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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K

CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
May 9, 2018
Date of Report (Date of earliest event reported)
 
ENERGY TRANSFER PARTNERS, L.P.
(Exact name of Registrant as specified in its charter)
 
 
 
Delaware
1-31219
73-1493906
(State or other jurisdiction of incorporation)
(Commission File Number)
(IRS Employer Identification No.)

8111 Westchester Drive, Suite 600,
Dallas, Texas 75225
(Address of principal executive offices) (Zip Code)

(214) 981-0700
(Registrant’s telephone number, including area code)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
¨
Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
¨
Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
¨
Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
¨
Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company  ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨





Item 2.02. Results of Operations and Financial Condition.
On May 9, 2018, Energy Transfer Partners, L.P. issued a press release announcing its financial and operating results for the first quarter ended March 31, 2018. A copy of this press release is furnished as Exhibit 99.1 to this report and is incorporated herein by reference.
In accordance with General Instruction B.2 of Form 8-K, the information set forth in this Item 2.02 and in the attached exhibit shall be deemed to be “furnished” and not be deemed to be “filed” for purposes of the Securities Exchange Act of 1934, as amended (the “Exchange Act”).
Item 9.01. Financial Statements and Exhibits.
(d) Exhibits. In accordance with General Instruction B.2 of Form 8-K, the information set forth in the attached Exhibit 99.1 is deemed to be “furnished” and shall not be deemed to be “filed” for purposes of Section 18 of the Exchange Act.
Exhibit Number
 
Description of the Exhibit
 




SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
 
 
ENERGY TRANSFER PARTNERS, L.P.
 
 
 
 
 
 
By:
Energy Transfer Partners GP, L.P.
 
 
 
its General Partner
 
 
 
 
 
 
By:
Energy Transfer Partners, L.L.C.
 
 
 
its General Partner
 
 
 
 
Date:
May 9, 2018
By:
/s/ Thomas E. Long
 
 
 
Thomas E. Long
 
 
 
Chief Financial Officer



Exhibit


https://cdn.kscope.io/23528304a9e274625b09979d06d33035-etplogoa01a01a26.jpg
ENERGY TRANSFER PARTNERS
REPORTS FIRST QUARTER RESULTS
Dallas – May 9, 2018 – Energy Transfer Partners, L.P. (NYSE: ETP) (“ETP” or the “Partnership”) today reported its financial results for the quarter ended March 31, 2018. For the three months ended March 31, 2018, net income was $879 million and Adjusted EBITDA was $1.88 billion. Adjusted EBITDA increased $436 million compared to the three months ended March 31, 2017, reflecting an increase of $277 million in Adjusted EBITDA from the crude oil transportation and services segment, as well as higher results from several of the other segments, as discussed in the segment results analysis below. Net income increased $486 million compared to the three months ended March 31, 2017, primarily due to increased operating income in addition to a $172 million pre-tax gain on Sunoco LP units that were repurchased by Sunoco LP from ETP in February 2018. Distributable Cash Flow attributable to partners, as adjusted, for the three months ended March 31, 2018 totaled $1.22 billion, an increase of $278 million compared to the three months ended March 31, 2017, primarily due to the increase in Adjusted EBITDA.
ETP’s other recent key accomplishments include the following:
•
In May 2018, ETP announced the formation of a joint venture to resume service on the Old Ocean natural gas pipeline and expand its jointly owned North Texas 36-inch pipeline that will provide more capacity from West Texas for deliveries into the Old Ocean Pipeline.
•
In May 2018, ETP announced the receipt of approval to place a portion of Phase 2 of the Rover pipeline in service, allowing for the full commercial operation capability of the Market Zone North Segment.
•
In April 2018, ETP completed the previously announced contribution transaction of certain compression assets to USA Compression Partners, LP for an aggregate consideration of $1.7 billion, consisting of $1.23 billion in cash and the remaining in equity.
•
In April 2018, ETP issued 18 million of its 7.375% Series C Preferred Units at a price of $25 per unit, resulting in total gross proceeds of $450 million.
•
In April 2018, ETP announced a quarterly distribution of $0.565 per unit ($2.260 annualized) on ETP common units for the quarter ended March 31, 2018.
•
In March 2018, ETP announced the formation of a joint venture, Orbit Gulf Coast NGL Exports, LLC, with Satellite Petrochemical USA Corp. (“Satellite”), with the purpose of constructing a new export terminal on the United States Gulf Coast to provide ethane to Satellite for consumption at their ethane cracking facilities in China. Subject to Chinese Governmental approval, it is anticipated that the Orbit export terminal will be ready for commercial service in the fourth quarter of 2020.
•
In February 2018, after the record date for Sunoco LP’s fourth quarter 2017 cash distributions, Sunoco LP repurchased approximately 17.3 million Sunoco LP common units owned by ETP for proceeds of approximately $540 million.  
•
As of March 31, 2018, ETP’s $5.00 billion revolving credit facilities had $2.76 billion of outstanding borrowings, and its leverage ratio, as defined by the credit agreement, was 3.89x.
An analysis of ETP’s segment results and other supplementary data is provided after the financial tables shown below. ETP has scheduled a conference call for 8:00 a.m. Central Time, Thursday, May 10, 2018 to discuss the first quarter 2018 results. The conference call will be broadcast live via an internet webcast, which can be accessed through www.energytransfer.com and will also be available for replay on ETP’s website for a limited time.
Energy Transfer Partners, L.P. (NYSE: ETP) is a master limited partnership that owns and operates one of the largest and most diversified portfolios of energy assets in the United States. Strategically positioned in all of the major U.S. production basins, ETP owns and operates a geographically diverse portfolio of complementary natural gas midstream, intrastate and interstate transportation and storage assets; crude oil, natural gas liquids (NGL) and refined product transportation and terminalling assets; NGL fractionation; and various acquisition and marketing assets.  ETP’s general partner is owned by Energy Transfer Equity, L.P. (NYSE: ETE). For more information, visit the Energy Transfer Partners, L.P. website at www.energytransfer.com.
Energy Transfer Equity, L.P. (NYSE: ETE) is a master limited partnership that owns the general partner and 100% of the incentive distribution rights (IDRs) of Energy Transfer Partners, L.P. (NYSE: ETP) and Sunoco LP (NYSE: SUN).  ETE also

