustment for insurance and timing |
— | — | (35 | ) | 118 | 83 | 54 | 96 | — | (71 | ) | 79 | ||||||||||||||||||||||||||||
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| Total NGL & Petchem Services adjustments |
— | 6 | (31 | ) | 122 | 97 | 54 | 96 | 5 | (66 | ) | 89 | ||||||||||||||||||||||||||||
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| Total segment adjustments |
$ | (6 | ) | $ | 1 | $ | (17 | ) | $ | 143 | $ | 121 | $ | 60 | $ | 119 | $ | (7 | ) | $ | (184 | ) | $ | (12 | ) | |||||||||||||||
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| Adjusted segment profit (loss): |
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| Northeast G&P |
$ | (9 | ) | $ | 12 | $ | 8 | $ | (3 | ) | $ | 8 | $ | 12 | $ | 32 | $ | 23 | $ | 26 | $ | 93 | ||||||||||||||||||
| Atlantic-Gulf |
153 | 147 | 142 | 164 | 606 | 165 | 168 | 162 | 150 | 645 | ||||||||||||||||||||||||||||||
| West |
186 | 162 | 207 | 186 | 741 | 165 | 158 | 175 | 141 | 639 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
158 | 107 | 37 | 141 | 443 | 221 | 154 | 6 | (27 | ) | 354 | |||||||||||||||||||||||||||||
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| Total adjusted segment profit (loss) |
$ | 488 | $ | 428 | $ | 394 | $ | 488 | $ | 1,798 | $ | 563 | $ | 512 | $ | 366 | $ | 290 | $ | 1,731 | ||||||||||||||||||||
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| Depreciation and amortization (DD&A): |
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| Northeast G&P |
$ | 29 | $ | 32 | $ | 33 | $ | 38 | $ | 132 | $ | 39 | $ | 40 | $ | 41 | $ | 50 | $ | 170 | ||||||||||||||||||||
| Atlantic-Gulf |
93 | 87 | 92 | 91 | 363 | 94 | 91 | 91 | 103 | 379 | ||||||||||||||||||||||||||||||
| West |
61 | 58 | 58 | 59 | 236 | 58 | 60 | 60 | 61 | 239 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
13 | 14 | 18 | 15 | 60 | 17 | 16 | 17 | 17 | 67 | ||||||||||||||||||||||||||||||
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| Total depreciation and amortization |
$ | 196 | $ | 191 | $ | 201 | $ | 203 | $ | 791 | $ | 208 | $ | 207 | $ | 209 | $ | 231 | $ | 855 | ||||||||||||||||||||
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| Adjusted segment profit (loss) + DD&A: |
||||||||||||||||||||||||||||||||||||||||
| Northeast G&P |
$ | 20 | $ | 44 | $ | 41 | $ | 35 | $ | 140 | $ | 51 | $ | 72 | $ | 64 | $ | 76 | $ | 263 | ||||||||||||||||||||
| Atlantic-Gulf |
246 | 234 | 234 | 255 | 969 | 259 | 259 | 253 | 253 | 1,024 | ||||||||||||||||||||||||||||||
| West |
247 | 220 | 265 | 245 | 977 | 223 | 218 | 235 | 202 | 878 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
171 | 121 | 55 | 156 | 503 | 238 | 170 | 23 | (10 | ) | 421 | |||||||||||||||||||||||||||||
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| Total adjusted segment profit (loss) + DD&A |
$ | 684 | $ | 619 | $ | 595 | $ | 691 | $ | 2,589 | $ | 771 | $ | 719 | $ | 575 | $ | 521 | $ | 2,586 | ||||||||||||||||||||
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| Note: | Segment profit (loss) includes equity earnings (losses) and income (loss) from investments reported in other income (expense) - net below operating income in the Consolidated Statement of Comprehensive Income. Equity earnings (losses) result from investments accounted for under the equity method. Income (loss) from investments results from the management of certain equity investments. |
Pre-merger Williams Partners L.P.
Consolidated Statement of Income
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions, except per-unit amounts) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Revenues: |
||||||||||||||||||||||||||||||||||||||||
| Service revenues |
$ | 702 | $ | 717 | $ | 731 | $ | 764 | $ | 2,914 | $ | 763 | $ | 763 | $ | 766 | $ | 815 | $ | 3,107 | ||||||||||||||||||||
| Product sales |
1,104 | 1,046 | 887 | 884 | 3,921 | 930 | 853 | 942 | 796 | 3,521 | ||||||||||||||||||||||||||||||
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| Total revenues |
1,806 | 1,763 | 1,618 | 1,648 | 6,835 | 1,693 | 1,616 | 1,708 | 1,611 | 6,628 | ||||||||||||||||||||||||||||||
| Costs and expenses: |
||||||||||||||||||||||||||||||||||||||||
| Product costs |
790 | 801 | 710 | 726 | 3,027 | 769 | 724 | 807 | 716 | 3,016 | ||||||||||||||||||||||||||||||
| Operating and maintenance expenses |
257 | 289 | 265 | 269 | 1,080 | 248 | 251 | 267 | 306 | 1,072 | ||||||||||||||||||||||||||||||
| Depreciation and amortization expenses |
196 | 191 | 201 | 203 | 791 | 208 | 207 | 209 | 231 | 855 | ||||||||||||||||||||||||||||||
| Selling, general, and administrative expenses |
130 | 131 | 130 | 128 | 519 | 130 | 132 | 129 | 154 | 545 | ||||||||||||||||||||||||||||||
