WPZ
$41.00
Williams Partners LP
($.12)
(.29%)
Earnings Details
1st Quarter March 2017
Wednesday, May 03, 2017 4:15:26 PM
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Summary

Williams Partners LP (WPZ) Recent Earnings

Williams Partners LP (WPZ) reported 1st Quarter March 2017 earnings of $0.68 per share on revenue of $2.0 billion. The consensus earnings estimate was $0.35 per share. Revenue grew 19.9% on a year-over-year basis.

Williams Partners LP is an energy infrastructure company. It owns and operates midstream gathering and processing assets, and interstate natural gas pipelines.

Results
Reported Earnings
$0.68
Earnings Whisper
-
Consensus Estimate
$0.35
Reported Revenue
$1.98 Bil
Revenue Estimate
Growth
Earnings Growth
Revenue Growth
Power Rating
Grade
Earnings Release

Williams Partners Reports First-Quarter 2017 Financial Results

1Q 2017 Adjusted EBITDA of $1.117 Billion, Up 5.4%

--Cash Distribution Coverage Ratio of 1.33x

Announced Agreement to Sell Its Interests in Geismar Plant for $2.1 Billion and to Provide Feedstock to Plant Buyer via Long-Term Supply and Transportation Agreements

--Williams Partners Analyst Day Set for May 11

Williams Partners L.P. (WPZ) today announced its financial results for the three months ended March 31, 2017.

Summary Financial Information
1Q
Amounts in millions, except per-unit amounts. Per-unit amounts
2017
2016
are reported on a diluted basis. All amounts are attributable to
Williams Partners L.P.
(Unaudited)
GAAP Measures
Net income (loss)
$
634
$
50
Net income (loss) per common unit
$
0.68
($0.25 )
Cash Flow from Operations
$
731
$
924
Non-GAAP Measures (1)
Adjusted EBITDA
$ 1,117
$
1,060
DCF attributable to partnership operations
$
752
$
739
Cash distribution coverage ratio
1.33x
1.02x
(1) Adjusted EBITDA, distributable cash flow (DCF) and cash
distribution coverage ratio are non-GAAP measures. Reconciliations
to the most relevant measures included in GAAP are attached to this
news release.

First-Quarter 2017 Financial Results

Williams Partners reported unaudited first-quarter 2017 net income attributable to controlling interests of $634 million, a $584 million increase over first-quarter 2016. The favorable change was driven by a $271 million increase in investing income, primarily associated with a transaction involving certain joint-venture interests, as well as a $141 million improvement in operating income and the absence of $112 million of impairments of equity-method investments in 2016.

Williams Partners reported first-quarter 2017 Cash Flow from Operations (CFFO) of $731 million, a $193 million decrease from first-quarter 2016. The decrease from the prior year is driven by the absence of $198 million of cash received in 2016 associated with minimum volume commitments, which were replaced by contract restructurings that occurred in the latter part of 2016. The prior year also included $80 million of cash received as a milestone payment associated with Transco’s Hillabee expansion project. These unfavorable changes in CFFO were partially offset by improved operating results.

Williams Partners reported first-quarter 2017 Adjusted EBITDA of $1.117 billion, a $57 million increase over first-quarter 2016. The increase is due primarily to $37 million higher commodity margins and $30 million lower operating and maintenance (O&M) and selling, general and administrative (SG&A) expenses, and a $16 million favorable change in other income and expense primarily related to our former Canadian operations which were sold in September 2016. Partially offsetting these increases was a $30 million decrease in fee-revenues due primarily to lower West segment results, partially offset by increases in the Atlantic-Gulf segment.

Distributable Cash Flow and Distributions

For first-quarter 2017, Williams Partners generated $752 million in distributable cash flow (DCF) attributable to partnership operations, compared with $739 million in DCF attributable to partnership operations for first-quarter 2016. The increase is due primarily to the previously described improvement in the quarter’s Adjusted EBITDA and $17 million lower interest expense. DCF has been reduced by $58 million for the planned removal of non-cash deferred revenue amortization associated with the fourth-quarter 2016 contract restructuring in the Barnett Shale and Mid-Continent region. For first-quarter 2017, the cash distribution coverage ratio was 1.33x.

Williams Partners recently announced a regular quarterly cash distribution of $0.60 per unit, payable May 12, 2017 to its common unitholders of record at the close of business on May 5, 2017.

