Plains All American Pipeline, L.P. and Plains GP Holdings Report First-Quarter 2017 Results |
Updates 2017 Full-Year Guidance
Plains All American Pipeline, L.P. (NYSE:PAA)
and Plains GP Holdings (NYSE:PAGP)
today reported first-quarter 2017 results.
Plains All American Pipeline, L.P.
| Summary Financial Information(unaudited)
|
(in millions, except per unit data)
|
| |
|
| Three Months Ended |
|
| | | | | March 31, | | | % | GAAP Results | | | 2017 |
|
| 2016 | | | Change |
Net income attributable to PAA
| | |
$
|
444
| | |
$
|
202
| | |
120
|
%
|
Diluted net income per common unit
| | |
$
|
0.58
| | |
$
|
0.07
| | |
729
|
%
|
Diluted weighted average common units outstanding
| | |
|
758
| | |
|
399
| | |
90
|
%
|
Distribution per common unit declared for the period
| | |
$
|
0.55
| | |
$
|
0.70
| | |
(21.4
|
)%
|
| | | | Three Months Ended | | | | | | | March 31, | | | % | Non-GAAP Results (1) | | | 2017 | | | 2016 | | | Change |
Adjusted net income attributable to PAA
| | |
$
|
224
| | |
$
|
355
| | |
(37
|
)%
|
Diluted adjusted net income per common unit
| | |
$
|
0.27
| | |
$
|
0.45
| | |
(40
|
)%
|
Adjusted EBITDA (2)
| | |
$
|
512
| | |
$
|
633
| | |
(19
|
)%
|
___________________________________________
| | | | | | | | | | | | |
(1)
|
|
|
See the section of this release entitled "Non-GAAP Financial
Measures and Selected Items Impacting Comparability" and the tables
attached hereto for information regarding certain selected items
that PAA believes impact comparability of financial results between
reporting periods, as well as for information regarding non-GAAP
financial measures (such as adjusted EBITDA) and their
reconciliation to the most directly comparable measures as reported
in accordance with GAAP.
|
(2)
| | |
Prior period amounts have been recast to conform to certain changes
made in the fourth quarter of 2016.
| | | |
|
"Our first quarter results reflect in-line performance from our
fee-based Transportation and Facilities segments as well as our
margin-based crude oil marketing activities, but were adversely impacted
by weaker than anticipated performance from our NGL marketing
activities, which are included in our Supply and Logistics segment,"
said Greg Armstrong, Chairman and CEO. "NGL margins were negatively
impacted by warmer weather and tighter differentials between Canada and
our US demand markets among other factors. To address these issues in
future periods, we are modifying the way we manage our inventory and
implementing contractual provisions that will reduce earnings volatility
and the quantity of seasonal NGL inventory we store, in exchange for
partially limiting our upside potential.
"In February, we shared our view that the first six to nine months of
the current year would prove challenging but that we expected to see
strong improvement toward the end of 2017 as several multi-year capital
projects are completed and volume growth in the Permian advances.
Although our cautious outlook for the near term is proving accurate, we
definitely like the way the industry is shaping up for the latter part
of 2017 and beyond.
"Producer activity levels in almost every area are ahead of levels
included in our outlook at the beginning of the year, especially with
respect to the Permian Basin. Well productivity is increasing as new
wells are coming in stronger than previously modeled. Our outlook
continues to incorporate an increasing time lag between increased
drilling activity and increased production volumes as producers shift to
multi-well pad operations. Accordingly, we continue to expect our
transportation volumes to ramp up in the second half of this year.
"Consistent with our outlook, we are seeing increased interest from
potential shippers for pipeline space currently available on our
existing assets as well as for incremental pipeline capacity at rates
that provide us an attractive return. All of this reinforces our outlook
and confidence in a back-end weighted improvement during 2017 in our fee
based growth and that we remain on-course for a meaningful increase in
year-over-year performance in 2018 and beyond."
Segment adjusted EBITDA for the first quarter of 2017 is presented below:
| Summary of Selected Financial Data by
Segment(1)(unaudited)
|
(in millions)
|
| |
|
| Three Months Ended |
|
| Three Months Ended | | | | March 31, 2017 | | | March 31, 2016 | | | | Transportation | |
| Facilities |
|
| Supply and Logistics | | | Transportation |
|
| Facilities |
|
| Supply and Logistics |
Segment adjusted EBITDA
| | |
$
|
273
|
| | |
$
|
188
|
| | |
$
|
51
|
| | |
$
|
281
|
| | |
$
|
167
|
| | |
$
|
184
| Percentage change in segment adjusted EBITDA versus 2016 period | | | (3 | )% | | | 13 | % | | | (72 | )% | | | | | | | | | |
___________________________________________
| | | | | | | | | | | | | | | | |
(1)
|
|
|
During the fourth quarter of 2016, we modified our primary segment
performance measure to segment adjusted EBITDA from segment profit
and also modified our definition of adjusted EBITDA to exclude our
proportionate share of depreciation and amortization expense
associated with equity method investments. Prior period segment
amounts have been recast to reflect these changes.
| | | |
|
First-quarter 2017 Transportation segment adjusted EBITDA decreased by
3% versus comparable 2016 results. This decrease was primarily driven by
the impact of non-core asset sales and other volume decreases in the
Rocky Mountain region primarily associated with pipeline downtime. These
decreases were partially offset by increases on certain of our Permian
Basin pipelines due largely to increased Delaware Basin production
impacting our Basin pipeline and contributions from our Alpha Crude
Connector gathering system which we acquired in February 2017.
First-quarter 2017 Facilities segment adjusted EBITDA increased by 13%
versus comparable 2016 results. This increase was primarily due to
contributions from the Canadian NGL assets we acquired in August 2016,
higher fees at certain of our NGL storage and fractionation facilities
and contributions from ongoing expansion projects at our Fort
Saskatchewan facility. These increases were partially offset by lower
U.S. rail terminal activity, lower utilization of our West Coast
terminals, and the impact of non-core asset sales.
First-quarter 2017 Supply and Logistics segment adjusted EBITDA
decreased by 72% relative to comparable 2016 results. This decrease was
primarily driven by lower results from our NGL activities due to the
impact of competition and continued margin compression, and unusually
warm weather, as well as margin compression from our crude oil gathering
and marketing activities caused by continued intense competition.