| Net insurance recoveries—Geismar Incident |
— | — | (50 | ) | 10 | (40 | ) | (119 | ) | (42 | ) | — | (71 | ) | (232 | ) | ||||||||||||||||||||||||
| Other (income) expense—net |
1 | 4 | 21 | 25 | 51 | 17 | 27 | (1 | ) | (111 | ) | (68 | ) | |||||||||||||||||||||||||||
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| Total costs and expenses |
1,374 | 1,416 | 1,277 | 1,361 | 5,428 | 1,253 | 1,299 | 1,411 | 1,225 | 5,188 | ||||||||||||||||||||||||||||||
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| Equity earnings (losses) |
18 | 35 | 31 | 20 | 104 | 23 | 32 | 36 | 41 | 132 | ||||||||||||||||||||||||||||||
| Income (loss) from investments |
(1 | ) | (1 | ) | (1 | ) | — | (3 | ) | — | — | — | — | — | ||||||||||||||||||||||||||
| General corporate expenses |
45 | 46 | 40 | 38 | 169 | 40 | 44 | 40 | 47 | 171 | ||||||||||||||||||||||||||||||
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| Total segment profit |
494 | 427 | 411 | 345 | 1,677 | 503 | 393 | 373 | 474 | 1,743 | ||||||||||||||||||||||||||||||
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| Reclass equity earnings (losses) |
(18 | ) | (35 | ) | (31 | ) | (20 | ) | (104 | ) | (23 | ) | (32 | ) | (36 | ) | (41 | ) | (132 | ) | ||||||||||||||||||||
| Reclass income (loss) from investments |
1 | 1 | 1 | — | 3 | — | — | — | — | — | ||||||||||||||||||||||||||||||
| Reclass general corporate expenses |
(45 | ) | (46 | ) | (40 | ) | (38 | ) | (169 | ) | (40 | ) | (44 | ) | (40 | ) | (47 | ) | (171 | ) | ||||||||||||||||||||
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| Operating income |
432 | 347 | 341 | 287 | 1,407 | 440 | 317 | 297 | 386 | 1,440 | ||||||||||||||||||||||||||||||
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| Equity earnings (losses) |
18 | 35 | 31 | 20 | 104 | 23 | 32 | 36 | 41 | 132 | ||||||||||||||||||||||||||||||
| Interest incurred |
(118 | ) | (118 | ) | (119 | ) | (122 | ) | (477 | ) | (131 | ) | (142 | ) | (155 | ) | (156 | ) | (584 | ) | ||||||||||||||||||||
| Interest capitalized |
22 | 22 | 24 | 22 | 90 | 25 | 25 | 36 | 23 | 109 | ||||||||||||||||||||||||||||||
| Other income (expense)—net |
5 | 7 | 7 | 6 | 25 | 3 | 7 | 13 | 15 | 38 | ||||||||||||||||||||||||||||||
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| Income before income taxes |
359 | 293 | 284 | 213 | 1,149 | 360 | 239 | 227 | 309 | 1,135 | ||||||||||||||||||||||||||||||
| Provision (benefit) for income taxes |
15 | 21 | (1 | ) | (5 | ) | 30 | 8 | 5 | 9 | 9 | 31 | ||||||||||||||||||||||||||||
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| Net income |
344 | 272 | 285 | 218 | 1,119 | 352 | 234 | 218 | 300 | 1,104 | ||||||||||||||||||||||||||||||
| Less: Net income attributable to noncontrolling interests |
— | 1 | 1 | 1 | 3 | — | 2 | 1 | 7 | 10 | ||||||||||||||||||||||||||||||
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| Net income attributable to controlling interests |
$ | 344 | $ | 271 | $ | 284 | $ | 217 | $ | 1,116 | $ | 352 | $ | 232 | $ | 217 | $ | 293 | $ | 1,094 | ||||||||||||||||||||
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| Allocation of net income for calculation of earnings per common unit: |
||||||||||||||||||||||||||||||||||||||||
| Net income attributable to controlling interests |
$ | 344 | $ | 271 | $ | 284 | $ | 217 | $ | 1,116 | $ | 352 | $ | 232 | $ | 217 | $ | 293 | $ | 1,094 | ||||||||||||||||||||
| Allocation of net income to general partner |
142 | 141 | 60 | 162 | 505 | 180 | 167 | 171 | 144 | 662 | ||||||||||||||||||||||||||||||
| Allocation of net income to Class D units |
— | — | — | — | — | 14 | 18 | 17 | 24 | 73 | ||||||||||||||||||||||||||||||
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| Allocation of net income to common units |
$ | 202 | $ | 130 | $ | 224 | $ | 55 | $ | 611 | $ | 158 | $ | 47 | $ | 29 | $ | 125 | $ | 359 | ||||||||||||||||||||
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|||||||||||||||||||||
| Net income per common unit |
$ | .50 | $ | .31 | $ | .52 | $ | .12 | $ | 1.45 | $ | .36 | $ | .11 | $ | .07 | $ | .27 | $ | .78 | ||||||||||||||||||||
| Weighted-average number of common units outstanding (thousands) |
401,969 | 413,901 | 428,682 | 438,626 | 420,916 | 438,626 | 438,626 | 439,138 | 466,469 | 461,086 | ||||||||||||||||||||||||||||||
| Cash distributions per common unit |
$ | .8475 | $ | .8625 | $ | .8775 | $ | .8925 | $ | 3.480 | $ | .9045 | $ | .9165 | $ | .9285 | $ | .8500 | $ | 3.5995 | ||||||||||||||||||||
| Note: | The sum of net income per common unit for the quarters may not equal the total income per common unit for the year due to changes in the weighted-average number of common units outstanding. |
Pre-merger Williams Partners L.P.