1


owns Lake Charles LNG Company and the general partner of USA Compression Partners, LP (NYSE: USAC). On a consolidated basis, ETE’s family of companies owns and operates a diverse portfolio of natural gas, natural gas liquids, crude oil and refined products assets, as well as retail and wholesale motor fuel operations and LNG terminalling. For more information, visit the Energy Transfer Equity, L.P. website at www.energytransfer.com.
Forward-Looking Statements
This news release may include certain statements concerning expectations for the future that are forward-looking statements as defined by federal law. Such forward-looking statements are subject to a variety of known and unknown risks, uncertainties, and other factors that are difficult to predict and many of which are beyond management’s control. An extensive list of factors that can affect future results are discussed in the Partnership’s Annual Report on Form 10-K and other documents filed from time to time with the Securities and Exchange Commission. The Partnership undertakes no obligation to update or revise any forward-looking statement to reflect new information or events.
The information contained in this press release is available on our website at www.energytransfer.com.
Contacts
Energy Transfer
Investor Relations:
Lyndsay Hannah, Brent Ratliff, Helen Ryoo, 214-981-0795
or
Media Relations:
Vicki Granado, 214-840-5820

2


ENERGY TRANSFER PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In millions)
(unaudited)
 
March 31,
2018
 
December 31, 2017
ASSETS
 
 
 
 
 
 
 
Current assets
$
5,748

 
$
6,528

 
 
 
 
Property, plant and equipment, net
59,373

 
58,437

 
 
 
 
Advances to and investments in unconsolidated affiliates
3,258

 
3,816

Other non-current assets, net
758

 
758

Intangible assets, net
5,243

 
5,311

Goodwill
3,115

 
3,115

Total assets
$
77,495

 
$
77,965

LIABILITIES AND EQUITY
 
 
 
 
 
 
 
Current liabilities
$
6,223

 
$
6,994

 
 
 
 
Long-term debt, less current maturities
33,109

 
32,687

Non-current derivative liabilities
97

 
145

Deferred income taxes
2,860

 
2,883

Other non-current liabilities
1,100

 
1,084

 
 
 
 
Commitments and contingencies
 
 
 
Redeemable noncontrolling interests
21

 
21

 
 
 
 
Equity:
 
 
 
Total partners’ capital
27,999

 
28,269

Noncontrolling interest
6,086

 
5,882

Total equity
34,085

 
34,151

Total liabilities and equity
$
77,495

 
$
77,965


3


ENERGY TRANSFER PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per unit data)
(unaudited)
 
Three Months Ended
March 31,
 
2018
 
2017 (a)
REVENUES
$
8,280

 
$
6,895

COSTS AND EXPENSES:
 
 
 