2017 Full-Year Guidance
Full-year 2017 financial and operating guidance is presented below:
| FINANCIAL AND OPERATING GUIDANCE
(unaudited)
|
(in millions, except per barrel data)
|
| |
|
| Twelve Months Ended December 31, | | | | 2015 |
|
| 2016 |
|
| 2017 (G) |
|
| 2017 vs 2016 | | | | | | | | | |
+ / -
| | | | Segment Adjusted EBITDA | | | | | | | | | | | | |
Transportation
| | |
$
|
1,056
| | | |
$
|
1,141
| | | |
$
|
1,325
| | | |
16
|
%
|
Facilities
| | |
588
| | | |
667
| | | |
705
| | | |
6
|
%
|
Supply and Logistics
| | |
568
| | | |
359
| | | |
230
| | | |
(36)
|
%
|
Other income/(expense), net
| | |
1
|
| | |
2
|
| | |
-
|
| | |
| Adjusted EBITDA (1) | | | $ | 2,213 |
| | | $ | 2,169 |
| | | $ | 2,260 |
| | | 4 | % |
Interest expense, net (2) | | |
(417
|
)
| | |
(451
|
)
| | |
(480
|
)
| | | |
6
|
%
|
Maintenance capital
| | |
(220
|
)
| | |
(186
|
)
| | |
(195
|
)
| | | |
5
|
%
|
Current income tax expense
| | |
(84
|
)
| | |
(85
|
)
| | |
(40
|
)
| | | |
(53)
|
%
|
Other
| | |
(18
|
)
| | |
(33
|
)
| | |
(5
|
)
|
| | |
(85)
|
%
| Implied DCF (1) | | | $ | 1,474 |
| | | $ | 1,414 |
| | | $ | 1,540 |
| | | 9 | % | | | | | | | | | | | | |
| Operating Data | | | | | | | | | | | | | Transportation | | | | | | | | | | | | |
Average daily volumes (MBbls/d)
| | |
4,453
| | | |
4,637
| | | |
5,400
| | | |
16
|
%
|
Segment Adjusted EBITDA per barrel
| | |
$
|
0.65
| | | |
$
|
0.67
| | | |
$
|
0.67
| | | |
-
|
%
| | | | | | | | | | | | |
| Facilities | | | | | | | | | | | | |
Average capacity (MMBbls/Mo)
| | |
126
| | | |
129
| | | |
130
| | | |
1
|
%
|
Segment Adjusted EBITDA per barrel
| | |
$
|
0.39
| | | |
$
|
0.43
| | | |
$
|
0.45
| | | |
5
|
%
| | | | | | | | | | | | |
| Supply and Logistics | | | | | | | | | | | | |
Average daily volumes (MBbls/d)
| | |
1,168
| | | |
1,160
| | | |
1,230
| | | |
6
|
%
|
Segment Adjusted EBITDA per barrel
| | |
$
|
1.33
| | | |
$
|
0.85
| | | |
$
|
0.51
| | | |
(40)
|
%
| | | | | | | | | | | | |
| Expansion Capital | | | $ | 2,170 | | | | $ | 1,405 | | | | $ | 900 | | | | $ | (505) |
| | | | | | | | | | | | |
| Second Quarter Adjusted EBITDA as Percentage of Full Year | | | 22 | % | | | 22 | % | | | 20 | % | | | | |
___________________________________________
| | | | | | | | | | | | | | | |
(G)
|
|
|
2017 Guidance forecasts are intended to be + / - amounts.
|
(1)
| | |
See the section of this release entitled "Non-GAAP Financial
Measures and Selected Items Impacting Comparability" and the
Financial Data Reconciliations table attached hereto for
information regarding non-GAAP financial measures. For the
historical 2015 and 2016 periods, please visit our website at www.plainsallamerican.com
(in particular the section under "Financial Information" entitled
"Non-GAAP Reconciliations" within the "Investor Relations" tab),
for a reconciliation to the most directly comparable measures as
reported in accordance with GAAP. We do not provide a
reconciliation of non-GAAP financial measures to the equivalent
GAAP financial measures on a forward-looking basis as it is
impractical to forecast certain items that we have defined as
"Selected Items Impacting Comparability" without unreasonable
effort, due to the uncertainty and inherent difficulty of
predicting the occurrence and financial impact of and the periods
in which such items may be recognized. Thus, a reconciliation of
non-GAAP financial measures to the equivalent GAAP financial
measures could result in disclosure that could be imprecise or
potentially misleading.
|
(2)
| | |
Excludes certain non-cash items impacting interest expense such as
amortization of debt issuance costs and terminated interest rate
swaps.
| | | |
|
Plains GP Holdings
PAGP owns an indirect non-economic controlling interest in PAA's general
partner and an indirect limited partner interest in PAA. As the control
entity of PAA, PAGP consolidates PAA's results into its financial
statements, which is reflected in the condensed consolidating balance
sheet and income statement tables included at the end of this release.
Information regarding PAGP's distributions is reflected below:
| |
|
| Q1 2017 |
|
| Q4 2016 |
|
| Q1 2016 | Distribution per Class A share declared for the period (1) | | |
$
|
0.55
| | | |
$
|
0.55
|
| | |
$
|
0.62
|
| Q1 2017 distribution percentage change from prior periods | | | | | |
-
|
%
| | |
(11.3
|
)%
|
___________________________________________
| | | | | | | | | | | |
(1)
|
|
|
A reverse split of PAGP's Class A shares was completed on November
15, 2016. The effect of the reverse split has been retroactively
applied to all per-share amounts presented.
| | | |
|
Conference Call
PAA and PAGP will hold a conference call at 11:00 a.m. ET on Tuesday,
May 9, 2017 to discuss the following items:
1. PAA's first-quarter 2017 performance;
2. Financial and operating guidance for 2017;
3. Major expansion projects;
4. Capitalization and liquidity; and
5. PAA and PAGP's outlook for the future.
Conference Call Webcast Instructions
To access the internet webcast of the conference call, please go to www.plainsallamerican.com,
under the Investor Relations section of the website (Navigate to:
Investor Relations / either PAA or PAGP / News & Events / Quarterly
Earnings). Following the live webcast, an audio replay in MP3 format
will be available on the website within two hours after the end of the
call and will be accessible for a period of 365 days.
Non-GAAP Financial Measures and Selected Items Impacting
Comparability
To supplement our financial information presented in accordance with
GAAP, management uses additional measures known as "non-GAAP financial
measures" in its evaluation of past performance and prospects for the
future. The primary additional measures used by management are earnings
before interest, taxes, depreciation and amortization (including our
proportionate share of depreciation and amortization of unconsolidated
entities) and adjusted for certain selected items impacting
comparability ("Adjusted EBITDA") and implied distributable cash flow
("DCF").
Management believes that the presentation of such additional financial
measures provides useful information to investors regarding our
performance and results of operations because these measures, when used
to supplement related GAAP financial measures, (i) provide additional
information about our core operating performance and ability to fund
distributions to our unitholders through cash generated by our
operations and (ii) provide investors with the same financial analytical
framework upon which management bases financial, operational,
compensation and planning/budgeting decisions. We also present these and
additional non-GAAP financial measures, including adjusted net income
attributable to PAA and basic and diluted adjusted net income per common
unit, as they are measurements that investors, rating agencies and debt
holders have indicated are useful in assessing us and our results of
operations. These non-GAAP measures may exclude, for example, (i)
charges for obligations that are expected to be settled with the
issuance of equity instruments, (ii) gains or losses on derivative
instruments that are related to underlying activities in another period
(or the reversal of such adjustments from a prior period), the
mark-to-market related to our Preferred Distribution Rate Reset Option,
gains and losses on derivatives that are related to investing activities
(such as the purchase of linefill) and inventory valuation adjustments,
as applicable, (iii) long-term inventory costing adjustments, (iv) items
that are not indicative of our core operating results and business
outlook and/or (v) other items that we believe should be excluded in
understanding our core operating performance. These measures may further
be adjusted to include amounts related to deficiencies associated with
minimum volume commitments whereby we have billed the counterparties for
their deficiency obligation and such amounts are recognized as deferred
revenue in "Accounts payable and accrued liabilities" on our Condensed
Consolidated Financial Statements. Such amounts are presented net of
applicable amounts subsequently recognized into revenue. Furthermore,
the calculation of these measures contemplates tax effects as a separate
reconciling item, where applicable. We have defined all such items as
"selected items impacting comparability." Due to the nature of the
selected items, certain selected items impacting comparability may
impact certain non-GAAP financial measures, referred to as adjusted
results, but not impact other non-GAAP financial measures. We do not
necessarily consider all of our selected items impacting comparability
to be non-recurring, infrequent or unusual, but we believe that an
understanding of these selected items impacting comparability is
material to the evaluation of our operating results and prospects.