Northeast G&P
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Revenues: |
||||||||||||||||||||||||||||||||||||||||
| Fee-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| Gathering & processing |
$ | 59 | $ | 69 | $ | 84 | $ | 90 | $ | 302 | $ | 90 | $ | 93 | $ | 99 | $ | 112 | $ | 394 | ||||||||||||||||||||
| Production handling and transportation |
1 | 3 | 2 | 4 | 10 | 3 | 2 | 4 | 5 | 14 | ||||||||||||||||||||||||||||||
| Other fee revenues |
3 | 6 | 8 | 6 | 23 | 6 | 12 | 11 | 15 | 44 | ||||||||||||||||||||||||||||||
| Commodity-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| NGL sales from gas processing |
1 | — | 3 | 2 | 6 | 2 | 2 | 2 | 3 | 9 | ||||||||||||||||||||||||||||||
| Marketing sales |
19 | 34 | 45 | 62 | 160 | 58 | 35 | 66 | 62 | 221 | ||||||||||||||||||||||||||||||
| Other sales |
— | 1 | (1 | ) | — | — | — | — | — | — | — | |||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| 83 | 113 | 141 | 164 | 501 | 159 | 144 | 182 | 197 | 682 | |||||||||||||||||||||||||||||||
| Intrasegment eliminations |
— | — | (1 | ) | 1 | — | — | — | — | (1 | ) | (1 | ) | |||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| Total revenues |
83 | 113 | 140 | 165 | 501 | 159 | 144 | 182 | 196 | 681 | ||||||||||||||||||||||||||||||
| Segment costs and expenses: |
||||||||||||||||||||||||||||||||||||||||
| NGL cost of goods sold |
— | — | (1 | ) | — | (1 | ) | 1 | — | — | (1 | ) | — | |||||||||||||||||||||||||||
| Marketing cost of goods sold |
20 | 33 | 46 | 62 | 161 | 57 | 37 | 65 | 62 | 221 | ||||||||||||||||||||||||||||||
| Depreciation and amortization |
29 | 32 | 33 | 38 | 132 | 39 | 40 | 41 | 50 | 170 | ||||||||||||||||||||||||||||||
| Other segment costs and expenses |
40 | 43 | 66 | 77 | 226 | 57 | 62 | 45 | (66 | ) | 98 | |||||||||||||||||||||||||||||
| Intrasegment eliminations |
— | — | (1 | ) | 1 | — | — | — | — | (1 | ) | (1 | ) | |||||||||||||||||||||||||||
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|||||||||||||||||||||
| Total segment costs and expenses |
89 | 108 | 143 | 178 | 518 | 154 | 139 | 151 | 44 | 488 | ||||||||||||||||||||||||||||||
| Equity earnings (losses) |
(3 | ) | 7 | 2 | (13 | ) | (7 | ) | 1 | 10 | 4 | 4 | 19 | |||||||||||||||||||||||||||
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|||||||||||||||||||||
| Reported segment profit (loss) |
(9 | ) | 12 | (1 | ) | (26 | ) | (24 | ) | 6 | 15 | 35 | 156 | 212 | ||||||||||||||||||||||||||
| Adjustments |
— | — | 9 | 23 | 32 | 6 | 17 | (12 | ) | (130 | ) | (119 | ) | |||||||||||||||||||||||||||
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|||||||||||||||||||||
| Adjusted segment profit (loss) |
$ | (9 | ) | $ | 12 | $ | 8 | $ | (3 | ) | $ | 8 | $ | 12 | $ | 32 | $ | 23 | $ | 26 | $ | 93 | ||||||||||||||||||
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|||||||||||||||||||||
| Operating statistics |
||||||||||||||||||||||||||||||||||||||||
| Gathering and Processing* |
||||||||||||||||||||||||||||||||||||||||
| Gathering volumes (Tbtu) |
127 | 142 | 157 | 180 | 606 | 179 | 189 | 193 | 227 | 788 | ||||||||||||||||||||||||||||||
| Plant inlet natural gas volumes (Tbtu) |
18 | 25 | 28 | 34 | 105 | 29 | 27 | 30 | 32 | 118 | ||||||||||||||||||||||||||||||
| Ethane equity sales (million gallons) |
— | — | — | — | — | — | — | — | 3 | 3 | ||||||||||||||||||||||||||||||
| Non-ethane equity sales (million gallons) |
1 | 1 | 3 | 2 | 7 | 2 | 1 | 3 | 2 | 8 | ||||||||||||||||||||||||||||||
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|||||||||||||||||||||
| NGL equity sales (million gallons) |
1 | 1 | 3 | 2 | 7 | 2 | 1 | 3 | 5 | 11 | ||||||||||||||||||||||||||||||
| Ethane production (million gallons) |
— | 1 | 1 | 1 | 3 | 1 | 1 | 1 | 30 | 33 | ||||||||||||||||||||||||||||||
| Non-ethane production (million gallons) |
21 | 32 | 39 | 44 | 136 | 38 | 37 | 42 | 40 | 157 | ||||||||||||||||||||||||||||||
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|||||||||||||||||||||
| NGL production (million gallons) |
21 | 33 | 40 | 45 | 139 | 39 | 38 | 43 | 70 | 190 | ||||||||||||||||||||||||||||||
| Laurel Mountain Midstream LLC |
||||||||||||||||||||||||||||||||||||||||
| Gathering volumes (Tbtu) |
27 | 29 | 32 | 36 | 124 | 34 | 36 | 38 | 40 | 148 | ||||||||||||||||||||||||||||||
| * | Excludes volumes associated with partially owned assets that are not consolidated for financial reporting purposes. |
Pre-merger Williams Partners L.P.
Atlantic-Gulf
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Revenues: |
||||||||||||||||||||||||||||||||||||||||
| Fee-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| Gathering & processing |
$ | 19 | $ | 19 | $ | 15 | $ | 17 | $ | 70 | $ | 16 | $ | 21 | $ | 21 | $ | 20 | $ | 78 | ||||||||||||||||||||
| Production handling and transportation |
283 | 282 | 282 | 302 | 1,149 | 307 | 293 | 296 | 328 | 1,224 | ||||||||||||||||||||||||||||||
| Other fee revenues |
29 | 29 | 30 | 30 | 118 | 30 | 29 | 28 | 27 | 114 | ||||||||||||||||||||||||||||||
| Commodity-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| NGL sales from gas processing |