CEO Perspective

Alan Armstrong, chief executive officer of Williams Partners’ general partner, made the following comments:

"We continue to differentiate ourselves with a focused strategy on natural gas infrastructure in support of consistent and sustainable growth in gas volumes. We continue to deliver top quartile EBITDA growth among our peers as we increased year-over-year Adjusted EBITDA for the 14th quarter in a row. This quarter, our growth was delivered despite some significant impacts from third-party outages and more extreme weather in the Rockies area, proving once again the resiliency of our business model.

"Our project teams continued to deliver as we brought on the 1.2 Bcf/D Gulf Trace project ahead of schedule and under budget. That is just one of five Transco pipeline system expansions that we expect to place in service in 2017. Our successful 2016 work to bring the Gunflint and Kodiak tiebacks in service was showcased this quarter by Atlantic-Gulf’s higher volumes and higher fee-based revenues. And our backlog of projects continues to grow as we had a very successful Southeastern Trail open season in the quarter as well.

"We continue to strengthen our foundation for long-term, sustainable growth in our core business, as highlighted by the recently announced agreement to sell our interests in the Geismar olefins facility while gaining a new third party fee-based revenue stream for our Bayou Ethane system. With the expected sale of Geismar, and the sale of our Canadian business in late 2016, we’ll realize around 97 percent of our gross margins coming from predictable, fee-based sources.

"Our consolidation of operating areas from five to three became effective in first-quarter 2017 - not only streamlining our organization, but helping us continue the cost-savings momentum we began in the second quarter of last year. We expect to realize further cost savings through the consolidation of offices and systems."

Business Segment Results

Effective, Jan. 1, 2017, Williams Partners implemented certain changes in its reporting segments as part of an operational realignment. As a result beginning with the reporting of first-quarter 2017 financial results, Williams Partners operations will be comprised of the following reportable segments: Atlantic-Gulf, West, Northeast G&P, and NGL & Petchem Services.

Williams Partners
Modified and Adjusted EBITDA
Amounts in millions
1Q 2017
1Q 2017
1Q 2016
1Q 2016
Modified
Adjust.
Adjusted
Modified
Adjust.
Adjusted
EBITDA
EBITDA
EBITDA
EBITDA
Atlantic-Gulf
$
450
$
3
$
453
$
382
$
23
$
405
West
385
4
389
327
73
400
Northeast G&P
226
1
227
220
5
225
NGL & Petchem Services
51
(2 )
49
26
4
30
Other
20
(21 )
(1 )
-
-
-
Total
$ 1,132
($15 )
$ 1,117
$
955
$ 105
$ 1,060
Definitions of modified EBITDA and adjusted EBITDA and schedules
reconciling these measures to net income are included in this news
release.

Atlantic-Gulf

This segment includes the partnership’s interstate natural gas pipeline, Transco, and significant natural gas gathering and processing and crude oil production handling and transportation assets in the Gulf Coast region, including a 51 percent interest in Gulfstar One (a consolidated entity), which is a proprietary floating production system, and various petrochemical and feedstock pipelines in the Gulf Coast region, as well as a 50 percent equity-method investment in Gulfstream, a 41 percent interest in Constitution (a consolidated entity) which is under development, and a 60 percent equity-method investment in Discovery.

The Atlantic-Gulf segment reported Modified EBITDA of $450 million for first-quarter 2017, compared with $382 million for first-quarter 2016. Adjusted EBITDA increased by $48 million to $453 million for the same time period. The increase in both measures was driven primarily by higher fee-based revenues due primarily to contributions from offshore expansion projects completed during 2016 and new Transco projects Rock Springs (in service in August 2016) and Gulf Trace (in service in February 2017). Also contributing to the increase in both measures were $12 million improved commodity margins. Partially offsetting these increases were increased O&M expenses due primarily to higher costs associated with Transco’s integrity and pipeline maintenance program.

West

This segment includes the partnership’s interstate natural gas pipeline, Northwest Pipeline, and natural gas gathering, processing, and treating operations in New Mexico, Colorado, and Wyoming, as well as the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, the Haynesville Shale region of northwest Louisiana, and the Mid-Continent region which includes the Anadarko, Arkoma, Delaware and Permian basins. This reporting segment also includes an NGL and natural gas marketing business, storage facilities, and undivided 50 percent interest in an NGL fractionator near Conway, Kansas, and a 50 percent equity-method investment in OPPL. The partnership completed the disposal of its 50 percent equity-method investment in a Delaware Basin gas gathering system in the Mid-Continent region during first-quarter 2017.