Although we present selected items impacting comparability that
management considers in evaluating our performance, you should also be
aware that the items presented do not represent all items that affect
comparability between the periods presented. Variations in our operating
results are also caused by changes in volumes, prices, exchange rates,
mechanical interruptions, acquisitions, expansion projects and numerous
other factors. These types of variations are not separately identified
in this release, but will be discussed, as applicable, in management's
discussion and analysis of operating results in our Quarterly Report on
Form 10-Q.
Our definition and calculation of certain non-GAAP financial measures
may not be comparable to similarly-titled measures of other companies.
Adjusted EBITDA, Implied DCF and other non-GAAP financial performance
measures are reconciled to Net Income (the most directly comparable
measure as reported in accordance with GAAP) for the historical periods
presented in the tables attached to this release, and should be viewed
in addition to, and not in lieu of, our Condensed Consolidated Financial
Statements and notes thereto. In addition, we encourage you to visit our
website at www.plainsallamerican.com
(in particular the section under "Financial Information" entitled
"Non-GAAP Reconciliations" within the Investor Relations tab), which
presents a reconciliation of our commonly used non-GAAP and supplemental
financial measures.
Forward-Looking Statements
Except for the historical information contained herein, the matters
discussed in this release consist of forward-looking statements that
involve certain risks and uncertainties that could cause actual results
or outcomes to differ materially from results or outcomes anticipated in
the forward-looking statements. These risks and uncertainties include,
among other things, declines in the volume of crude oil and NGL shipped,
processed, purchased, stored, fractionated and/or gathered at or through
the use of our assets, whether due to declines in production from
existing oil and gas reserves, reduced demand, failure to develop or
slowdown in the development of additional oil and gas reserves, whether
from reduced cash flow to fund drilling or the inability to access
capital, or other factors; the effects of competition; market
distortions caused by producer over-commitments to new or recently
constructed infrastructure projects, which impacts volumes, margins,
returns and overall earnings; unanticipated changes in crude oil market
structure, grade differentials and volatility (or lack thereof);
environmental liabilities or events that are not covered by an
indemnity, insurance or existing reserves; maintenance of our credit
rating and ability to receive open credit from our suppliers and trade
counterparties; fluctuations in refinery capacity in areas supplied by
our mainlines and other factors affecting demand for various grades of
crude oil, refined products and natural gas and resulting changes in
pricing conditions or transportation throughput requirements; the
occurrence of a natural disaster, catastrophe, terrorist attack
(including eco-terrorist attacks) or other event, including attacks on
our electronic and computer systems; failure to implement or capitalize,
or delays in implementing or capitalizing, on expansion projects,
whether due to permitting delays, permitting withdrawals or other
factors; tightened capital markets or other factors that increase our
cost of capital or limit our ability to obtain debt or equity financing
on satisfactory terms to fund additional acquisitions, expansion
projects, working capital requirements and the repayment or refinancing
of indebtedness; the successful integration and future performance of
acquired assets or businesses and the risks associated with operating in
lines of business that are distinct and separate from our historical
operations; the currency exchange rate of the Canadian dollar; continued
creditworthiness of, and performance by, our counterparties, including
financial institutions and trading companies with which we do business;
inability to recognize current revenue attributable to deficiency
payments received from customers who fail to ship or move more than
minimum contracted volumes until the related credits expire or are used;
non-utilization of our assets and facilities; increased costs, or lack
of availability, of insurance; weather interference with business
operations or project construction, including the impact of extreme
weather events or conditions; the availability of, and our ability to
consummate, acquisition or combination opportunities; the effectiveness
of our risk management activities; shortages or cost increases of
supplies, materials or labor; the impact of current and future laws,
rulings, governmental regulations, accounting standards and statements,
and related interpretations; fluctuations in the debt and equity
markets, including the price of our units at the time of vesting under
our long-term incentive plans; risks related to the development and
operation of our assets, including our ability to satisfy our
contractual obligations to our customers; factors affecting demand for
natural gas and natural gas storage services and rates; general
economic, market or business conditions and the amplification of other
risks caused by volatile financial markets, capital constraints and
pervasive liquidity concerns; and other factors and uncertainties
inherent in the transportation, storage, terminalling and marketing of
crude oil and refined products, as well as in the storage of natural gas
and the processing, transportation, fractionation, storage and marketing
of natural gas liquids as discussed in the Partnerships' filings with
the Securities and Exchange Commission.
Plains All American Pipeline, L.P. is a publicly traded master limited
partnership that owns and operates midstream energy infrastructure and
provides logistics services for crude oil, NGLs, natural gas and refined
products. PAA owns an extensive network of pipeline transportation,
terminalling, storage and gathering assets in key crude oil and NGL
producing basins and transportation corridors and at major market hubs
in the United States and Canada. On average, PAA handles over 4.7
million barrels per day of crude oil and NGL in its Transportation
segment. PAA is headquartered in Houston, Texas. More information is
available at www.plainsallamerican.com.
Plains GP Holdings is a publicly traded entity that owns an indirect,
non-economic controlling general partner interest in PAA and an indirect
limited partner interest in PAA, one of the largest energy
infrastructure and logistics companies in North America. PAGP is
headquartered in Houston, Texas. More information is available at www.plainsallamerican.com.