Cost of products sold
5,988

 
5,050

Operating expenses
604

 
492

Depreciation, depletion and amortization
603

 
560

Selling, general and administrative
112

 
110

Total costs and expenses
7,307

 
6,212

OPERATING INCOME
973

 
683

OTHER INCOME (EXPENSE):
 
 
 
Interest expense, net
(346
)
 
(332
)
Equity in earnings (losses) of unconsolidated affiliates
(72
)
 
73

Gain on Sunoco LP common unit repurchase
172

 
—

Gains on interest rate derivatives
52

 
5

Other, net
60

 
19

INCOME BEFORE INCOME TAX EXPENSE (BENEFIT)
839

 
448

Income tax expense (benefit)
(40
)
 
55

NET INCOME
879

 
393

Less: Net income attributable to noncontrolling interest
164

 
62

NET INCOME ATTRIBUTABLE TO PARTNERS
715

 
331

General Partner’s interest in net income
402

 
206

Series A Preferred Unitholders’ interest in net income
15

 
—

Series B Preferred Unitholders’ interest in net income
9

 
—

Class H Unitholder’s interest in net income
—

 
93

Common Unitholders’ interest in net income
$
289

 
$
32

NET INCOME PER COMMON UNIT:
 
 
 
Basic
$
0.24

 
$
0.03

Diluted
$
0.24

 
$
0.03

WEIGHTED AVERAGE NUMBER OF COMMON UNITS OUTSTANDING:
 
 
 
Basic
1,163.8

 
822.3

Diluted
1,167.8

 
824.5

(a)
During the fourth quarter of 2017, the Partnership changed its accounting policy related to certain inventories. Certain crude oil, refined product and NGL inventories associated with the legacy Sunoco Logistics business were changed from the LIFO method to the weighted average cost method. These changes have been applied retrospectively to all periods presented, and the prior period amounts reflected below have been adjusted from those amounts previously reported. Certain other prior period amounts have also been reclassified to conform to the current period presentation, including a reclassification between capitalized interest and AFUDC from the three months ended March 31, 2017.

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SUPPLEMENTAL INFORMATION
(Dollars and units in millions)
(unaudited)
 
Three Months Ended
March 31,
 
2018
 
2017 (a)(b)
Reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow (c):
 
 
 
Net income
$
879

 
$
393

Interest expense, net
346

 
332

Income tax expense (benefit)
(40
)
 
55

Depreciation, depletion and amortization
603

 
560

Non-cash compensation expense
20

 
23

Gains on interest rate derivatives
(52
)
 
(5
)
Unrealized (gains) losses on commodity risk management activities
87

 
(64
)
Gain on Sunoco LP common unit repurchase
(172
)
 
—

Equity in (earnings) losses of unconsolidated affiliates
72

 
(73
)
Adjusted EBITDA related to unconsolidated affiliates
185

 
239

Other, net
(47
)
 
(15
)
Adjusted EBITDA (consolidated)
1,881

 
1,445

Adjusted EBITDA related to unconsolidated affiliates
(185
)
 
(239
)
Distributable cash flow from unconsolidated affiliates
125

 
144

Interest expense, net
(346
)
 
(332
)
Preferred unitholders’ distributions
(24
)
 
—

Current income tax expense
—

 
(1
)
Maintenance capital expenditures
(88
)
 
(60
)
Other, net
3

 
15

Distributable Cash Flow (consolidated)
1,366

 
972

Distributable Cash Flow attributable to PennTex Midstream Partners, LP (“PennTex”) (100%) (d)
—

 
(19
)
Distributions from PennTex to ETP (d)
—

 
8

Distributable cash flow attributable to noncontrolling interest in other consolidated subsidiaries
(147
)
 
(23
)
Distributable Cash Flow attributable to the partners of ETP
1,219

 
938

Transaction-related expenses
4

 
7

Distributable Cash Flow attributable to the partners of ETP, as adjusted
$
1,223

 
$
945

 
 
 
 
Distributions to partners:
 
 
 
Limited Partners:
 
 
 
Common Units held by public
$
642

 
$
567

Common Units held by parent
16

 
15

General Partner interests and Incentive Distribution Rights (“IDRs”) held by parent
449

 
381

IDR relinquishments
(42
)
 