The West segment reported Modified EBITDA of $385 million for first-quarter 2017, compared with $327 million for first-quarter 2016. Adjusted EBITDA of $389 million is $11 million lower than the same period in 2016. The increase in Modified EBITDA was driven primarily by $35 million lower O&M and SG&A expenses and $21 million higher commodity margins. The Adjusted EBITDA decrease was due primarily to $57 million lower fee-based revenues including $25 million lower fee-based revenues in the Barnett from lower volumes and contract changes that occurred during 2016. Fee-based revenues were also impacted by more extreme weather in 2017.

Northeast G&P

This segment includes the partnership’s natural gas gathering and processing, compression and NGL fractionation businesses in the Marcellus Shale region primarily in Pennsylvania, New York, and West Virginia and Utica Shale region of eastern Ohio, as well as a 66 percent interest in Cardinal (a consolidated entity), a 62 percent equity-method investment in UEOM, a 69 percent equity-method investment in Laurel Mountain, a 58 percent equity-method investment in Caiman II, and Appalachia Midstream Services, LLC, which owns an approximate average 66 percent equity-method investment in multiple gas gathering systems in the Marcellus Shale (Appalachia Midstream Investments).

The Northeast G&P segment reported Modified EBITDA of $226 million for first-quarter 2017, compared with $220 million for first-quarter 2016. Adjusted EBITDA increased $2 million to $227 million. The increase in both measures was due primarily to lower SG&A expenses. Fee-based revenues and proportional EBITDA from joint ventures were stable between the two periods due to increases in the Bradford, Susquehanna and Ohio River systems that offset decreases in the Utica.

NGL & Petchem Services

This segment includes the partnership’s 88.46 percent undivided interest in an olefins production facility in Geismar, Louisiana, along with a refinery grade propylene splitter. On April 17, 2017, the partnership announced an agreement to sell the subsidiary that owns its interests in the Geismar olefins production facility. Prior to September 2016, this reporting segment also included an oil sands offgas processing plant near Fort McMurray, Alberta, and an NGL/olefin fractionation facility, which were subsequently sold.

The NGL & Petchem Services segment reported Modified EBITDA of $51 million for first-quarter 2017, compared with $26 million for first-quarter 2016. Adjusted EBITDA increased by $19 million to $49 million. The increase in both measures was due primarily to a favorable change in other income and expense related to our former Canadian operations, which were sold in September 2016. Additionally, lower O&M and SG&A expenses positively impacted the quarter. Ethylene margins were stable between the two periods due to favorable 2017 per-unit ethylene margins offsetting lower 2017 production volumes caused by an unexpected power outage and related repair activities. The unplanned shutdown and subsequent repair work resulted in the Geismar olefins plant being offline from March 12 until restarting on April 18, 2017. For first-quarter 2017, the Geismar plant contributed approximately $37 million in Adjusted EBITDA.

Notable Recent Events

On March 30, 2017, Williams Partners announced that it had completed separate transactions with Western Gas Partners, LP (WES) ("Western Gas"), Anadarko Petroleum Corporation (APC) ("Anadarko"), and Energy Transfer Partners, L.P. (ETP) ("Energy Transfer"), and certain of their respective affiliates, for an aggregate cash consideration of $200 million paid to Williams Partners and an increase in Williams Partners’ ownership in two Marcellus shale gathering systems, in exchange for Williams Partners’ assignment of interests in certain non-operated Delaware Basin assets.

On April 17, 2017, Williams Partners announced that it has agreed to sell 100 percent of its membership interests in Williams Olefins LLC, which owns an 88.46 percent undivided ownership interest in the Geismar, Louisiana, olefins plant and associated complex, to NOVA Chemicals for $2.1 billion in cash. The transaction is expected to close in summer 2017. Closing is subject to customary closing conditions and regulatory approvals. Additionally, upon closing of the transaction, Williams Partners subsidiaries will enter into long-term supply and transportation agreements with NOVA Chemicals to provide feedstock to the Geismar olefins plant via Williams Partners’ ethane pipeline system in the U.S. Gulf Coast. These agreements will secure a meaningful long-term fee-based revenue stream for the partnership.