|
|
| | PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | | | | FINANCIAL SUMMARY (unaudited)
|
|
|
| | | |
| CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS | | | |
(in millions, except per unit data)
| | | |
| | | | Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | REVENUES | | |
$
|
6,667
| | | |
$
|
4,111
| | | | | | | |
| COSTS AND EXPENSES | | | | | | |
Purchases and related costs
| | |
5,593
| | | |
3,348
| |
Field operating costs
| | |
288
| | | |
300
| |
General and administrative expenses
| | |
74
| | | |
67
| |
Depreciation and amortization
| | |
121
|
| | |
114
|
|
Total costs and expenses
| | |
6,076
| | | |
3,829
| | | | | | | |
| OPERATING INCOME | | |
591
| | | |
282
| | | | | | | |
| OTHER INCOME/(EXPENSE) | | | | | | |
Equity earnings in unconsolidated entities
| | |
53
| | | |
47
| |
Interest expense, net
| | |
(129
|
)
| | |
(112
|
)
|
Other income/(expense), net
| | |
(5
|
)
| | |
5
|
| | | | | | |
| INCOME BEFORE TAX | | |
510
| | | |
222
| |
Current income tax expense
| | |
(10
|
)
| | |
(31
|
)
|
Deferred income tax benefit/(expense)
| | |
(56
|
)
| | |
12
|
| | | | | | |
| NET INCOME | | |
444
| | | |
203
| |
Net income attributable to noncontrolling interests
| | |
-
|
| | |
(1
|
)
| NET INCOME ATTRIBUTABLE TO PAA | | |
$
|
444
|
| | |
$
|
202
|
| | | | | | |
| NET INCOME PER COMMON UNIT: | | | | | | |
Net income allocated to common unitholders - Basic
| | |
$
|
406
| | | |
$
|
28
| |
Basic weighted average common units outstanding
| | |
691
| | | |
398
| |
Basic net income per common unit
| | |
$
|
0.59
|
| | |
$
|
0.07
|
| | | | | | |
|
Net income allocated to common unitholders - Diluted
| | |
$
|
443
| | | |
$
|
28
| |
Diluted weighted average common units outstanding
| | |
758
| | | |
399
| |
Diluted net income per common unit
| | |
$
|
0.58
|
| | |
$
|
0.07
|
|
|
| NON-GAAP ADJUSTED RESULTS |
|
| |
(in millions, except per unit data)
| | | |
| | | | Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 |
Adjusted net income attributable to PAA
| | |
$
|
224
|
| | |
$
|
355
| | | | | | |
|
Diluted adjusted net income per common unit
| | |
$
|
0.27
|
| | |
$
|
0.45
| | | | | | |
|
Adjusted EBITDA
| | |
$
|
512
|
| | |
$
|
633
| | | | | | | | | |
|
|
|
| |
|
| | PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | | | | | | | FINANCIAL SUMMARY (unaudited)
|
|
|
|
|
|
| | | | | | |
| CONDENSED CONSOLIDATED BALANCE SHEET DATA | | | | | | |
(in millions)
| | | | | | |
| | | | March 31, | | | December 31, | | | | 2017 | | | 2016 | ASSETS | | | | | | |
Current assets
| | |
$
|
4,210
| | | |
$
|
4,272
|
Property and equipment, net
| | |
14,060
| | | |
13,872
|
Goodwill
| | |
2,596
| | | |
2,344
|
Investments in unconsolidated entities
| | |
2,469
| | | |
2,343
|
Linefill and base gas
| | |
883
| | | |
896
|
Long-term inventory
| | |
131
| | | |
193
|
Other long-term assets, net
| | |
920
|
| | |
290
|
Total assets
| | |
$
|
25,269
|
| | |
$
|
24,210
| | | | | | |
| LIABILITIES AND PARTNERS' CAPITAL | | | | | | |
Current liabilities
| | |
$
|
4,156
| | | |
$
|
4,664
|
Senior notes, net of unamortized discounts and debt issuance costs
| | |
9,876
| | | |
9,874
|
Other long-term debt
| | |
3
| | | |
250
|
Other long-term liabilities and deferred credits
| | |
644
|
| | |
606
|
Total liabilities
| | |
$
|
14,679
| | | |
$
|
15,394
| | | | | | |
|
Partners' capital excluding noncontrolling interests
| | |
10,534
| | | |
8,759
|
Noncontrolling interests
| | |
56
|
| | |
57
|
Total partners' capital
| | |
10,590
|
| | |
8,816
|
Total liabilities and partners' capital
| | |
$
|
25,269
|
| | |
$
|
24,210
| | | | | | | | | |
|
| DEBT CAPITALIZATION RATIOS |
(in millions)
|
| |
|
| March 31, |
|
| December 31, | | | | 2017 | | | 2016 |
Short-term debt (1) | | |
$
|
1,341
| | | |
$
|
1,715
| |
Long-term debt
| | |
9,879
|
| | |
10,124
|
|
Total debt
| | |
$
|
11,220
|
| | |
$
|
11,839
|
| | | | | | |
|
Long-term debt
| | |
$
|
9,879
| | | |
$
|
10,124
| |
Partners' capital
| | |
10,590
|
| | |
8,816
|
|
Total book capitalization
| | |
$
|
20,469
|
| | |
$
|
18,940
|
|
Total book capitalization, including short-term debt
| | |
$
|
21,810
|
| | |
$
|
20,655
|
| | | | | | |
|
Long-term debt-to-total book capitalization
| | |
48
|
%
| | |
53
|
%
|
Total debt-to-total book capitalization, including short-term debt
| | |
51
|
%
| | |
57
|
%
|
___________________________________________
| | | | | | | | |
(1)
|
|
|
As of March 31, 2017 and December 31, 2016, short-term debt includes
borrowings of approximately $1,307 million and $1,303 million,
respectively, for short-term hedged inventory purchases and
borrowings of approximately $95 million and $410 million,
respectively, for cash margin deposits with our clearing brokers,
which are associated with financial derivatives used for hedging
purposes.
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES |
|
| |
|
| | FINANCIAL SUMMARY (unaudited)
|
|
|
|
|
|
| | | | | | |
| OPERATING DATA(1) | | | | | | | | | | Three Months Ended | | | | March 31, | | | | 2017 | | | 2016 | Transportation segment (average daily volumes in thousands of
barrels per day): | | | | | | |
Tariff activities volumes
| | | | | | |
Crude oil pipelines (by region):
| | | | | | |
Permian Basin (2) | | |
2,466
| | | |
2,045
|
South Texas / Eagle Ford (2) | | |
310
| | | |
313
|
Western
| | |
189
| | | |
175
|
Rocky Mountain (2) | | |
385
| | | |
437
|
Gulf Coast
| | |
342
| | | |
581
|
Central (2) | | |
405
| | | |
379
|
Canada
| | |
363
|
| | |
394
|
Crude oil pipelines
| | |
4,460
| | | |
4,324
|
NGL pipelines
| | |
180
|
| | |
178
|
Tariff activities total volumes
| | |
4,640
| | | |
4,502
|
Trucking volumes
| | |
114
|
| | |
106
|
Transportation segment total volumes
| | |
4,754
|
| | |
4,608
| | | | | | |
| Facilities segment (average monthly volumes): | | | | | | |
Crude oil, refined products and NGL terminalling and storage
(average monthly capacity in millions of barrels)
| | |
111
|
| | |
105
|
Rail load / unload volumes (average volumes in thousands of barrels
per day)
| | |
35
|
| | |
91
|
Natural gas storage (average monthly working capacity in billions of
cubic feet)
| | |
97
|
| | |
97
|
NGL fractionation (average volumes in thousands of barrels per day)
| | |
125
|
| | |
115
|
Facilities segment total volumes (average monthly volumes in
millions of barrels) (3) | | |
132
|
| | |
127
| | | | | | |
| Supply and Logistics segment (average daily volumes in thousands
of barrels per day): | | | | | | |
Crude oil lease gathering purchases
| | |
916
| | | |
913
|
NGL sales
| | |
351
| | | |
308
|
Waterborne cargos
| | |
7
|
| | |
7
|
Supply and Logistics segment total volumes
| | |
1,274
|
| | |
1,228
|
___________________________________________
| | | | | | | |
(1)
|
|
|
Average volumes are calculated as total volumes for the period
(attributable to our interest) divided by the number of days or
months in the period.
|
(2)
| | |
Region includes volumes (attributable to our interest) from
pipelines owned by unconsolidated entities.
|
(3)
| | |
Facilities segment total volumes is calculated as the sum of: (i)
crude oil, refined products and NGL terminalling and storage
capacity; (ii) rail load and unload volumes multiplied by the number
of days in the period and divided by the number of months in the
period; (iii) natural gas storage working capacity divided by 6 to
account for the 6:1 mcf of natural gas to crude Btu equivalent ratio
and further divided by 1,000 to convert to monthly volumes in
millions; and (iv) NGL fractionation volumes multiplied by the
number of days in the period and divided by the number of months in
the period.