(157
)
Total distributions to be paid to partners
$
1,065

 
$
806

Common Units outstanding – end of period (e)
1,164.0

 
1,084.6

Distribution coverage ratio (f)
1.15x

 
1.17x


5


(a)
For the three months ended March 31, 2017, the calculation of Distributable Cash Flow and the amounts reflected for distributions to partners and common units outstanding reflect the pro forma impacts of the Sunoco Logistics Merger as though the merger had occurred on January 1, 2017. As a result, the prior period amounts reported above differ from information previously reported by legacy ETP, as follows:
•
Distributable cash flow attributable to the partners of ETP includes amounts attributable to the partners of both legacy ETP and legacy Sunoco Logistics. Previously, the calculation of distributable cash flow attributable to the partners of ETP (as previously reported by legacy ETP) excluded the distributable cash flow attributable to Sunoco Logistics and only included distributions from legacy Sunoco Logistics to legacy ETP.
•
Distributable cash flow attributable to noncontrolling interest in other consolidated subsidiaries includes amounts attributable to the noncontrolling interests in the other consolidated subsidiaries of both legacy ETP and legacy Sunoco Logistics.
•
The transaction-related expenses adjustment in distributable cash flow attributable to the partners of ETP, as adjusted, includes amounts incurred by both legacy ETP and legacy Sunoco Logistics.
•
Distributions to limited partners include distributions paid on the common units of both legacy ETP and legacy Sunoco Logistics but exclude the following distributions in the prior periods on units that were cancelled in the merger, which comprise the following: (i) distributions paid by legacy Sunoco Logistics on its common units held legacy ETP and (ii) distributions paid by legacy ETP on its Class H units held by ETE.
•
Distributions on General Partner interests and incentive distribution rights are reflected on a pro forma basis, based on the pro forma cash distributions to limited partners and the current distribution waterfall per the limited partnership agreement (i.e., the legacy Sunoco Logistics distribution waterfall).
•
Common units outstanding for the pre-merger periods reflect (i) the legacy ETP common units outstanding at the end of the period multiplied by a factor of 1.5x and (ii) the legacy Sunoco Logistics common units outstanding at the end of the period minus 67.1 million legacy Sunoco Logistics common units held by ETP, which were cancelled in connection with the closing of the merger.
(b)
During the fourth quarter of 2017, the Partnership changed its accounting policy related to certain inventories. Certain crude oil, refined product and NGL inventories associated with the legacy Sunoco Logistics business were changed from the LIFO method to the weighted average cost method. These changes have been applied retrospectively to all periods presented, and the prior period amounts reflected below have been adjusted from those amounts previously reported. Certain other prior period amounts have also been reclassified to conform to the current period presentation, including a reclassification between capitalized interest and AFUDC from the three months ended March 31, 2017.
(c)
Adjusted EBITDA and Distributable Cash Flow are non-GAAP financial measures used by industry analysts, investors, lenders, and rating agencies to assess the financial performance and the operating results of ETP’s fundamental business activities and should not be considered in isolation or as a substitute for net income, income from operations, cash flows from operating activities, or other GAAP measures.
There are material limitations to using measures such as Adjusted EBITDA and Distributable Cash Flow, including the difficulty associated with using either as the sole measure to compare the results of one company to another, and the inability to analyze certain significant items that directly affect a company’s net income or loss or cash flows. In addition, our calculations of Adjusted EBITDA and Distributable Cash Flow may not be consistent with similarly titled measures of other companies and should be viewed in conjunction with measurements that are computed in accordance with GAAP, such as segment margin, operating income, net income, and cash flow from operating activities.
Definition of Adjusted EBITDA
We define Adjusted EBITDA as total partnership earnings before interest, taxes, depreciation, depletion, amortization and other non-cash items, such as non-cash compensation expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, non-cash impairment charges, losses on extinguishments of debt and other non-operating income or expense items. Unrealized gains and losses on commodity risk management activities include unrealized gains and losses on commodity derivatives and inventory fair value adjustments. Adjusted EBITDA reflects amounts for less than wholly-owned subsidiaries based on 100% of the subsidiaries’ results of operations and for unconsolidated affiliates based on our proportionate ownership.
Adjusted EBITDA is used by management to determine our operating performance and, along with other financial and volumetric data, as internal measures for setting annual operating budgets, assessing financial performance of our numerous