Williams Partners, Williams Analyst Day Set for May 11

Williams Partners and Williams are scheduled to host their 2017 Analyst Day event May 11. During the event, Williams’ management will give in-depth presentations covering all of the partnership’s and company’s energy infrastructure businesses and update certain aspects of its financial guidance. This year’s Analyst Day meeting is scheduled from approximately 8:00 a.m. to 2:00 p.m. EDT.

Presentation slides along with a link to the live webcast will be accessible at www.williams.com the morning of May 11. A replay of the Analyst Day webcast will be available on the website for at least 90 days following the event.

Williams Partners’ First-Quarter 2017 Materials to be Posted Shortly; Q&A Webcast Scheduled for Tomorrow

Williams Partners’ first-quarter 2017 financial results package will be posted shortly at www.williams.com. The materials will include the analyst package.

Williams Partners and Williams will host a joint Q&A live webcast on Thursday, May 4 at 9:30 a.m. EDT. A limited number of phone lines will be available at (877) 741-4253. International callers should dial (719) 325-4783. The conference ID is 2089672. A link to the webcast, as well as replays of the webcast, will be available for at least 90 days following the event at www.williams.com.

Form 10-Q

The partnership plans to file its first-quarter 2017 Form 10-Q with the Securities and Exchange Commission (SEC) this week. Once filed, the document will be available on both the SEC and Williams Partners websites.

Definitions of Non-GAAP Measures

This news release may include certain financial measures - Adjusted EBITDA, distributable cash flow and cash distribution coverage ratio - that are non-GAAP financial measures as defined under the rules of the SEC.

Our segment performance measure, Modified EBITDA, is defined as net income (loss) before income tax expense, net interest expense, equity earnings from equity-method investments, other net investing income, impairments of equity investments and goodwill, depreciation and amortization expense, and accretion expense associated with asset retirement obligations for nonregulated operations. We also add our proportional ownership share (based on ownership interest) of Modified EBITDA of equity-method investments.

Adjusted EBITDA further excludes items of income or loss that we characterize as unrepresentative of our ongoing operations. Management believes these measures provide investors meaningful insight into results from ongoing operations.

We define distributable cash flow as Adjusted EBITDA less maintenance capital expenditures, cash portion of interest expense, income attributable to noncontrolling interests and cash income taxes, plus WPZ restricted stock unit non-cash compensation expense and certain other adjustments that management believes affects the comparability of results. Adjustments for maintenance capital expenditures and cash portion of interest expense include our proportionate share of these items of our equity-method investments.

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 using the most directly comparable GAAP measure, net income (loss).

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 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

Williams Partners is an industry-leading, large-cap natural gas infrastructure master limited partnership with a strong growth outlook and major positions in key U.S. supply basins. 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 - providing natural gas for clean-power generation, heating and industrial use. Williams Partners’ operations touch approximately 30 percent of U.S. natural gas. Tulsa, Okla.-based Williams (WMB), a premier provider of large-scale U.S. natural gas infrastructure, owns approximately 74 percent of Williams Partners.

Forward-Looking Statements

The reports, filings, and other public announcements of 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 (Securities Act) and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters.

All statements, other than statements of historical facts, included in this report that address activities, events or developments that we expect, believe or anticipate will exist or may occur in the future, are forward-looking statements. Forward-looking statements can be identified 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 to limited partner interests;

-- Our and our affiliates’ future credit ratings;

-- 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;

-- 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 report. 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 we will produce sufficient cash flows to provide the level of cash distributions that Williams expects;

-- Whether we elect to pay expected levels of cash distributions;

Whether we will be able to effectively execute our financing plan including the receipt of anticipated levels of proceeds from planned asset sales;

Whether Williams will be able to effectively manage the transition in its board of directors and management as well as successfully execute its business restructuring;

Availability of supplies, including lower than anticipated volumes from third parties served by our midstream business, and market demand;

Volatility of pricing including the effect of lower than anticipated energy commodity prices and margins;

Inflation, interest 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 timely execute our capital projects and other investment opportunities in accordance with our forecasted capital expenditures budget;

-- Our ability to successfully expand our facilities and operations;

-- Development of alternative energy sources;

The impact of operational and developmental hazards, unforeseen interruptions, and the availability of adequate coverage for such interruptions;

The impact of existing and future laws, regulations, the regulatory environment, environmental liabilities, and litigation as well as our ability to obtain permits and achieve favorable rate proceeding outcomes;

Williams’ costs and funding obligations for defined benefit pension plans and other postretirement benefit plans;

Our allocated costs for defined benefit pension plans and other postretirement benefit plans sponsored by our 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 and physical damage to our facilities;

Acts of terrorism, including cybersecurity threats and related disruptions;

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 and referred to below may cause our intentions to change from those statements of intention set forth in this report. 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.