| | | |
|
|
|
| | PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | | | | FINANCIAL SUMMARY (unaudited)
|
|
|
| | | |
| COMPUTATION OF BASIC AND DILUTED NET
INCOME PER COMMON UNIT(1) | | | |
(in millions, except per unit data)
| | | |
| | | | | | | Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | Basic Net Income per Common Unit | | | | | | |
Net income attributable to PAA
| | |
$
|
444
| | | |
$
|
202
| |
Distributions to Series A preferred units
| | |
(34
|
)
| | |
(23
|
)
|
Distributions to general partner
| | |
-
| | | |
(155
|
)
|
Other
| | |
(4
|
)
| | |
4
|
|
Net income allocated to common unitholders
| | |
$
|
406
|
| | |
$
|
28
|
| | | | | | |
|
Basic weighted average common units outstanding
| | |
691
| | | |
398
| | | | | | | |
|
Basic net income per common unit
| | |
$
|
0.59
|
| | |
$
|
0.07
|
| | | | | | |
| Diluted Net Income per Common Unit | | | | | | |
Net income attributable to PAA
| | |
$
|
444
| | | |
$
|
202
| |
Distributions to Series A preferred units
| | |
-
| | | |
(23
|
)
|
Distributions to general partner
| | |
-
| | | |
(155
|
)
|
Other
| | |
(1
|
)
| | |
4
|
|
Net income allocated to common unitholders
| | |
$
|
443
|
| | |
$
|
28
|
| | | | | | |
|
Basic weighted average common units outstanding
| | |
691
| | | |
398
| |
Effect of dilutive securities:
| | | | | | |
Series A preferred units (2) | | |
65
| | | |
-
| |
LTIP units (3) | | |
2
|
| | |
1
|
|
Diluted weighted average common units outstanding
| | |
758
|
| | |
399
|
| | | | | | |
|
Diluted net income per common unit
| | |
$
|
0.58
|
| | |
$
|
0.07
|
|
___________________________________________
| | | | | | | | | | |
(1)
|
|
|
We calculate net income allocated to common unitholders based on the
distributions pertaining to the current period's net income. After
adjusting for the appropriate period's distributions, the remaining
undistributed earnings or excess distributions over earnings
("undistributed loss"), if any, are allocated to the general
partner, common unitholders and participating securities in
accordance with the contractual terms of our partnership agreement
in effect for the period and as further prescribed under the
two-class method. The Simplification Transactions, which closed on
November 15, 2016, simplified our governance structure and
permanently eliminated our IDRs and the economic rights associated
with our 2% general partner interest. As such, beginning with the
distribution pertaining to the fourth quarter of 2016, our general
partner is no longer entitled to receive distributions on these
interests.
|
(2)
| | |
The possible conversion of our Series A preferred units was excluded
from the calculation of diluted net income per common unit for the
three months ended March 31, 2016 as the effect was antidilutive.
|
(3)
| | |
Our Long-term Incentive Plan ("LTIP") awards that contemplate the
issuance of common units are considered dilutive unless (i) vesting
occurs only upon the satisfaction of a performance condition and
(ii) that performance condition has yet to be satisfied. LTIP awards
that are deemed to be dilutive are reduced by a hypothetical unit
repurchase based on the remaining unamortized fair value, as
prescribed by the treasury stock method in guidance issued by the
FASB.
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| SELECTED FINANCIAL DATA BY SEGMENT(1) |
(in millions)
|
| |
|
| Three Months Ended |
|
| Three Months Ended | | | | March 31, 2017 | | | March 31, 2016 | | | | |
|
| |
|
| Supply and | | | |
|
| |
|
| Supply and | | | | Transportation | | | Facilities | | | Logistics | | | Transportation | | | Facilities | | | Logistics |
Revenues (2) | | |
$
|
389
| | | |
$
|
293
| | | |
$
|
6,400
| | | |
$
|
383
| | | |
$
|
265
| | | |
$
|
3,821
| |
Purchases and related costs (2) | | |
(24
|
)
| | |
(11
|
)
| | |
(5,970
|
)
| | |
(21
|
)
| | |
(5
|
)
| | |
(3,677
|
)
|
Field operating costs (2) (3) | | |
(137
|
)
| | |
(82
|
)
| | |
(67
|
)
| | |
(137
|
)
| | |
(85
|
)
| | |
(81
|
)
|
Equity-indexed compensation expense - field operating costs
| | |
(4
|
)
| | |
(1
|
)
| | |
-
| | | |
-
| | | |
-
| | | |
-
| |
Segment general and administrative expenses (3) (4) | | |
(27
|
)
| | |
(17
|
)
| | |
(23
|
)
| | |
(23
|
)
| | |
(15
|
)
| | |
(25
|
)
|
Equity-indexed compensation expense - general and administrative
| | |
(2
|
)
| | |
(2
|
)
| | |
(3
|
)
| | |
(2
|
)
| | |
(1
|
)
| | |
(1
|
)
|
Equity earnings in unconsolidated entities
| | |
53
| | | |
-
| | | |
-
| | | |
47
| | | |
-
| | | |
-
| |
|
Adjustments: (5) | | | | | | | | | | | | | | | | | | |
Depreciation and amortization of unconsolidated entities
| | |
14
| | | |
-
| | | |
-
| | | |
12
| | | |
-
| | | |
-
| |
(Gains)/losses from derivative activities net of inventory valuation
adjustments
| | |
-
| | | |
2
| | | |
(291
|
)
| | |
-
| | | |
-
| | | |
122
| |
Long-term inventory costing adjustments
| | |
-
| | | |
-
| | | |
7
| | | |
-
| | | |
-
| | | |
23
| |
Deficiencies under minimum volume commitments, net
| | |
5
| | | |
6
| | | |
-
| | | |
20
| | | |
7
| | | |
-
| |
Equity-indexed compensation expense
| | |
1
| | | |
-
| | | |
2
| | | |
2
| | | |
1
| | | |
1
| |
Net (gain)/loss on foreign currency revaluation
| | |
-
| | | |
-
| | | |
(4
|
)
| | |
-
| | | |
-
| | | |
1
| |
Significant acquisition-related expenses
| | |
5
|
| | |
-
|
| | |
-
|
| | |
-
|
| | |
-
|
| | |
-
|
|
Segment adjusted EBITDA
| | |
$
|
273
|
| | |
$
|
188
|
| | |
$
|
51
|
| | |
$
|
281
|
| | |
$
|
167
|
| | |
$
|
184
|
| | | | | | | | | | | | | | | | | | |
|
Maintenance capital
| | |
$
|
29
|
| | |
$
|
27
|
| | |
$
|
3
|
| | |
$
|
35
|
| | |
$
|
9
|
| | |
$
|
3
|
|
___________________________________________
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
(1)
|
|
|
During the fourth quarter of 2016, we modified our primary segment
performance measure to segment adjusted EBITDA from segment profit.