6


business locations, as a measure for evaluating targeted businesses for acquisition and as a measurement component of incentive compensation.
Definition of Distributable Cash Flow
We define Distributable Cash Flow as net income, adjusted for certain non-cash items, less maintenance capital expenditures. Non-cash items include depreciation, depletion and amortization, non-cash compensation expense, amortization included in interest expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, non-cash impairment charges, losses on extinguishments of debt and deferred income taxes. Unrealized gains and losses on commodity risk management activities includes unrealized gains and losses on commodity derivatives and inventory fair value adjustments (excluding lower of cost or market adjustments). For unconsolidated affiliates, Distributable Cash Flow reflects the Partnership’s proportionate share of the investee’s distributable cash flow.
Distributable Cash Flow is used by management to evaluate our overall performance. Our partnership agreement requires us to distribute all available cash, and Distributable Cash Flow is calculated to evaluate our ability to fund distributions through cash generated by our operations.
On a consolidated basis, Distributable Cash Flow includes 100% of the Distributable Cash Flow of ETP’s consolidated subsidiaries. However, to the extent that noncontrolling interests exist among our subsidiaries, the Distributable Cash Flow generated by our subsidiaries may not be available to be distributed to our partners. In order to reflect the cash flows available for distributions to our partners, we have reported Distributable Cash Flow attributable to partners, which is calculated by adjusting Distributable Cash Flow (consolidated), as follows:
•
For subsidiaries with publicly traded equity interests, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiary, and Distributable Cash Flow attributable to our partners includes distributions to be received by the parent company with respect to the periods presented.
•
For consolidated joint ventures or similar entities, where the noncontrolling interest is not publicly traded, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiary, but Distributable Cash Flow attributable to partners is net of distributions to be paid by the subsidiary to the noncontrolling interests.
For Distributable Cash Flow attributable to partners, as adjusted, certain transaction-related and non-recurring expenses that are included in net income are excluded.
(d)
Beginning with the second quarter of 2017, PennTex became a wholly-owned subsidiary of ETP.  The amounts reflected above for PennTex relate only to the first quarter of 2017, and no distributable cash flow has been attributed to noncontrolling interests in PennTex subsequent to March 31, 2017.
(e)
For the three months ended March 31, 2017, reflects the sum of (i) the ETP Common Units outstanding at the end of period multiplied by a factor of 1.5x and (ii) the Sunoco Logistics Common Units outstanding at end of period minus 67.1 million Sunoco Logistics Common Units held by ETP, which units were cancelled in connection with the closing of the merger.
(f)
Distribution coverage ratio for a period is calculated as Distributable Cash Flow attributable to partners, as adjusted, divided by net distributions expected to be paid to the partners of ETP in respect of such period.

7


SUMMARY ANALYSIS OF QUARTERLY RESULTS BY SEGMENT
(Tabular dollar amounts in millions)
(unaudited)
 
Three Months Ended
March 31,
 
2018
 
2017
Segment Adjusted EBITDA:
 
 
 
Intrastate transportation and storage
$
192

 
$
169

Interstate transportation and storage
323

 
265

Midstream
377

 
320

NGL and refined products transportation and services (1)
451

 
381

Crude oil transportation and services (1)
464

 
187

All other
74

 
123

 
$
1,881

 
$
1,445

(1) 
Subsequent to the Sunoco Logistics Merger, the Partnership’s reportable segments were revised. Amounts reflected in prior periods have been retrospectively adjusted to conform to the current reportable segment presentation for NGL and refined products transportation and services and crude oil transportation and services.
In the following analysis of segment operating results, a measure of segment margin is reported for segments with sales revenues. Segment Margin is a non-GAAP financial measure and is presented herein to assist in the analysis of segment operating results and particularly to facilitate an understanding of the impacts that changes in sales revenues have on the segment performance measure of Segment Adjusted EBITDA. Segment Margin is similar to the GAAP measure of gross margin, except that Segment Margin excludes charges for depreciation, depletion and amortization.
In addition, for certain segments, the sections below include information on the components of Segment Margin by sales type, which components are included in order to provide additional disaggregated information to facilitate the analysis of Segment Margin and Segment Adjusted EBITDA. For example, these components include transportation margin, storage margin, and other margin. These components of Segment Margin are calculated consistent with the calculation of Segment Margin; therefore, these components also exclude charges for depreciation, depletion and amortization.
For prior periods reported herein, certain transactions related to the business of legacy Sunoco Logistics have been reclassified from cost of products sold to operating expenses; these transactions include sales between operating subsidiaries and their marketing affiliates. These reclassifications had no impact on net income or total equity.