28 | 26 | 22 | 27 | 103 | 20 | 25 | 19 | 14 | 78 | ||||||||||||||||||||||||||||||
| Marketing sales |
176 | 186 | 167 | 175 | 704 | 171 | 162 | 171 | 139 | 643 | ||||||||||||||||||||||||||||||
| Other sales |
1 | — | — | 2 | 3 | 1 | 1 | 2 | (1 | ) | 3 | |||||||||||||||||||||||||||||
| Tracked revenues: |
52 | 59 | 46 | 43 | 200 | 53 | 40 | 52 | 62 | 207 | ||||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| 588 | 601 | 562 | 596 | 2,347 | 598 | 571 | 589 | 589 | 2,347 | |||||||||||||||||||||||||||||||
| Intrasegment eliminations |
1 | 1 | 1 | (1 | ) | 2 | 2 | 2 | 1 | 2 | 7 | |||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| Total revenues |
589 | 602 | 563 | 595 | 2,349 | 600 | 573 | 590 | 591 | 2,354 | ||||||||||||||||||||||||||||||
| Segment costs and expenses: |
||||||||||||||||||||||||||||||||||||||||
| NGL cost of goods sold |
6 | 7 | 5 | 6 | 24 | 6 | 5 | 5 | 5 | 21 | ||||||||||||||||||||||||||||||
| Marketing cost of goods sold |
176 | 186 | 167 | 175 | 704 | 171 | 162 | 171 | 140 | 644 | ||||||||||||||||||||||||||||||
| Depreciation and amortization expenses |
93 | 87 | 92 | 91 | 363 | 94 | 91 | 91 | 103 | 379 | ||||||||||||||||||||||||||||||
| Other segment costs and expenses |
118 | 130 | 132 | 134 | 514 | 124 | 121 | 133 | 160 | 538 | ||||||||||||||||||||||||||||||
| Tracked costs |
52 | 59 | 46 | 43 | 200 | 53 | 40 | 52 | 62 | 207 | ||||||||||||||||||||||||||||||
| Intrasegment eliminations |
1 | 1 | 1 | (1 | ) | 2 | 2 | 2 | 1 | 1 | 6 | |||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| Total segment costs and expenses |
446 | 470 | 443 | 448 | 1,807 | 450 | 421 | 453 | 471 | 1,795 | ||||||||||||||||||||||||||||||
| Equity earnings (losses) |
16 | 20 | 17 | 19 | 72 | 15 | 16 | 25 | 20 | 76 | ||||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| Reported segment profit |
159 | 152 | 137 | 166 | 614 | 165 | 168 | 162 | 140 | 635 | ||||||||||||||||||||||||||||||
| Adjustments |
(6 | ) | (5 | ) | 5 | (2 | ) | (8 | ) | — | — | — | 10 | 10 | ||||||||||||||||||||||||||
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|||||||||||||||||||||
| Adjusted segment profit |
$ | 153 | $ | 147 | $ | 142 | $ | 164 | $ | 606 | $ | 165 | $ | 168 | $ | 162 | $ | 150 | $ | 645 | ||||||||||||||||||||
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|||||||||||||||||||||
| Operating statistics |
||||||||||||||||||||||||||||||||||||||||
| Gathering and Processing* |
||||||||||||||||||||||||||||||||||||||||
| Gathering volumes (Tbtu) |
39 | 36 | 31 | 31 | 137 | 28 | 31 | 30 | 27 | 116 | ||||||||||||||||||||||||||||||
| Plant inlet natural gas volumes (Tbtu) |
76 | 78 | 55 | 61 | 270 | 60 | 72 | 73 | 73 | 278 | ||||||||||||||||||||||||||||||
| Ethane equity sales (million gallons) |
8 | 6 | 7 | 7 | 28 | 2 | 6 | 8 | 2 | 18 | ||||||||||||||||||||||||||||||
| Non-ethane equity sales (million gallons) |
20 | 20 | 16 | 18 | 74 | 12 | 18 | 13 | 13 | 56 | ||||||||||||||||||||||||||||||
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|||||||||||||||||||||
| NGL equity sales (million gallons) |
28 | 26 | 23 | 25 | 102 | 14 | 24 | 21 | 15 | 74 | ||||||||||||||||||||||||||||||
| Ethane margin ($/gallon) |
$ | 0.16 | $ | 0.21 | $ | 0.11 | $ | 0.08 | $ | 0.14 | $ | 0.46 | $ | 0.23 | $ | 0.14 | $ | (0.03 | ) | $ | 0.18 | |||||||||||||||||||
| Non-ethane margin ($/gallon) |
$ | 1.03 | $ | 0.89 | $ | 1.03 | $ | 1.09 | $ | 1.01 | $ | 1.10 | $ | 1.04 | $ | 1.00 | $ | 0.69 | $ | 0.96 | ||||||||||||||||||||
| NGL margin ($/gallon) |
$ | 0.79 | $ | 0.73 | $ | 0.75 | $ | 0.81 | $ | 0.77 | $ | 1.02 | $ | 0.82 | $ | 0.68 | $ | 0.59 | $ | 0.77 | ||||||||||||||||||||
| Ethane production (million gallons) |
61 | 61 | 42 | 47 | 211 | 45 | 57 | 60 | 59 | 221 | ||||||||||||||||||||||||||||||
| Non-ethane production (million gallons) |
85 | 91 | 68 | 73 | 317 | 71 | 87 | 92 | 93 | 343 | ||||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| NGL production (million gallons) |
146 | 152 | 110 | 120 | 528 | 116 | 144 | 152 | 152 | 564 | ||||||||||||||||||||||||||||||
| Discovery Producer Services LLC (equity investment) - 100% |
||||||||||||||||||||||||||||||||||||||||
| NGL equity sales (million gallons) |
19 | 18 | 6 | 6 | 49 | 10 | 10 | 18 | 15 | 53 | ||||||||||||||||||||||||||||||
| NGL production (million gallons) |
63 | 64 | 45 | 46 | 218 | 47 | 54 | 65 | 61 | 227 | ||||||||||||||||||||||||||||||
| Transcontinental Gas Pipe Line |
||||||||||||||||||||||||||||||||||||||||
| Throughput (Tbtu) |
845.6 | 713.1 | 756.8 | 837.5 | 3,153.0 | 949.2 | 796.8 | 821.3 | 887.3 | 3,454.6 | ||||||||||||||||||||||||||||||
| Avg. daily transportation volumes (Tbtu) |
9.4 | 7.8 | 8.2 | 9.1 | 8.6 | 10.5 | 8.8 | 8.9 | 9.6 | 9.5 | ||||||||||||||||||||||||||||||
| Avg. daily firm reserved capacity (Tbtu) |
9.3 | 8.9 | 8.8 | 9.3 | 9.1 | 9.6 | 9.4 | 9.5 | 9.9 | 9.6 | ||||||||||||||||||||||||||||||
| * | Excludes volumes associated with partially owned assets that are not consolidated for financial reporting purposes. |
Pre-merger Williams Partners L.P.
