Aug 07, 2017 |
Plains All American Pipeline, L.P. and Plains GP Holdings Report Second-Quarter 2017 Results and Update 2017 Full-Year Guidance and 2018 Preliminary Forecast |
Timing of Earnings Call Changed to 5:00PM CT This Evening, August
7, 2017
Plains All American Pipeline, L.P. (NYSE:PAA)
and Plains GP Holdings (NYSE:PAGP)
today reported second-quarter 2017 results.
| Plains All American Pipeline, L.P. |
| Summary Financial Information
(unaudited)
|
(in millions, except per unit data)
|
| |
| Three Months Ended |
| |
| Six Months Ended |
| | | | June 30, | | % | | June 30, | | % | GAAP Results | | 2017 |
| 2016 | | Change | | 2017 |
| 2016 | | Change |
Net income attributable to PAA
| |
$
|
188
| | |
$
|
101
| | |
86
|
%
| |
$
|
632
| | |
$
|
302
| | |
109
|
%
|
Diluted net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.20
|
)
| |
205
|
%
| |
$
|
0.78
| | |
$
|
(0.13
|
)
| |
700
|
%
|
Diluted weighted average common units outstanding
| |
727
|
| |
398
|
| |
83
|
%
| |
710
| | |
398
| | |
78
|
%
|
Distribution per common unit declared for the period
| |
$
|
0.55
|
| |
$
|
0.70
|
| |
(21.4
|
)%
| |
| |
| | |
| | | Three Months Ended | | | | Six Months Ended | | | | | June 30, | | % | | June 30, | | % | Non-GAAP Results (1) | | 2017 | | 2016 | | Change | | 2017 | | 2016 | | Change |
Adjusted net income attributable to PAA
| |
$
|
189
| | |
$
|
136
| | |
39
|
%
| |
$
|
414
| | |
$
|
491
| | |
(16
|
)%
|
Diluted adjusted net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.12
|
)
| |
275
|
%
| |
$
|
0.47
| | |
$
|
0.33
| | |
42
|
%
|
Adjusted EBITDA (2) | |
$
|
451
| | |
$
|
474
| | |
(5
|
)%
| |
$
|
963
| | |
$
|
1,107
| | |
(13
|
)%
|
| | |
(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. |
|
"This afternoon PAA reported second-quarter results in line with the
guidance provided in May," stated Greg L. Armstrong, Chairman and CEO of
Plains All American Pipeline. "We continue to generate attractive
year-over-year growth in our fee-based segments, as second quarter 2017
results for our Transportation and Facilities segments increased an
aggregate of 10% over last year's comparative quarterly results.
Additionally, our outlook for our fee-based segments, which comprise
more than 90% of our consolidated Adjusted EBITDA, remains solid. Based
on completion of several projects and step ups in commitment levels, we
currently expect these two fee-based segments to generate approximately
15% growth in 2018.
"Unfortunately, we continue to experience significant downward pressure
in our margin-based Supply and Logistics segment. As a result, we
updated our full-year 2017 Adjusted EBITDA guidance and our 2018
preliminary forecast. The updated 2017 guidance reflects a downward
revision of $185 million, or 8%, primarily associated with the Supply &
Logistics segment. Our 2018 preliminary forecast now includes a range
with respect to our Supply & Logistics segment, from $100 million to
$300 million.
"The revisions to our updated 2017 Adjusted EBITDA guidance are
associated with our Supply and Logistics activities, primarily due to a
lack of visibility for crude oil and NGL arbitrage opportunities that we
have historically been able to capture with our asset base and business
model and margin erosion in our crude oil and NGL supply activities.
"As we will discuss on our conference call, we are taking a number of
actions to ensure we are responsive to the market changes experienced by
our Supply and Logistics businesses. These actions include changing the
way we plan to manage our distribution and taking other business,
financial and balance sheet management actions." Armstrong noted that
the conference call will be held today, August 7, 2017, at 5:00 p.m.