Segment adjusted EBITDA forms the basis of our internal financial
reporting and is the primary measure used by our Chief Operating
Decision Maker ("CODM") in assessing performance and allocating
resources among our operating segments. Prior period segment amounts
have been recast to reflect this change.
|
(2)
| | |
Includes intersegment amounts.
|
(3)
| | |
Field operating costs and Segment general and administrative
expenses exclude equity-indexed compensation expense, which is
presented separately in the table above.
|
(4)
| | |
Segment general and administrative expenses reflect direct costs
attributable to each segment and an allocation of other expenses to
the segments. The proportional allocations by segment require
judgment by management and are based on the business activities that
exist during each period.
|
(5)
| | |
Represents adjustments utilized by our CODM in the evaluation of
segment results. Many of these adjustments are also considered
selected items impacting comparability when calculating consolidated
non-GAAP financial measures such as Adjusted EBITDA. See the
"Selected Items Impacting Comparability" table on the following page
for additional discussion.
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| SELECTED ITEMS IMPACTING COMPARABILITY |
(in millions, except per unit data)
|
| |
|
| Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | Selected Items Impacting Comparability: (1) | | | | | | |
Gains/(losses) from derivative activities net of inventory valuation
adjustments (2) | | |
$
|
285
| | | |
$
|
(122
|
)
|
Long-term inventory costing adjustments (3) | | |
(7
|
)
| | |
(23
|
)
|
Deficiencies under minimum volume commitments, net (4) | | |
(11
|
)
| | |
(27
|
)
|
Equity-indexed compensation expense (5) | | |
(3
|
)
| | |
(4
|
)
|
Net gain on foreign currency revaluation (6) | | |
3
| | | |
3
| |
Significant acquisition-related expenses (7) | | |
(5
|
)
| | |
-
|
|
Selected items impacting comparability - Adjusted EBITDA
| | |
$
|
262
|
| | |
$
|
(173
|
)
|
Tax effect on selected items impacting comparability
| | |
(42
|
)
| | |
20
|
|
Selected items impacting comparability - Adjusted net income
attributable to PAA
| | |
$
|
220
|
| | |
$
|
(153
|
)
| | | | | | |
|
Impact to basic net income per common unit
| | |
$
|
0.32
|
| | |
$
|
(0.38
|
)
|
Impact to diluted net income per common unit
| | |
$
|
0.31
|
| | |
$
|
(0.38
|
)
|
___________________________________________
| | | | | | | | | | |
(1)
|
|
|
Certain of our non-GAAP financial measures may not be impacted by
each of the selected items impacting comparability.
|
(2)
| | |
We use derivative instruments for risk management purposes and our
related processes include specific identification of hedging
instruments to an underlying hedged transaction. Although we
identify an underlying transaction for each derivative instrument we
enter into, there may not be an accounting hedge relationship
between the instrument and the underlying transaction. In the course
of evaluating our results of operations, we identify the earnings
that were recognized during the period related to derivative
instruments for which the identified underlying transaction does not
occur in the current period and exclude the related gains and losses
in determining adjusted results. In addition, we exclude gains and
losses on derivatives that are related to investing activities, such
as the purchase of linefill. We also exclude the impact of
corresponding inventory valuation adjustments, as applicable, as
well as the mark-to-market adjustment related to our Preferred
Distribution Rate Reset Option.
|
(3)
| | |
We carry crude oil and NGL inventory comprised of minimum working
inventory requirements in third-party assets and other working
inventory that is needed for our commercial operations. We consider
this inventory necessary to conduct our operations and we intend to
carry this inventory for the foreseeable future. Therefore, we
classify this inventory as long-term on our balance sheet and do not
hedge the inventory with derivative instruments (similar to linefill
in our own assets). We treat the impact of changes in the average
cost of the long-term inventory (that result from fluctuations in
market prices) and writedowns of such inventory that result from
price declines as a selected item impacting comparability.
|
(4)
| | |
We have certain agreements that require counterparties to deliver,
transport or throughput a minimum volume over an agreed upon period.
Substantially all of such agreements were entered into with
counterparties to economically support the return on our capital
expenditure necessary to construct the related asset. Some of these
agreements include make-up rights if the minimum volume is not met.
We record a receivable from the counterparty in the period that
services are provided or when the transaction occurs, including
amounts for deficiency obligations from counterparties associated
with minimum volume commitments. If a counterparty has a make-up
right associated with a deficiency, we defer the revenue
attributable to the counterparty's make-up right and subsequently
recognize the revenue at the earlier of when the deficiency volume
is delivered or shipped, when the make-up right expires or when it
is determined that the counterparty's ability to utilize the make-up
right is remote. We include the impact of amounts billed to
counterparties for their deficiency obligation, net of applicable
amounts subsequently recognized into revenue, as a selected item
impacting comparability. We believe the inclusion of the
contractually committed revenues associated with that period is
meaningful to investors as the related asset has been constructed,
is standing ready to provide the committed service and the fixed
operating costs are included in the current period results.
|
(5)
| | |
Our total equity-indexed compensation expense includes expense
associated with awards that will or may be settled in units and
awards that will or may be settled in cash. The awards that will or
may be settled in units are included in our diluted net income per
unit calculation when the applicable performance criteria have been
met. We consider the compensation expense associated with these
awards as a selected item impacting comparability as the dilutive
impact of the outstanding awards is included in our diluted net
income per unit calculation and the majority of the awards are
expected to be settled in units. The portion of compensation expense
associated with awards that are certain to be settled in cash is not
considered a selected item impacting comparability.
|
(6)
| | |
During the periods presented, there were fluctuations in the value
of the Canadian dollar to the U.S. dollar, resulting in gains and
losses that were not related to our core operating results for the
period and were thus classified as a selected item impacting
comparability.
|
(7)
| | |
Includes acquisition-related expenses associated with the Alpha
Crude Connector acquisition.
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| FINANCIAL DATA RECONCILATIONS |
(in millions)
|
| |
|
| Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | Net Income to Adjusted EBITDA and Implied DCF Reconciliation | | | | | | |
Net Income
| | |
$
|
444
| | | |
$
|
203
| |
Interest expense, net
| | |
129
| | | |
112
| |
Income tax expense
| | |
66
| | | |
19
| |
Depreciation and amortization
| | |
121
| | | |
114
| |
Depreciation and amortization of unconsolidated entities (1) | | |
14
| | | |
12
| |
Selected items impacting comparability - Adjusted EBITDA (2) | | |
(262
|
)
| | |
173
|
|
Adjusted EBITDA
| | |
$
|
512
| | | |
$
|
633
| |
Interest expense, net (3) | | |
(125
|
)
| | |
(108
|
)
|
Maintenance capital
| | |
(59
|
)
| | |
(47
|
)
|
Current income tax expense
| | |
(10
|
)
| | |
(31
|
)
|
Adjusted equity earnings in unconsolidated entities, net of
distributions (4) | | |
(15
|
)
| | |
(7
|
)
|
Distributions to noncontrolling interests (5) | | |
-
|
| | |
(1
|
)
|
Implied DCF (6) | | |
$
|
303
|
| | |
$
|
439
|
|
___________________________________________
| | | | | | | | | | |
(1)
|
|
|
Adjustment to add back our proportionate share of depreciation and
amortization expense of unconsolidated entities.
|
(2)
| | |
Certain of our non-GAAP financial measures may not be impacted by
each of the selected items impacting comparability.
|
(3)
| | |
Excludes certain non-cash items impacting interest expense such as
amortization of debt issuance costs and terminated interest rate
swaps.
|
(4)
| | |
Represents the difference between non-cash equity earnings in
unconsolidated entities (adjusted for our proportionate share of
depreciation and amortization) and cash distributions received from
such entities.
|
(5)
| | |
Includes distributions that pertain to the current period's net
income, which are paid in the subsequent period.