West
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Revenues: |
||||||||||||||||||||||||||||||||||||||||
| Fee-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| Gathering & processing |
$ | 134 | $ | 141 | $ | 143 | $ | 144 | $ | 562 | $ | 132 | $ | 141 | $ | 136 | $ | 135 | $ | 544 | ||||||||||||||||||||
| Production handling and transportation |
116 | 110 | 114 | 118 | 458 | 116 | 112 | 113 | 117 | 458 | ||||||||||||||||||||||||||||||
| Other fee revenues |
9 | 9 | 8 | 7 | 33 | 8 | 8 | 8 | 8 | 32 | ||||||||||||||||||||||||||||||
| Commodity-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| NGL sales from gas processing |
142 | 137 | 151 | 128 | 558 | 103 | 95 | 116 | 88 | 402 | ||||||||||||||||||||||||||||||
| Marketing sales |
46 | 46 | 55 | 34 | 181 | 30 | 28 | 29 | 20 | 107 | ||||||||||||||||||||||||||||||
| Other sales |
10 | 7 | 8 | 8 | 33 | 12 | 9 | 10 | 6 | 37 | ||||||||||||||||||||||||||||||
| Tracked revenues |
— | 1 | — | 1 | 2 | — | 1 | — | — | 1 | ||||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| 457 | 451 | 479 | 440 | 1,827 | 401 | 394 | 412 | 374 | 1,581 | |||||||||||||||||||||||||||||||
| Intrasegment eliminations |
— | — | (1 | ) | — | (1 | ) | — | (1 | ) | — | — | (1 | ) | ||||||||||||||||||||||||||
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|||||||||||||||||||||
| Total revenues |
457 | 451 | 478 | 440 | 1,826 | 401 | 393 | 412 | 374 | 1,580 | ||||||||||||||||||||||||||||||
| Segment costs and expenses: |
||||||||||||||||||||||||||||||||||||||||
| NGL cost of goods sold |
44 | 51 | 54 | 40 | 189 | 38 | 35 | 41 | 33 | 147 | ||||||||||||||||||||||||||||||
| Marketing cost of goods sold |
46 | 46 | 55 | 33 | 180 | 30 | 27 | 29 | 19 | 105 | ||||||||||||||||||||||||||||||
| Other cost of goods sold |
4 | 2 | 2 | 3 | 11 | 4 | 6 | 4 | 4 | 18 | ||||||||||||||||||||||||||||||
| Depreciation and amortization expenses |
61 | 58 | 58 | 59 | 236 | 58 | 60 | 60 | 61 | 239 | ||||||||||||||||||||||||||||||
| Other segment costs and expenses |
116 | 131 | 103 | 118 | 468 | 106 | 113 | 103 | 118 | 440 | ||||||||||||||||||||||||||||||
| Tracked costs |
— | 1 | — | 1 | 2 | — | 1 | — | — | 1 | ||||||||||||||||||||||||||||||
| Intrasegment eliminations |
— | — | (1 | ) | — | (1 | ) | — | (1 | ) | — | — | (1 | ) | ||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| Total segment costs and expenses |
271 | 289 | 271 | 254 | 1,085 | 236 | 241 | 237 | 235 | 949 | ||||||||||||||||||||||||||||||
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|||||||||||||||||||||
| Reported segment profit |
186 | 162 | 207 | 186 | 741 | 165 | 152 | 175 | 139 | 631 | ||||||||||||||||||||||||||||||
| Adjustments |
— | — | — | — | — | — | 6 | — | 2 | 8 | ||||||||||||||||||||||||||||||
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|||||||||||||||||||||
| Adjusted segment profit |
$ | 186 | $ | 162 | $ | 207 | $ | 186 | $ | 741 | $ | 165 | $ | 158 | $ | 175 | $ | 141 | $ | 639 | ||||||||||||||||||||
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|||||||||||||||||||||
| Operating statistics |
||||||||||||||||||||||||||||||||||||||||
| Gathering and Processing |
||||||||||||||||||||||||||||||||||||||||
| Gathering volumes (Tbtu) |
240 | 250 | 254 | 244 | 988 | 229 | 230 | 238 | 234 | 931 | ||||||||||||||||||||||||||||||
| Plant inlet natural gas volumes (Tbtu) |
295 | 305 | 310 | 264 | 1,174 | 249 | 246 | 267 | 261 | 1,023 | ||||||||||||||||||||||||||||||
| Ethane equity sales (million gallons) |
15 | 37 | 51 | 12 | 115 | 4 | 5 | 7 | 4 | 20 | ||||||||||||||||||||||||||||||
| Non-ethane equity sales (million gallons) |
102 | 106 | 110 | 89 | 407 | 69 | 71 | 90 | 80 | 310 | ||||||||||||||||||||||||||||||
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|
|||||||||||||||||||||
| NGL equity sales (million gallons) |
117 | 143 | 161 | 101 | 522 | 73 | 76 | 97 | 84 | 330 | ||||||||||||||||||||||||||||||
| Ethane margin ($/gallon) |
$ | (0.03 | ) | $ | (0.01 | ) | $ | (0.02 | ) | $ | (0.00 | ) | $ | (0.02 | ) | $ | 0.12 | $ | 0.22 | $ | 0.21 | $ | 0.17 | $ | 0.19 | |||||||||||||||
| Non-ethane margin ($/gallon) |
$ | 0.96 | $ | 0.81 | $ | 0.89 | $ | 0.99 | $ | 0.91 | $ | 0.94 | $ | 0.84 | $ | 0.81 | $ | 0.66 | $ | 0.81 | ||||||||||||||||||||
| NGL margin ($/gallon) |
$ | 0.83 | $ | 0.60 | $ | 0.61 | $ | 0.86 | $ | 0.71 | $ | 0.89 | $ | 0.80 | $ | 0.77 | $ | 0.64 | $ | 0.77 | ||||||||||||||||||||
| Ethane production (million gallons) |
98 | 124 | 139 | 89 | 450 | 60 | 86 | 64 | 40 | 250 | ||||||||||||||||||||||||||||||
| Non-ethane production (million gallons) |
262 | 281 | 294 | 246 | 1,083 | 233 | 232 | 255 | 245 | 965 | ||||||||||||||||||||||||||||||
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| NGL production (million gallons) |
360 | 405 | 433 | 335 | 1,533 | 293 | 318 | 319 | 285 | 1,215 | ||||||||||||||||||||||||||||||
| Northwest Pipeline LLC |
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| Throughput (Tbtu) |
201.0 | 136.9 | 168.6 | 210.4 | 716.9 | 192.4 | 141.3 | 156.7 | 196.6 | 687.0 | ||||||||||||||||||||||||||||||
| Avg. daily transportation volumes (Tbtu) |
2.2 | 1.5 | 1.8 | 2.3 | 2.0 | 2.1 | 1.6 | 1.7 | 2.1 | 1.9 | ||||||||||||||||||||||||||||||
| Avg. daily firm reserved capacity (Tbtu) |
3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | 3.0 | ||||||||||||||||||||||||||||||
Pre-merger Williams Partners L.P.
