A Closer Look at Energy Transfer Partners’ Distributable Cash Flow as of 3Q 2012

by Ron Hiram
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Submitted by Ron Hiram of Wise Analysis using our Trefis Contributors tool.

On November 7, 2012, Energy Transfer Partners, L.P. (ETP) reported results of operations for 3Q 2012. I usually prefer to review trailing 12-months data but in this case 9-month data will have to suffice because restated prior data is available only for the quarter and 9-month period ending 9/30/11. Restatement was required because in October 2012, ETP sold ETC Canyon Pipeline, LLC (“Canyon”) for ~$207 million and reclassified Canyon’s results for the three and nine months ended September 30, 2012, as discontinued operations. Prior year amounts were accordingly restated and a $145 million non-cash write-down of the Canyon assets was recorded during the three months ended September 30, 2012. Note that the propane business is not considered a discontinued operation. It was contributed by ETP to AmeriGas Partners, L.P. (APU) in January 2012 in return for ~$1.46 billion in cash and ~29.6 million APU units (which ETP is obligated to hold until January 2013). Its results are accounted for under the equity method, similarly to the manner in which ETP accounts for its 50% interest in the Fayetteville Express Pipeline (“FEP”) and 50% interest in Citrus Corp. (“Citrus”) which owns the FGT natural gas pipeline.

The acquisition of Sunoco, Inc. (SUN) pursuant to which SUN shareholders received ~55 million ETP units plus $2.6 billion in cash was completed on October 5, 2012, and is therefore not yet reflected in ETP’s 3Q12 financials.

Revenues, operating income, net income and earnings before interest, depreciation & amortization and income tax expenses (“EBITDA”) are summarized in Table 1 below:

Period: 3Q12 3Q11 9M 

9/30/12

9M 9/30/11
Revenues:
Natural gas sales 603 680 1,481 1,963
NGL sales 327 333 1,012 757
Gathering, transportation and other fees 399 392 1,162 1,095
Retail propane sales 0 213 87 962
Other 91 83 199 217
Total revenues 1,420 1,701 3,941 4,994
Operating income 292 274 838 910
Net income from continuing operations 193 78 1,446 484
Net income from discontinued operations (147) (2) (150) (5)
Net income 46 76 1,296 480
EBITDA 254 311 384 461
Adjusted EBITDA 482 404 1,484 1,264
Weighted average units outstanding (million) 246 209 235 205

Table 1: Figures in $ Millions except units outstanding

Segment contribution to Adjusted EBITDA was as follows:

Period: 3Q12 3Q11 9M 

9/30/12

9M 9/30/11
Intrastate transportation and storage 121 170 470 515
Interstate transportation 204 102 502 266
Midstream 105 103 299 274
NGL transportation and services 36 31 111 55
Retail propane and other related 4 (4) 94 151
All other 11 2 8 3
Total Segment Adjusted EBITDA 482 404 1,484 1,264

Table 2: Figures in $ Millions

The lower Adjusted EBITDA levels at the Intrastate Transportation and Storage segment reflect lower transportation volumes and lower gross margins.

The higher Adjusted EBITDA levels at the Interstate Transportation segment reflect increase in transported volumes, primarily due to the Tiger pipeline expansion, and contributions from unconsolidated affiliates that began in 2012. Specifically, in the 9 months ending 9/30/12 the 50% ownership stake in Citrus contributed $162.2 million and the 50% interest in FEP contributed $21.1 million to Adjusted EBITDA.

Higher transportation volumes, higher gross margins improved the year-to-date Adjusted EBITDA numbers for the Midstream segment.

The increase in NGL Transportation and Services segment Adjusted EBITDA primarily reflect a full nine months of activity for the Lone Star JV compared to only five months of activity in 2011

In an article titled Distributable Cash Flow (“DCF”) I present the definition of DCF used by ETP and provide a comparison to definitions used by other MLPs. Using ETP’s definition, DCF for the 9 months period ending 9/30/12 was $3.98 per unit ($935 million), down from $4.03 per unit ($827 million) for the comparable prior year period. As always, I first attempt to assess how these figures compare with what I call sustainable DCF for these periods and whether distributions were funded by additional debt or issuing additional units.

The generic reasons why DCF as reported by the MLP may differs from call sustainable DCF are reviewed in an article titled “Estimating sustainable DCF-why and how”. Applying the method described there to ETP results through 9/30/12 generates the comparison outlined in Table 3 below:

9 months ending: 9/30/12 9/30/11
Net cash provided by operating activities 938 1,030
Less: Maintenance capital expenditures (81) (81)
Less: Working capital (generated) (60) (195)
Add: Distributions from unconsolidated affiliates in excess of cumulative earnings 95 16
Sustainable DCF 892 770
Risk management activities 68 63
Other (24) (7)
DCF as reported 935 827

Table 3: Figures in $ Millions

Some distributions from unconsolidated affiliates appear in the cash flow statement as cash provided by operating activities while others appear under cash from investing activities. I did not see an explanation for this. My assumption is that distributions from unconsolidated affiliates that appear in the cash flow statement as cash provided by operating activities include: a) the 50% ownership stake in Citrus and, through that, a 50% stake in FGT, a natural gas pipeline system that originates in Texas, delivers natural gas to the Florida peninsula, and is 50% owned by Kinder Morgan, Inc. (KMI); and b) ETP’s 50% interest in FEP, a 50/50 joint venture with Kinder Morgan Energy Partners (KMP) built to serve the Fayetteville Shale producing region in Arkansas. I added to sustainable cash flow distributions from unconsolidated affiliates that appear under cash from investing activities and assume these consist principally of the 29.6 million shares of AmeriGas Partners, L.P. (APU) received by ETP (together with ~$1.46 billion in cash) upon ETP’s contribution of its propane business to APU in January 2012.