8


Following is a reconciliation of segment margin to operating income, as reported in the Partnership’s consolidated statements of operations:
 
Three Months Ended
March 31,
 
2018
 
2017
Intrastate transportation and storage
$
171

 
$
182

Interstate transportation and storage
316

 
235

Midstream
553

 
513

NGL and refined products transportation and services
600

 
559

Crude oil transportation and services
568

 
272

All other
95

 
102

Intersegment eliminations
(11
)
 
(18
)
Total segment margin
2,292

 
1,845

 
 
 
 
Less:
 
 
 
Operating expenses
604

 
492

Depreciation, depletion and amortization
603

 
560

Selling, general and administrative
112

 
110

Operating income
$
973

 
$
683

Intrastate Transportation and Storage
 
Three Months Ended
March 31,
 
2018
 
2017
Natural gas transported (BBtu/d)
9,271

 
7,870

Withdrawals from storage natural gas inventory (BBtu)
17,703

 
23,093

Revenues
$
875

 
$
816

Cost of products sold
704

 
634

Segment margin
171

 
182

Unrealized losses on commodity risk management activities
53

 
15

Operating expenses, excluding non-cash compensation expense
(39
)
 
(38
)
Selling, general and administrative expenses, excluding non-cash compensation expense
(6
)
 
(6
)
Adjusted EBITDA related to unconsolidated affiliates
13

 
16

Segment Adjusted EBITDA
$
192

 
$
169

Transported volumes increased primarily due to higher demand for exports to Mexico, the addition of new pipelines and more favorable market pricing.
Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our intrastate transportation and storage segment increased due to the net impacts of the following:
•
an increase of $58 million in realized natural gas sales and other due to higher realized gains from pipeline optimization activity; offset by
•
a decrease of $24 million in realized storage margin primarily due to an adjustment to the Bammel storage inventory;
•
a decrease of $7 million in transportation fees due to renegotiated contracts resulting in lower billed volumes;
•
an increase of $1 million in operating expenses primarily due to higher expense projects; and
•
a decrease of $3 million in Adjusted EBITDA related to unconsolidated affiliates primarily due to a decrease of $3 million from lower demand volumes related to renegotiation of a contract and a decrease of $3 million due to a reserve recorded in

9


the prior period pursuant to the bankruptcy filing of a transport customer, partially offset by an increase of $3 million related to two new joint venture pipelines placed in service in 2017.
Interstate Transportation and Storage
 
Three Months Ended
March 31,
 
2018
 
2017
Natural gas transported (BBtu/d)
8,204

 
5,656

Natural gas sold (BBtu/d)
17

 
17

Revenues
$
316

 
$
235

Operating expenses, excluding non-cash compensation, amortization and accretion expenses
(94
)
 
(74
)
Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses
(17
)
 
(12
)
Adjusted EBITDA related to unconsolidated affiliates
116

 
115

Other
2

 
1

Segment Adjusted EBITDA
$
323

 
$
265

Transported volumes reflected an increase of 1,470 BBtu/d as a result of the partial in service of the Rover pipeline, an increase of 444 BBtu/d on the Tiger pipeline as a result of production increases in the Haynesville Shale and deliveries into third party storage and the intrastate markets, and an increase of 402 BBtu/d and 229 BBtu/d on the Panhandle and Trunkline pipelines, respectively, resulting from higher demand due to colder weather.
Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our interstate transportation and storage segment increased due to the net effect of the following:
•
an increase of $49 million due to the partial in service of the Rover pipeline which reflected increases of $82 million in revenues, $26 million in operating expenses and $7 million in general and administrative expenses;
•
a decrease of $6 million in operating expenses, excluding the incremental expenses related to the Rover pipeline discussed above, primarily due to lower allocated costs, reduction in project maintenance work and lower transportation and storage related expenses; and
•
a decrease of $2 million in general and administrative expenses, excluding the incremental expenses related to the Rover pipeline discussed above, primarily due to lower allocated costs and insurance reserves.

10


Midstream
 
Three Months Ended
March 31,
 
2018
 
2017
Gathered volumes (BBtu/d)
11,306

 
10,232

NGLs produced (MBbls/d)
503

 
445

Equity NGLs (MBbls/d)
28

 
26

Revenues
$
1,614

 
$
1,637

Cost of products sold
1,061

 
1,124

Segment margin
553

 
513

Unrealized gains on commodity risk management activities
—

 
(16
)
Operating expenses, excluding non-cash compensation expense
(164
)
 
(161
)
Selling, general and administrative expenses, excluding non-cash compensation expense
(20
)
 
(23
)
Adjusted EBITDA related to unconsolidated affiliates
7

 
7

Other
1

 
—

Segment Adjusted EBITDA
$
377

 
$
320

Gathered volumes and NGL production increased primarily due to increases in the Permian and Northeast regions, partially offset by basin declines in the Ark-La-Tex, North Texas and Mid-Continent/Panhandle regions.
Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our midstream segment increased due to the net effects of the following:
•
an increase of $27 million in non fee-based margin due to increased throughput volumes in the Permian and South Texas regions;
•
an increase of $16 million in non fee-based margin due to an $11 million increase resulting from higher crude and NGL prices and a $5 million increase in settled price risk management activity;
•
an increase of $13 million in fee-based revenue due to growth in the Permian and Northeast regions, offset by declines in Ark-La-Tex, North Texas and the Mid-Continent/Panhandle regions; and
•
a decrease of $3 million in selling, general and administrative expenses due to lower employee costs and professional fees; offset by
•
an increase of $3 million in operating expenses primarily due to an increase of $2 million in employee costs and an increase of $1 million in ad valorem taxes.