NGL & Petchem Services
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Revenues: |
||||||||||||||||||||||||||||||||||||||||
| Fee-based revenues: |
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| Production handling and transportation |
$ | 6 | $ | 6 | $ | 6 | $ | 5 | $ | 23 | $ | 7 | $ | 7 | $ | 7 | $ | 7 | $ | 28 | ||||||||||||||||||||
| Other fee-based revenues |
26 | 31 | 29 | 31 | 117 | 33 | 33 | 33 | 35 | 134 | ||||||||||||||||||||||||||||||
| Commodity-based revenues: |
||||||||||||||||||||||||||||||||||||||||
| NGL sales from gas processing |
37 | 24 | 22 | 28 | 111 | 54 | 32 | 31 | 41 | 158 | ||||||||||||||||||||||||||||||
| Olefin sales |
269 | 228 | 67 | 29 | 593 | 79 | 96 | 73 | 93 | 341 | ||||||||||||||||||||||||||||||
| Marketing sales |
684 | 673 | 645 | 644 | 2,646 | 698 | 680 | 748 | 589 | 2,715 | ||||||||||||||||||||||||||||||
| Other sales |
15 | 11 | 11 | 9 | 46 | 11 | 11 | 8 | 5 | 35 | ||||||||||||||||||||||||||||||
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| 1,037 | 973 | 780 | 746 | 3,536 | 882 | 859 | 900 | 770 | 3,411 | |||||||||||||||||||||||||||||||
| Intrasegment eliminations |
(79 | ) | (80 | ) | (56 | ) | (54 | ) | (269 | ) | (77 | ) | (76 | ) | (72 | ) | (74 | ) | (299 | ) | ||||||||||||||||||||
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| Total revenues |
958 | 893 | 724 | 692 | 3,267 | 805 | 783 | 828 | 696 | 3,112 | ||||||||||||||||||||||||||||||
| Segment costs and expenses: |
||||||||||||||||||||||||||||||||||||||||
| NGL cost of goods sold |
14 | 12 | 9 | 12 | 47 | 28 | 20 | 19 | 23 | 90 | ||||||||||||||||||||||||||||||
| Olefins cost of goods sold |
119 | 111 | 44 | 17 | 291 | 51 | 69 | 46 | 65 | 231 | ||||||||||||||||||||||||||||||
| Marketing cost of goods sold |
679 | 678 | 630 | 638 | 2,625 | 684 | 681 | 752 | 629 | 2,746 | ||||||||||||||||||||||||||||||
| Other cost of goods sold |
13 | 10 | 10 | 7 | 40 | 12 | 10 | 8 | 7 | 37 | ||||||||||||||||||||||||||||||
| Depreciation and amortization expenses |
13 | 14 | 18 | 15 | 60 | 17 | 16 | 17 | 17 | 67 | ||||||||||||||||||||||||||||||
| Net insurance recoveries—Geismar Incident |
— | 6 | (45 | ) | 13 | (26 | ) | (119 | ) | (42 | ) | — | (71 | ) | (232 | ) | ||||||||||||||||||||||||
| Other segment costs and expenses |
46 | 49 | 58 | 39 | 192 | 49 | 53 | 64 | 78 | 244 | ||||||||||||||||||||||||||||||
| Intrasegment eliminations |
(79 | ) | (80 | ) | (56 | ) | (54 | ) | (269 | ) | (77 | ) | (76 | ) | (72 | ) | (74 | ) | (299 | ) | ||||||||||||||||||||
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| Total segment costs and expenses |
805 | 800 | 668 | 687 | 2,960 | 645 | 731 | 834 | 674 | 2,884 | ||||||||||||||||||||||||||||||
| Equity earnings (losses) |
5 | 8 | 12 | 14 | 39 | 7 | 6 | 7 | 17 | 37 | ||||||||||||||||||||||||||||||
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| Reported segment profit |
158 | 101 | 68 | 19 | 346 | 167 | 58 | 1 | 39 | 265 | ||||||||||||||||||||||||||||||
| Adjustments |
— | 6 | (31 | ) | 122 | 97 | 54 | 96 | 5 | (66 | ) | 89 | ||||||||||||||||||||||||||||
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| Adjusted segment profit |
$ | 158 | $ | 107 | $ | 37 | $ | 141 | $ | 443 | $ | 221 | $ | 154 | $ | 6 | $ | (27 | ) | $ | 354 | |||||||||||||||||||
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| Operating statistics |
||||||||||||||||||||||||||||||||||||||||
| Ethane equity sales (million gallons) |
— | — | — | 3 | 3 | 27 | 28 | 28 | 33 | 116 | ||||||||||||||||||||||||||||||
| Non-ethane equity sales (million gallons) |
40 | 29 | 25 | 26 | 120 | 30 | 18 | 19 | 35 | 102 | ||||||||||||||||||||||||||||||
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| NGL equity sales (million gallons) |
40 | 29 | 25 | 29 | 123 | 57 | 46 | 47 | 68 | 218 | ||||||||||||||||||||||||||||||
| Ethane production (million gallons) |
— | — | — | 7 | 7 | 29 | 29 | 29 | 34 | 121 | ||||||||||||||||||||||||||||||
| Non-ethane production (million gallons) |
36 | 35 | 24 | 18 | 113 | 30 | 28 | 28 | 31 | 117 | ||||||||||||||||||||||||||||||
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| NGL production (million gallons) |
36 | 35 | 24 | 25 | 120 | 59 | 57 | 57 | 65 | 238 | ||||||||||||||||||||||||||||||
| Petrochemical Services |
||||||||||||||||||||||||||||||||||||||||
| Geismar ethylene sales volumes (million lbs) |
246 | 211 | 10 | — | 467 | — | — | — | — | — | ||||||||||||||||||||||||||||||
| Geismar ethylene margin ($/lb) |
$ | 0.37 | $ | 0.33 | $ | 0.05 | $ | — | $ | 0.34 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||||||||||
| Canadian propylene sales volumes (millions lbs) |
35 | 36 | 27 | 20 | 118 | 32 | 34 | 34 | 43 | 143 | ||||||||||||||||||||||||||||||
| Canadian alky feedstock sales volumes (million gallons) |
9 | 10 | 7 | 5 | 31 | 7 | 7 | 6 | 7 | 27 | ||||||||||||||||||||||||||||||
| Overland Pass Pipeline Company LLC (equity investment)—100% |
||||||||||||||||||||||||||||||||||||||||
| NGL Transportation volumes (Mbbls) |
7,402 | 11,151 | 13,174 | 11,463 | 43,190 | 8,612 | 8,926 | 9,482 | 10,118 | 37,138 | ||||||||||||||||||||||||||||||
Pre-merger Williams Partners L.P.