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| COMPUTATION OF BASIC AND DILUTED ADJUSTED
NET INCOME PER COMMON UNIT(1) |
(in millions, except per unit data)
|
| |
|
| Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | Basic Adjusted Net Income per Common Unit | | | | | | |
Net income attributable to PAA
| | |
$
|
444
| | | |
$
|
202
| |
Selected items impacting comparability - Adjusted net income
attributable to PAA (2) | | |
(220
|
)
| | |
153
|
|
Adjusted net income attributable to PAA
| | |
224
| | | |
355
| |
Distributions to Series A preferred units
| | |
(34
|
)
| | |
(23
|
)
|
Distributions to general partner
| | |
-
| | | |
(155
|
)
|
Other
| | |
(4
|
)
| | |
2
|
|
Adjusted net income allocated to common unitholders
| | |
$
|
186
|
| | |
$
|
179
|
| | | | | | |
|
Basic weighted average common units outstanding
| | |
691
| | | |
398
| | | | | | | |
|
Basic adjusted net income per common unit
| | |
$
|
0.27
|
| | |
$
|
0.45
|
| | | | | | |
| Diluted Adjusted Net Income per Common Unit | | | | | | |
Net income attributable to PAA
| | |
$
|
444
| | | |
$
|
202
| |
Selected items impacting comparability - Adjusted net income
attributable to PAA (2) | | |
(220
|
)
| | |
153
|
|
Adjusted net income attributable to PAA
| | |
224
| | | |
355
| |
Distributions to Series A preferred units
| | |
(34
|
)
| | |
(23
|
)
|
Distributions to general partner
| | |
-
| | | |
(155
|
)
|
Other
| | |
(4
|
)
| | |
2
|
|
Adjusted net income allocated to common unitholders
| | |
$
|
186
|
| | |
$
|
179
|
| | | | | | |
|
Basic weighted average common units outstanding
| | |
691
| | | |
398
| |
Effect of dilutive securities: LTIP units (3) | | |
2
|
| | |
1
|
|
Diluted weighted average common units outstanding
| | |
693
|
| | |
399
|
| | | | | | |
|
Diluted adjusted net income per common unit (4) | | |
$
|
0.27
|
| | |
$
|
0.45
|
|
___________________________________________
| | | | | | | | | | |
(1)
|
|
|
We calculate adjusted net income allocated to common unitholders
based on the distributions pertaining to the current period's net
income. After adjusting for the appropriate period's distributions,
the remaining undistributed earnings or excess distributions over
earnings ("undistributed loss"), if any, are allocated to the
general partner, common unitholders and participating securities in
accordance with the contractual terms of our partnership agreement
in effect for the period and as further prescribed under the
two-class method. The Simplification Transactions, which closed on
November 15, 2016, simplified our governance structure and
permanently eliminated our IDRs and the economic rights associated
with our 2% general partner interest. As such, beginning with the
distribution pertaining to the fourth quarter of 2016, our general
partner is no longer entitled to receive distributions from these
interests.
|
(2)
| | |
Certain of our non-GAAP financial measures may not be impacted by
each of the selected items impacting comparability.
|
(3)
| | |
Our Long-term Incentive Plan ("LTIP") awards that contemplate the
issuance of common units are considered dilutive unless (i) vesting
occurs only upon the satisfaction of a performance condition and
(ii) that performance condition has yet to be satisfied. LTIP awards
that are deemed to be dilutive are reduced by a hypothetical unit
repurchase based on the remaining unamortized fair value, as
prescribed by the treasury stock method in guidance issued by the
FASB.
|
(4)
| | |
The possible conversion of our Series A preferred units was excluded
from the calculation of diluted adjusted net income per common unit
for the three months ended March 31, 2017 and 2016 as the effect was
antidilutive.
|
|
| PLAINS GP HOLDINGS AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS(1) |
(in millions, except per share data)
|
| |
|
| Three Months Ended |
|
| Three Months Ended | | | | March 31, 2017 | | | March 31, 2016 | | | | |
|
| Consolidating |
|
| | | | |
|
| Consolidating |
|
| | | | | PAA | | | Adjustments (2) | | | PAGP | | | PAA | | | Adjustments (2) | | | PAGP | REVENUES | | |
$
|
6,667
| | | |
$
|
-
| | | |
$
|
6,667
| | | |
$
|
4,111
| | | |
$
|
-
| | | |
$
|
4,111
| | | | | | | | | | | | | | | | | | | |
| COSTS AND EXPENSES | | | | | | | | | | | | | | | | | | |
Purchases and related costs
| | |
5,593
| | | |
-
| | | |
5,593
| | | |
3,348
| | | |
-
| | | |
3,348
| |
Field operating costs
| | |
288
| | | |
-
| | | |
288
| | | |
300
| | | |
-
| | | |
300
| |
General and administrative expenses
| | |
74
| | | |
1
| | | |
75
| | | |
67
| | | |
1
| | | |
68
| |
Depreciation and amortization
| | |
121
|
| | |
1
|
| | |
122
|
| | |
114
|
| | |
-
|
| | |
114
|
|
Total costs and expenses
| | |
6,076
| | | |
2
| | | |
6,078
| | | |
3,829
| | | |
1
| | | |
3,830
| | | | | | | | | | | | | | | | | | | |
| OPERATING INCOME | | |
591
| | | |
(2
|
)
| | |
589
| | | |
282
| | | |
(1
|
)
| | |
281
| | | | | | | | | | | | | | | | | | | |
| OTHER INCOME/(EXPENSE) | | | | | | | | | | | | | | | | | | |
Equity earnings in unconsolidated entities
| | |
53
| | | |
-
| | | |
53
| | | |
47
| | | |
-
| | | |
47
| |
Interest expense, net
| | |
(129
|
)
| | |
-
| | | |
(129
|
)
| | |
(112
|
)
| | |
(4
|
)
| | |
(116
|
)
|
Other income/(expense), net
| | |
(5
|
)
| | |
-
|
| | |
(5
|
)
| | |
5
|
| | |
-
|
| | |
5
|
| | | | | | | | | | | | | | | | | | |
| INCOME BEFORE TAX | | |
510
| | | |
(2
|
)
| | |
508
| | | |
222
| | | |
(5
|
)
| | |
217
| |
Current income tax expense
| | |
(10
|
)
| | |
-
| | | |
(10
|
)
| | |
(31
|
)
| | |
-
| | | |
(31
|
)
|
Deferred income tax benefit/(expense)
| | |
(56
|
)
| | |
(40
|
)
| | |
(96
|
)
| | |
12
|
| | |
(21
|
)
| | |
(9
|
)
| | | | | | | | | | | | | | | | | | |
| NET INCOME | | |
444
| | | |
(42
|
)
| | |
402
| | | |
203
| | | |
(26
|
)
| | |
177
| |
Net income attributable to noncontrolling interests
| | |
-
|
| | |
(361
|
)
| | |
(361
|
)
| | |
(1
|
)
| | |
(140
|
)
| | |
(141
|
)
| NET INCOME ATTRIBUTABLE TO PAGP | | |
$
|
444
|
| | |
$
|
(403
|
)
| | |
$
|
41
|
| | |
$
|
202
|
| | |
$
|
(166
|
)
| | |
$
|
36
|
|
| BASIC NET INCOME PER CLASS A SHARE | | |
$
|
0.34
|
| | | | | | | | |
$
|
0.39
|
|
| DILUTED NET INCOME PER CLASS A SHARE | | |
$
|
0.34
|
| | | | | | | | |
$
|
0.37
|
|
| BASIC WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | | |
120
|
| | | | | | | | |
95
|
|
| DILUTED WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | | |
120
|
| | | | | | | | |
245
|
|
___________________________________________
| | | | | | | | | | | | | | |
(1)
|
|
|
A reverse split of PAGP's Class A shares was completed on November
15, 2016. The effect of the reverse split has been retroactively
applied to all per-share amounts presented.