11


NGL and Refined Products Transportation and Services
 
Three Months Ended
March 31,
 
2018
 
2017
NGL transportation volumes (MBbls/d)
936

 
816

Refined products transportation volumes (MBbls/d)
620

 
624

NGL and refined products terminal volumes (MBbls/d)
702

 
790

NGL fractionation volumes (MBbls/d)
472

 
433

Revenues
$
2,546

 
$
2,266

Cost of products sold
1,946

 
1,707

Segment margin
600

 
559

Unrealized gains on commodity risk management activities
(13
)
 
(50
)
Operating expenses, excluding non-cash compensation expense
(139
)
 
(127
)
Selling, general and administrative expenses, excluding non-cash compensation expense
(18
)
 
(19
)
Adjusted EBITDA related to unconsolidated affiliates
21

 
17

Other
—

 
1

Segment Adjusted EBITDA
$
451

 
$
381

NGL transportation volumes increased primarily from the Permian region, Mariner West pipeline and Mariner South pipeline, partially offset by decreased throughput volumes on Mariner East I due to system downtime in March 2018. Refined products transportation volumes decreased slightly primarily due to lower throughput volumes from the Midwest and Northeast regions, partially offset by increased throughput volumes from the Southwest region.
NGL and refined products terminal volumes decreased primarily due to the sale of one of our refined product marketing terminals in April 2017, lower volumes loaded for export at our Nederland terminal and lower throughput volumes at our Marcus Hook Industrial Complex due to system downtime on our Mariner East I pipeline in March 2018.
Average fractionated volumes at our Mont Belvieu, Texas fractionation facility increased 11% primarily due to increased volumes from Permian producers.
Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our NGL and refined products transportation and services segment increased due to net impact of the following:
•
an increase of $33 million in transportation margin due to a $33 million increase resulting from increased producer volumes from the Permian region on our Texas NGL pipelines and a $6 million increase due to higher throughput on Mariner West driven by end user facility constraints in the prior period. These increases were offset by a $6 million decrease resulting from lower throughput on Mariner East I due to system downtime in March 2018;
•
an increase of $25 million in marketing margin due to gains of $9 million from optimizing sales of purity product from our Mont Belvieu fractionators, as well as an $8 million increase from our butane blending operations and an $8 million increase from sales of domestic propane and other products at our Marcus Hook Industrial Complex;
•
an increase of $14 million in fractionation and refinery services margin primarily due to an $8 million increase resulting from higher NGL volumes from the Permian region feeding our Mont Belvieu fractionation facility and a $7 million increase from blending gains as a result of improved market pricing;
•
an increase of $7 million in terminal services margin due to a $10 million increase resulting from a change in the classification of certain customer reimbursements previously recorded in operating expenses that are now classified as revenue following the adoption of ASC 606 on January 1, 2018. This increase was offset by a $3 million decrease from our marketing terminal volumes primarily due to the sale of one of our terminals in April 2017; and
•
an increase of $4 million in Adjusted EBITDA related to unconsolidated affiliates primarily due to annual true-up payments from one of our unconsolidated refined product pipelines recorded in January 2018; offset by
•
an increase of $12 million in operating expenses primarily due to a change in the classification of certain customer reimbursements previously recorded in operating expenses that are now classified as revenue following the adoption of ASC 606 on January 1, 2018.

12


Crude Oil Transportation and Services
 
Three Months Ended
March 31,
 
2018
 
2017
Crude transportation volumes (MBbls/d)
3,827

 
3,042

Crude terminals volumes (MBbls/d)
1,940

 
1,777

Revenues
$
3,745

 
$
2,575

Cost of products sold
3,177

 
2,303

Segment margin
568

 
272

Unrealized losses on commodity risk management activities
43

 
—

Operating expenses, excluding non-cash compensation expense
(127
)
 
(72
)
Selling, general and administrative expenses, excluding non-cash compensation expense
(22
)
 