Capital Expenditures and Investments
(UNAUDITED)
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) |
1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | ||||||||||||||||||||||||||||||
| Capital expenditures: |
||||||||||||||||||||||||||||||||||||||||
| Northeast G&P |
$ | 307 | $ | 298 | $ | 338 | $ | 407 | $ | 1,350 | $ | 359 | $ | 291 | $ | 288 | $ | 253 | $ | 1,191 | ||||||||||||||||||||
| Atlantic-Gulf |
174 | 276 | 290 | 247 | 987 | 180 | 412 | 319 | 387 | 1,298 | ||||||||||||||||||||||||||||||
| West |
63 | 58 | 55 | 35 | 211 | 22 | 27 | 47 | 48 | 144 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
157 | 158 | 244 | 201 | 760 | 161 | 211 | 136 | 120 | 628 | ||||||||||||||||||||||||||||||
| Other |
2 | 1 | 1 | 4 | 8 | 2 | 2 | 1 | 3 | 8 | ||||||||||||||||||||||||||||||
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| Total* |
$ | 703 | $ | 791 | $ | 928 | $ | 894 | $ | 3,316 | $ | 724 | $ | 943 | $ | 791 | $ | 811 | $ | 3,269 | ||||||||||||||||||||
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| Purchase of businesses: |
||||||||||||||||||||||||||||||||||||||||
| NGL & Petchem Services** |
$ | (25 | ) | $ | — | $ | — | $ | — | $ | (25 | ) | $ | 25 | $ | 31 | $ | — | $ | (56 | ) | $ | — | |||||||||||||||||
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| Purchase of investments: |
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| Northeast G&P |
$ | 72 | $ | 37 | $ | 123 | $ | 1 | $ | 233 | $ | 163 | $ | 6 | $ | 12 | $ | 7 | $ | 188 | ||||||||||||||||||||
| Atlantic-Gulf |
15 | 50 | 35 | 93 | 193 | 51 | 9 | 21 | 25 | 106 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
6 | 2 | 4 | 1 | 13 | 1 | 1 | 1 | 1 | 4 | ||||||||||||||||||||||||||||||
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| Total |
$ | 93 | $ | 89 | $ | 162 | $ | 95 | $ | 439 | $ | 215 | $ | 16 | $ | 34 | $ | 33 | $ | 298 | ||||||||||||||||||||
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| Summary: |
||||||||||||||||||||||||||||||||||||||||
| Northeast G&P |
$ | 379 | $ | 335 | $ | 461 | $ | 408 | $ | 1,583 | $ | 522 | $ | 297 | $ | 300 | $ | 260 | $ | 1,379 | ||||||||||||||||||||
| Atlantic-Gulf |
189 | 326 | 325 | 340 | 1,180 | 231 | 421 | 340 | 412 | 1,404 | ||||||||||||||||||||||||||||||
| West |
63 | 58 | 55 | 35 | 211 | 22 | 27 | 47 | 48 | 144 | ||||||||||||||||||||||||||||||
| NGL & Petchem Services |
138 | 160 | 248 | 202 | 748 | 187 | 243 | 137 | 65 | 632 | ||||||||||||||||||||||||||||||
| Other |
2 | 1 | 1 | 4 | 8 | 2 | 2 | 1 | 3 | 8 | ||||||||||||||||||||||||||||||
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| Total |
$ | 771 | $ | 880 | $ | 1,090 | $ | 989 | $ | 3,730 | $ | 964 | $ | 990 | $ | 825 | $ | 788 | $ | 3,567 | ||||||||||||||||||||
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| Capital expenditures incurred, purchase of businesses, and purchase of investments: |
||||||||||||||||||||||||||||||||||||||||
| Increases to property, plant, and equipment |
$ | 716 | $ | 824 | $ | 968 | $ | 825 | $ | 3,333 | $ | 769 | $ | 867 | $ | 770 | $ | 723 | $ | 3,129 | ||||||||||||||||||||
| Purchase of businesses |
(25 | ) | — | — | — | (25 | ) | 25 | 31 | — | (56 | ) | — | |||||||||||||||||||||||||||
| Purchase of investments |
93 | 89 | 162 | 95 | 439 | 215 | 16 | 34 | 33 | 298 | ||||||||||||||||||||||||||||||
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| Total |
$ | 784 | $ | 913 | $ | 1,130 | $ | 920 | $ | 3,747 | $ | 1,009 | $ | 914 | $ | 804 | $ | 700 | $ | 3,427 | ||||||||||||||||||||
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| *Increases to property, plant, and equipment |
$ | 716 | $ | 824 | $ | 968 | $ | 825 | $ | 3,333 | $ | 769 | $ | 867 | $ | 770 | $ | 723 | $ | 3,129 | ||||||||||||||||||||
| Changes in related accounts payable and accrued liabilities |
(13 | ) | (33 | ) | (40 | ) | 69 | (17 | ) | (45 | ) | 76 | 21 | 88 | 140 | |||||||||||||||||||||||||
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| Capital expenditures |
$ | 703 | $ | 791 | $ | 928 | $ | 894 | $ | 3,316 | $ | 724 | $ | 943 | $ | 791 | $ | 811 | $ | 3,269 | ||||||||||||||||||||
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|||||||||||||||||||||
| ** | The first quarter of 2013 relates to a working capital adjustment associated with the acquisition of the olefins business from a subsidiary of Williams and the 2014 amounts relate to adjustments from the acquisition of certain Canadian operations from a subsidiary of Williams. |
WPZ Net Income to Adjusted EBITDA
| 2015 | 2016 | 2017 | ||||||||||||||||||||||||||||||||||
| (‘$ in millions) |
Low | Base | High | Low | Base | High | Low | Base | High | |||||||||||||||||||||||||||
| Net income from continuing operations |