|
(2)
| | |
Represents the aggregate consolidating adjustments necessary to
produce consolidated financial statements for PAGP.
| | | |
|
| PLAINS GP HOLDINGS AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| CONDENSED CONSOLIDATING BALANCE SHEET DATA |
(in millions)
|
| |
|
| March 31, 2017 |
|
| December 31, 2016 | | | | |
|
| Consolidating |
|
| | | | |
|
| Consolidating |
|
| | | | | PAA | | | Adjustments (1) | | | PAGP | | | PAA | | | Adjustments (1) | | | PAGP | ASSETS | | | | | | | | | | | | | | | | | | |
Current assets
| | |
$
|
4,210
| | | |
$
|
4
| | | |
$
|
4,214
| | | |
$
|
4,272
| | | |
$
|
3
| | | |
$
|
4,275
|
Property and equipment, net
| | |
14,060
| | | |
17
| | | |
14,077
| | | |
13,872
| | | |
18
| | | |
13,890
|
Goodwill
| | |
2,596
| | | |
-
| | | |
2,596
| | | |
2,344
| | | |
-
| | | |
2,344
|
Investments in unconsolidated entities
| | |
2,469
| | | |
-
| | | |
2,469
| | | |
2,343
| | | |
-
| | | |
2,343
|
Deferred tax asset
| | |
-
| | | |
2,221
| | | |
2,221
| | | |
-
| | | |
1,876
| | | |
1,876
|
Linefill and base gas
| | |
883
| | | |
-
| | | |
883
| | | |
896
| | | |
-
| | | |
896
|
Long-term inventory
| | |
131
| | | |
-
| | | |
131
| | | |
193
| | | |
-
| | | |
193
|
Other long-term assets, net
| | |
920
|
| | |
(3
|
)
| | |
917
|
| | |
290
|
| | |
(4
|
)
| | |
286
|
Total assets
| | |
$
|
25,269
|
| | |
$
|
2,239
|
| | |
$
|
27,508
|
| | |
$
|
24,210
|
| | |
$
|
1,893
|
| | |
$
|
26,103
| | | | | | | | | | | | | | | | | | |
| LIABILITIES AND PARTNERS' CAPITAL | | | | | | | | | | | | | | | | | | |
Current liabilities
| | |
$
|
4,156
| | | |
$
|
2
| | | |
$
|
4,158
| | | |
$
|
4,664
| | | |
$
|
2
| | | |
$
|
4,666
|
Senior notes, net of unamortized discounts and debt issuance costs
| | |
9,876
| | | |
-
| | | |
9,876
| | | |
9,874
| | | |
-
| | | |
9,874
|
Other long-term debt
| | |
3
| | | |
-
| | | |
3
| | | |
250
| | | |
-
| | | |
250
|
Other long-term liabilities and deferred credits
| | |
644
|
| | |
-
|
| | |
644
|
| | |
606
|
| | |
-
|
| | |
606
|
Total liabilities
| | |
$
|
14,679
| | | |
$
|
2
| | | |
$
|
14,681
| | | |
$
|
15,394
| | | |
$
|
2
| | | |
$
|
15,396
| | | | | | | | | | | | | | | | | | |
|
Partners' capital excluding noncontrolling interests
| | |
10,534
| | | |
(7,930
|
)
| | |
2,604
| | | |
8,759
| | | |
(7,022
|
)
| | |
1,737
|
Noncontrolling interests
| | |
56
|
| | |
10,167
|
| | |
10,223
|
| | |
57
|
| | |
8,913
|
| | |
8,970
|
Total partners' capital
| | |
10,590
|
| | |
2,237
|
| | |
12,827
|
| | |
8,816
|
| | |
1,891
|
| | |
10,707
|
Total liabilities and partners' capital
| | |
$
|
25,269
|
| | |
$
|
2,239
|
| | |
$
|
27,508
|
| | |
$
|
24,210
|
| | |
$
|
1,893
|
| | |
$
|
26,103
|
___________________________________________
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
(1)
|
|
|
Represents the aggregate consolidating adjustments necessary to
produce consolidated financial statements for PAGP.
|
|
| PLAINS GP HOLDINGS AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
| COMPUTATION OF BASIC AND DILUTED NET
INCOME PER CLASS A SHARE(1) |
(in millions, except per share data)
|
| |
|
| Three Months Ended | | | | March 31, | | | | 2017 |
|
| 2016 | Basic Net Income per Class A Share | | | | | | |
Net income attributable to PAGP
| | |
$
|
41
| | | |
$
|
36
|
Basic weighted average Class A shares outstanding
| | |
120
| | | |
95
| | | | | | |
|
Basic net income per Class A share
| | |
$
|
0.34
|
| | |
$
|
0.39
| | | | | | |
| Diluted Net Income per Class A Share | | | | | | |
Net income attributable to PAGP
| | |
$
|
41
| | | |
$
|
36
|
Incremental net income attributable to PAGP resulting from assumed
exchange of AAP units and AAP Management Units
| | |
-
|
| | |
54
|
Net income attributable to PAGP including incremental net income
from assumed exchange of AAP units and AAP Management Units
| | |
$
|
41
|
| | |
$
|
90
| | | | | | |
|
Basic weighted average Class A shares outstanding
| | |
120
| | | |
95
|
Dilutive shares resulting from assumed exchange of AAP units and AAP
Management Units
| | |
-
|
| | |
150
|
Diluted weighted average Class A shares outstanding
| | |
120
|
| | |
245
| | | | | | |
|
Diluted net income per Class A share(2) | | |
$
|
0.34
|
| | |
$
|
0.37
|
___________________________________________
| | | | | | | | | |
(1)
|
|
|
A reverse split of PAGP's Class A shares was completed on November
15, 2016. The effect of the reverse split has been retroactively
applied to all per-share amounts presented.
|
(2)
| | |
For the three months ended March 31, 2017, the possible exchange
of any AAP units and certain AAP Management Units would not have
had a dilutive effect on basic net income per Class A share.
|
View source version on businesswire.com: http://www.businesswire.com/news/home/20170508006348/en/
Plains All American Pipeline, L.P. and Plains GP Holdings Roy
Lamoreaux, 866-809-1291 Vice President, Investor Relations &
Communications or Brett Magill, 866-809-1291 Manager,
Investor Relations
|
May 08, 2017 |
|