(17
)
Adjusted EBITDA related to unconsolidated affiliates
2

 
4

Segment Adjusted EBITDA
$
464

 
$
187

Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our crude oil transportation and services segment increased due to the following:
•
an increase of $339 million in segment margin (excluding unrealized losses on commodity risk management activities) due to a $222 million increase resulting primarily from placing our Bakken pipeline in service in the second quarter of 2017 as well as a $25 million increase resulting from increased throughput, primarily from Permian producers, on existing pipeline assets; an $85 million increase (excluding $43 million in unrealized losses on commodity risk management activities) from our crude oil acquisition and marketing business primarily resulting from more favorable market price differentials between the West Texas and Gulf Coast markets; and a $7 million increase from higher ship loading and throughput fees at our Nederland terminal due to an increase in exports; offset by
•
an increase of $55 million in operating expenses primarily due to a $26 million increase resulting from placing our Bakken pipeline in service in the second quarter of 2017; a $12 million increase resulting from the addition of certain joint venture crude transportation assets in the second quarter of 2017; and a $15 million increase from existing transportation assets mainly due to higher ad valorem taxes, management fees and pipeline loss allowance; and
•
an increase of $5 million in selling, general and administrative expenses due primarily to insurance and Bakken management fees.
All Other
 
Three Months Ended
March 31,
 
2018
 
2017
Revenues
$
571

 
$
770

Cost of products sold
476

 
668

Segment margin
95

 
102

Unrealized (gains) losses on commodity risk management activities
4

 
(13
)
Operating expenses, excluding non-cash compensation expense
(31
)
 
(21
)
Selling, general and administrative expenses, excluding non-cash compensation expense
(18
)
 
(21
)
Adjusted EBITDA related to unconsolidated affiliates
26

 
80

Other and eliminations
(2
)
 
(4
)
Segment Adjusted EBITDA
$
74

 
$
123

Amounts reflected in our all other segment primarily include:
•
our equity method investment in limited partnership units of Sunoco LP consisting of 26.2 million and 43.5 million units, representing 31.8% and 43.7% of Sunoco LP’s total outstanding common units as of March 31, 2018 and March 31, 2017, respectively;

13


•
our natural gas marketing and compression operations;
•
a non-controlling interest in PES, comprising 33% of PES’ outstanding common units; and
•
our investment in coal handling facilities.
Segment Adjusted EBITDA. For the three months ended March 31, 2018 compared to the same period last year, Segment Adjusted EBITDA related to our all other segment decreased primarily due to the net impact of the following:
•
a decrease of $54 million in Adjusted EBITDA related to unconsolidated affiliates, primarily reflecting a decrease of $30 million from our investment in PES due to lower earnings and a decrease of $25 million from our investment in Sunoco LP primarily due to Sunoco LP’s sale of retail assets, as well as a decrease in our ownership interest in Sunoco LP subsequent to the repurchase of common units by Sunoco LP in February 2018;
•
an increase of $10 million in operating expenses primarily attributable to an increase of $8 million in the compression business; offset by
•
an increase of $11 million from commodity trading activities; and
•
a decrease of $3 million in selling, general and administrative expenses due to lower merger and acquisition costs.

14


SUPPLEMENTAL INFORMATION ON LIQUIDITY
(In millions)
(unaudited)
 
Facility Size
 
Funds Available at March 31, 2018
 
Maturity Date
ETP Five-Year Revolving Credit Facility
$
4,000

 
$
1,089

 
December 1, 2022
ETP 364-Day Revolving Credit Facility
1,000

 
1,000

 
November 30, 2018
 
$
5,000

 
$
2,089

 
 

15


SUPPLEMENTAL INFORMATION ON UNCONSOLIDATED AFFILIATES
(In millions)
(unaudited)
 
Three Months Ended
March 31,
 
2018
 
2017
Equity in earnings (losses) of unconsolidated affiliates:
 
 
 
Citrus
$
27

 
$
21

FEP
14

 
12

MEP
9

 
10

HPC
3

 
7

Sunoco LP
(151
)
 
(14
)
Other
26

 
37

Total equity in earnings (losses) of unconsolidated affiliates
$
(72
)
 
$
73

 
 
 
 
Adjusted EBITDA related to unconsolidated affiliates:
 
 
 
Citrus
$
75

 
$
75

FEP
19

 
18

MEP
22

 
22

HPC
9

 
15

Sunoco LP
29

 
54

Other
31

 
55

Total Adjusted EBITDA related to unconsolidated affiliates
$
185

 
$
239

 
 
 
 
Distributions received from unconsolidated affiliates:
 
 
 
Citrus
$
46

 
$
41

FEP
17

 
—

MEP
13

 
73

Sunoco LP
36

 
35

Other
21

 
23

Total distributions received from unconsolidated affiliates
$
133

 
$
172


16