The differences between reported DCF and sustainable DCF in Table 3 relate to ETP’s risk management activities and to a variety of items grouped under “Other”.

In deriving its reported DCF, ETP adds back losses from risk management activities. This item totals $68 million in the 9 months ended 9/30/12, the bulk of which is due to derivatives related to stored natural gas. ETP adds back this unrealized loss in calculating DCF while I do not.

Coverage ratios continue to be below 1.0 as indicated in Table 4 below:

9 months ending: 9/30/12 9/30/11
Total distributions $960 $864
Coverage ratio based on reported DCF 0.97 0.96
Coverage ratio based on sustainable DCF 0.93 0.89

Table 4

Incentive distributions to Energy Transfer Equity, L.P. (ETE), ETP’s general partner, are included and accounted for ~34% of total distributions for the TTM ended 9/30/12 and ~36% for the comparable prior year period. While reported DCF per unit has not really changed in recent years, sustainable DCF has improved slightly which is an encouraging sign. This can be seen in Table 5 below:

9 months ending: 9/30/12 9/30/11 9/30/10
Reported DCF per unit $3.98 $4.03 $3.97
Sustainable DCF per unit $3.79 $3.76 $3.67

Table 5

I find it helpful to look at a simplified cash flow statement by netting certain items (e.g., acquisitions against dispositions) and by separating cash generation from cash consumption. Here is what I see for ETP:

Simplified Sources and Uses of Funds

9 months ending: 9/30/12 9/30/11
Net cash from operations, less maintenance capex, less net income from non-controlling interests, less distributions (103) -
Capital expenditures ex maintenance, net of PP&E proceeds (1,716) (870)
Acquisitions, investments (net of sale proceeds) (450) (1,965)
Other CF from financing activities, net (18) (12)
(2,287) (2,848)
Net cash from operations, less maintenance capex, less net income from non-controlling interests, less distributions - 86
Cash contributions/distributions related to affiliates & noncontrolling interests 294 392
Debt incurred (repaid) 1,196 1,639
Partnership units  issued 772 799
Other CF from investing activities, net 28 18
2,290 2,934
Net change in cash 4 87

Table 6: Figures in $ Millions

Net cash from operations, less maintenance capital expenditures, less net income from non-controlling interests fell short of covering distributions by $103 million in the 9 month period ending 9/30/12. However, some distributions from unconsolidated affiliates appear in the cash flow statement as cash from operating activities while others appear under cash from investing activities. I did not see an explanation for this. If I add back to cash from operations distributions the ~$95 million cash received during this period from unconsolidated affiliates that appears under cash from investing activities, the shortfall is reduced to $8 million. So only a very small portion of the period’s distributions were funded by issuance of units or debt.

ETP’s current yield of 8.50% is higher than almost all the other MLPs I cover:

As of 11/9/12: Price Yield
Magellan Midstream Partners (MMP) 42.90 4.39%
Plains All American Pipeline (PAA) 45.50 4.77%
Enterprise Products Partners L.P. (EPD) 51.39 5.06%
Kinder Morgan Energy Partners (KMP) 80.64 6.25%
Williams Partners (WPZ) 50.62 6.38%
El Paso Pipeline Partners (EPB) 36.21 6.41%
Targa Resources Partners (NGLS) 40.74 6.50%
Regency Energy Partners (RGP) 22.25 8.27%
Boardwalk Pipeline Partners (BWP) 25.29 8.42%
Energy Transfer Partners (ETP) 42.08 8.50%
Suburban Propane Partners (SPH) 39.43 8.65%
Buckeye Partner (BPL) 45.38 9.14%

Table 7

On the positive side, distributable cash flow, whether as reported or sustainable, seems very close to fully supporting this high yield. On the other hand, I am troubled by the complexities created by using ETP for some acquisitions, ETE for others and the resultant creation of ETP Holdco Corporation (“Holdco”) into which ETE contributed its interest in Southern Union for a 60% equity interest and ETP contributed its interest in SUN for a 40% controlling equity stake. Management acknowledges this will have to be untangled. ETP also now owns a retail gasoline business which is non-strategic and does not fit well structure-wise because it is a corporation and is subject to corporate taxes. Contrary to expectations, management stated it does not intend to dispose of that business and is seeking a structural solution to eliminate the tax inefficiencies. Also, management is contemplating folding RGP into ETP. I reduced my ETP position at prices ranging from $47.43 to $42.02 but am not currently considering further reductions.

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