$ | 1,555 | $ | 1,720 | $ | 1,885 | $ | 2,025 | $ | 2,225 | $ | 2,425 | $ | 2,465 | $ | 2,690 | $ | 2,915 | ||||||||||||||||||
| Add: Net interest expense |
855 | 855 | 855 | 965 | 960 | 955 | 1,075 | 1,065 | 1,055 | |||||||||||||||||||||||||||
| Add: Provision for income taxes |
15 | 15 | 15 | 25 | 25 | 25 | 25 | 25 | 25 | |||||||||||||||||||||||||||
| Add: Depreciation & amortization (DD&A) |
1,705 | 1,705 | 1,705 | 1,800 | 1,800 | 1,800 | 1,875 | 1,875 | 1,875 | |||||||||||||||||||||||||||
| Less: Equity earnings from investments |
(380 | ) | (385 | ) | (390 | ) | (495 | ) | (505 | ) | (515 | ) | (645 | ) | (660 | ) | (675 | ) | ||||||||||||||||||
| Add: Proportionate share of EBITDA from investments1 |
665 | 670 | 675 | 800 | 810 | 820 | 955 | 970 | 985 | |||||||||||||||||||||||||||
| Adjustments2 |
(115 | ) | (115 | ) | (115 | ) | — | — | — | — | — | — | ||||||||||||||||||||||||
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| Adjusted EBITDA |
$ | 4,300 | $ | 4,465 | $ | 4,630 | $ | 5,120 | $ | 5,315 | $ | 5,510 | $ | 5,750 | $ | 5,965 | $ | 6,180 | ||||||||||||||||||
| 2015 | 2016 | 2017 | ||||||||||||||||||||||||||||||||||
| 1) Proportionate Share of EBITDA from investments: |
Low | Base | High | Low | Base | High | Low | Base | High | |||||||||||||||||||||||||||
| Net income from continuing operations |
$ | 380 | $ | 385 | $ | 390 | $ | 495 | $ | 505 | $ | 515 | $ | 645 | $ | 660 | $ | 675 | ||||||||||||||||||
| Add: Net interest expense |
53 | 53 | 53 | 58 | 58 | 58 | 61 | 61 | 61 | |||||||||||||||||||||||||||
| Add: Depreciation & amortization (DD&A) |
206 | 206 | 206 | 226 | 226 | 226 | 236 | 236 | 236 | |||||||||||||||||||||||||||
| Other |
26 | 26 | 26 | 21 | 21 | 21 | 13 | 13 | 13 | |||||||||||||||||||||||||||
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| Adjusted EBITDA from Equity Investments |
$ | 665 | $ | 670 | $ | 675 | $ | 800 | $ | 810 | $ | 820 | $ | 955 | $ | 970 | $ | 985 | ||||||||||||||||||
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| 2015 | 2016 | 2017 | ||||||||||||||||||||||||||||||||||
| 2) Adjustments: |
Low | Base | High | Low | Base | High | Low | Base | High | |||||||||||||||||||||||||||
| Geismar incident adjustment for insurance and timing |
($ | 150 | ) | ($ | 150 | ) | ($ | 150 | ) | — | — | — | — | — | — | |||||||||||||||||||||
| ACMP acquisition-related expenses |
35 | 35 | 35 | — | — | — | — | — | — | |||||||||||||||||||||||||||
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|||||||||||||||||||
| Total Adjustments |
($ | 115 | ) | ($ | 115 | ) | ($ | 115 | ) | — | — | — | — | — | — | |||||||||||||||||||||
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WPZ Distributable Cash Flow and Cash Distribution Coverage Ratio
| 2015 | 2016 | 2017 | ||||||||||||||||||||||||||||||||||
| Dollars in millions, except per L.P. unit |
Low | Base | High | Low | Base | High | Low | Base | High | |||||||||||||||||||||||||||
| Adjusted EBITDA1 |
$ | 4,300 | $ | 4,465 | $ | 4,630 | $ | 5,120 | $ | 5,315 | $ | 5,510 | $ | 5,750 | $ | 5,965 | $ | 6,180 | ||||||||||||||||||
| Less: Maintenance Capex2 |
(430 | ) | (430 | ) | (430 | ) | (440 | ) | (440 | ) | (440 | ) | (440 | ) | (440 | ) | (440 | ) | ||||||||||||||||||
| Less: Interest Expense (cash portion)3 |
(885 | ) | (885 | ) | (885 | ) | (1,000 | ) | (995 | ) | (990 | ) | (1,110 | ) | (1,100 | ) | (1,090 | ) | ||||||||||||||||||
| Less: Cash Taxes |
(5 | ) | (5 | ) | (5 | ) | (10 | ) | (10 | ) | (10 | ) | (10 | ) | (10 | ) | (10 | ) | ||||||||||||||||||
| Less: Noncontrolling Interests |
(135 | ) | (135 | ) | (135 | ) | (195 | ) | (195 | ) | (195 | ) | (230 | ) | (230 | ) | (230 | ) | ||||||||||||||||||
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| Distributable Cash Flow Attributable to Partnership Operations |
$ | 2,845 | $ | 3,010 | $ | 3,175 | $ | 3,475 | $ | 3,675 | $ | 3,875 | $ | 3,960 | $ | 4,185 | $ | 4,410 | ||||||||||||||||||
| Cash Distributions (accrued) |
$ | 3,010 | $ | 3,005 | $ | 2,995 | $ | 3,380 | $ | 3,440 | $ | 3,515 | $ | 3,770 | $ | 3,925 | $ | 4,090 | ||||||||||||||||||
| —per L.P. Unit |
$ | 3.40 | $ | 3.40 | $ | 3.40 | $ | 3.64 | $ | 3.71 | $ | 3.78 | $ | 3.89 | $ | 4.04 | $ | 4.19 | ||||||||||||||||||
| —Annual growth rate |
7 | % | 9 | % | 11 | % | 7 | % | 9 | % | 11 | % | ||||||||||||||||||||||||
| Cash Distribution Coverage Ratio |
0.95x | 1.00x | 1.06x | 1.03x | 1.07x | 1.10x | 1.05x | 1.07x | 1.08x | |||||||||||||||||||||||||||
Notes: 1 A more detailed schedule reconciling this non-GAAP measure is provided in this presentation. 2 Includes proportionate share of maintenance capex of equity investments 3 Includes proportionate share of interest expense of equity investments