Limited partner units are inherently different from the capital stock of a corporation, although many of the business risks to which we are subject are similar to those that would be faced by a corporation engaged in a similar business. You should carefully consider the risk factors discussed above in addition to the other information in this report. If any of such risks were actually to occur, our business, results of operations, and financial condition could be materially adversely affected. In that case, we might not be able to pay distributions on our common units, the trading price of our common units could decline, and unitholders could lose all or part of their investment.

Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K filed with the SEC on Feb. 22, 2017.

Williams Partners L.P.
Reconciliation of Non-GAAP Measures
(UNAUDITED)(UNAUDITED)
2016
2017
(Dollars in millions, except coverage ratios)
1st Qtr
2nd Qtr
3rd Qtr
4th Qtr
Year
1st Qtr
Williams Partners L.P.
Reconciliation of GAAP "Net Income (Loss)" to Non-GAAP
"Modified EBITDA," "Adjusted EBITDA," and "Distributable cash flow"
Net income (loss)
$
79
$
(77 )
$
351
$
166
$
519
$
660
Provision (benefit) for income taxes
1
(80 )
(6 )
5
(80 )
3
Interest expense
229
231
229
227
916
214
Equity (earnings) losses
(97 )
(101 )
(104 )
(95 )
(397 )
(107 )
Impairment of equity-method investments
112
--
--
318
430
--
Other investing (income) loss
--
(1 )
(28 )
--
(29 )
(271 )
Proportional Modified EBITDA of equity-method investments
189
191
194
180
754
194
Depreciation and amortization expenses
435
432
426
427
1,720
433
7
9
8
7
31
6
Accretion for asset retirement obligations associated with
nonregulated operations
Modified EBITDA
955
604
1,070
1,235
3,864
1,132
Adjustments
Estimated minimum volume commitments
60
64
70
(194 )
--
15
Severance and related costs
25
--
--
12
37
9
Potential rate refunds associated with rate case litigation
15
--
--
--
15
--
Merger and transition related expenses
5
--
--
--
5
--
Constitution Pipeline project development costs
--
8
11
9
28
2
Share of impairment at equity-method investment
--
--
6
19
25
--
Geismar Incident adjustment for insurance and timing
--
--
--
(7 )
(7 )
(9 )
Impairment of certain assets
--
389
--
22
411
--
Organizational realignment-related costs
--
--
--
24
24
4
Loss related to Canada disposition
--
--
32
2
34
(3 )
Gain on asset retirement
--
--
--
(11 )
(11 )
--
Gains from contract settlements and terminations
--
--
--
--
--
(13 )
Accrual for loss contingency
--
--
--
--
--
9
Gain on early retirement of debt
--
--
--
--
--
(30 )
Expenses associated with strategic asset monetizations
--
--
--
2
2
1
Total EBITDA adjustments
105
461
119
(122 )
563
(15 )
Adjusted EBITDA
1,060
1,065
1,189
1,113
4,427
1,117
Maintenance capital expenditures (1)
(58 )
(75 )
(121 )
(147 )
(401 )
(53 )
Interest expense (cash portion) (2)
(241 )
(245 )
(244 )
(239 )
(969 )
(224 )
Cash taxes
--
--
--
(3 )
(3 )
(5 )
Income attributable to noncontrolling interests (3)
(29 )
(13 )
(31 )
(27 )
(100 )
(27 )
WPZ restricted stock unit non-cash compensation
7
5
2
2
16
2
Amortization of deferred revenue associated with certain 2016
--
--
--
--
--
(58 )
contract restructurings
Distributable cash flow attributable to Partnership Operations (4)
739
737
795
699
2,970
752
Total cash distributed (5)
$
725
$
725
$
734
$
762
$
2,946
$
567
Coverage ratios:
Distributable cash flow attributable to partnership operations
1.02
1.02
1.08
0.92
1.01
1.33
divided by Total cash distributed
Net income (loss) divided by Total cash distributed
0.11
(0.11 )
0.48
0.22
0.18
1.16
Notes:
(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)
The fourth quarter of 2016 includes income of $183 million
associated with proceeds from the contract restructuring in the
Barnett Shale and Mid-Continent region as the cash was received
during 2016.
(5)
In order to exclude the impact of the IDR waiver associated with the
WPZ merger termination fee from the determination of coverage
ratios, cash distributions have been increased by $10 million in the
first quarter of 2016. Cash distributions for the third quarter of
2016 have been increased to exclude the impact of the $150 million
IDR waiver associated with the sale of our Canadian operations. Cash
distributions for the fourth quarter of 2016 and the first quarter
of 2017 have been decreased by $50 million and $6 million,
respectively, to reflect the amount paid by WMB to WPZ pursuant to
the January 2017 Common Unit Purchase Agreement.
Williams Partners L.P.
Reconciliation of Non-GAAP "Modified EBITDA" to Non-GAAP
"Adjusted EBITDA"
(UNAUDITED)
2016*
2017
(Dollars in millions)
1st Qtr
2nd Qtr
3rd Qtr
4th Qtr
Year
1st Qtr
Modified EBITDA:
Northeast G&P
$
220
$
222
$
214
$
197
$
853
$
226
Atlantic-Gulf
382
360
423
456
1,621
450
West
327
312
363
542
1,544
385
NGL & Petchem Services
26
(290 )
70
49
(145 )
51
Other
--
--
--
(9 )
(9 )
20
Total Modified EBITDA
$
955
$
604
$
1,070
$
1,235
$
3,864
$
1,132
Adjustments:
Northeast G&P
Severance and related costs
$
3
$ --
$ --
$ --
$
3
$ --
Share of impairment at equity-method investments
--
--
6
19
25
--
ACMP Merger and transition costs
2
--
--
--
2
--
Organizational realignment-related costs
--
--
--
3
3
1
Total Northeast G&P adjustments
5
--
6
22
33
1
Atlantic-Gulf
Potential rate refunds associated with rate case litigation
15
--
--
--
15
--
Severance and related costs
8
--
--
--
8
--
Constitution Pipeline project development costs
--
8
11
9
28
2
Organizational realignment-related costs
--
--
--
--
--
1
Gain on asset retirement
--
--
--
(11 )
(11 )
--
Total Atlantic-Gulf adjustments
23
8
11
(2 )
40
3
West
Estimated minimum volume commitments
60
64
70
(194 )
--
15
Severance and related costs
10
--
--
3
13
--
ACMP Merger and transition costs
3
--
--
--
3
--
Impairment of certain assets
--
48
--
22
70
--
Organizational realignment-related costs
--
--
--
21
21
2
--
--
--
--
--
(13 )
Gains from contract settlements and terminations
Total West adjustments
73
112
70
(148 )
107
4
NGL & Petchem Services
Impairment of certain assets
--
341
--
--
341
--
Loss related to Canada disposition
--
--
32
2
34
(3 )
Severance and related costs
4
--
--
--
4
--
Expenses associated with strategic asset monetizations
--
--
--
2
2
1
Geismar Incident adjustment for insurance and timing
--
--
--
(7 )
(7 )
(9 )
Accrual for loss contingency
--
--
--
--
--
9
Total NGL & Petchem Services adjustments
4
341
32
(3 )
374
(2 )
Other
Severance and related costs
--
--
--
9
9
9
Gain on early retirement of debt
--
--
--
--
--
(30 )
Total Other adjustments
--
--
--
9
9
(21 )
Total Adjustments
$
105
$
461
$
119
$
(122 )
$
563
$
(15 )
Adjusted EBITDA:
Northeast G&P
$
225
$
222
$
220
$
219
$
886
$
227
Atlantic-Gulf
405
368
434
454
1,661
453
West
400
424
433
394
1,651
389
NGL & Petchem Services
30
51
102
46
229
49
Other
--
--
--
--
--
(1 )
Total Adjusted EBITDA
$
1,060
$
1,065
$
1,189
$
1,113
$
4,427
$
1,117
* Recast due to the change in WPZ segments in the first
quarter of 2017.

http://cts.businesswire.com/ct/CT?id=bwnews&sty=20170503006480r1&sid=cmtx6&distro=nx&lang=en

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SOURCE: Williams Partners L.P.

Williams Partners L.P.
Media Contact:
Keith Isbell, 918-573-7308
or
Investor Contacts:
John Porter, 918-573-0797
or
Brett Krieg, 918-573-4614