Central Time versus the originally scheduled time of Tuesday, August 8,
2017 at 10:00 a.m. Central Time.
Segment adjusted EBITDA for the second quarter and first half of 2017 is
presented below:
| Summary of Selected Financial Data by Segment (1)(unaudited)
| (in millions) |
|
| |
| | | | Three Months Ended | | Three Months Ended | | | June 30, 2017 | | June 30, 2016 | | | |
| |
| Supply and | | |
| |
| Supply and | | | Transportation | | Facilities | | Logistics | | Transportation | | Facilities | | Logistics |
Segment adjusted EBITDA
| |
$
|
298
|
| |
$
|
180
|
| |
$
|
(28
|
)
| |
$
|
274
|
| |
$
|
161
|
| |
$
|
39
| Percentage change in segment adjusted EBITDA versus 2016 period | | 9 | % | | 12 | % | | (172 | )% | | | | | | |
| | | Six Months Ended | | Six Months Ended | | | June 30, 2017 | | June 30, 2016 | | | | | | | Supply and | | | | | | Supply and | | | Transportation | | Facilities | | Logistics | | Transportation | | Facilities | | Logistics |
Segment adjusted EBITDA
| |
$
|
571
|
| |
$
|
368
|
| |
$
|
23
|
| |
$
|
555
|
| |
$
|
327
|
| |
$
|
224
| Percentage change in segment adjusted EBITDA versus 2016 period | | 3 | % | | 13 | % | | (90 | )% | | | | | | |
| | |
(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. |
|
Second-quarter 2017 Transportation segment adjusted EBITDA increased by
9% over comparable 2016 results. This increase was primarily driven by
increased volume on our Permian Basin assets including contributions
from the Alpha Crude Connector gathering system that we acquired in
February 2017 and contributions from newly commissioned systems,
partially offset by the effects of non-core asset sales.
Second-quarter 2017 Facilities segment adjusted EBITDA increased by 12%
versus comparable 2016 results. This increase was primarily due to
contributions from the Canadian NGL assets we acquired in August 2016,
as well as higher fees at certain of our NGL storage and fractionation
facilities. These increases were partially offset by lower U.S. rail
terminal volumes and revenues.
Second-quarter 2017 Supply and Logistics segment adjusted EBITDA
decreased by 172% relative to comparable 2016 results. This decrease was
consistent with our expectations and was due to continuing competition
and margin compression affecting our NGL and crude oil gathering and
marketing activities.
2017 Full-Year Guidance and 2018 Preliminary Forecast
The table below presents our full-year 2017 financial and operating
guidance and 2018 preliminary forecast:
| Financial and Operating Guidance(unaudited)
|
(in millions, except per barrel data)
|
| |
| Twelve Months Ended December 31, | | | |
| |
| |
| 2018 | | | 2015 | | 2016 | | 2017 (G) | | Preliminary (1) | | | | | | |
+ / -
| |
+ / -
| Segment Adjusted EBITDA | | | | | | | | |
Transportation
| |
$
|
1,056
| | |
$
|
1,141
| | |
$
|
1,295
| | | |
Facilities
| |
588
|
| |
667
|
| |
705
|
| | | Fee-Based | | $ | 1,644 | | | $ | 1,808 | | | $ | 2,000 | | | $2,350 |
Supply and Logistics
| |
568
| | |
359
| | |
75
| | |
100 - 300
|
Other income/(expense), net
| |
1
|
| |
2
|
| |
-
|
| |
| Adjusted EBITDA (2) | | $ | 2,213 |
| | $ | 2,169 |
| | $ | 2,075 |
| | $2,450 - $2,650 |
Interest expense, net (3) | |
(417
|
)
| |
(451
|
)
| |
(485
|
)
| | |
Maintenance capital
| |
(220
|
)
| |
(186
|
)
| |
(210
|
)
| | |
Current income tax expense
| |
(84
|
)
| |
(85
|
)
| |
(10
|
)
| | |
Other
| |
(18
|
)
| |
(33
|
)
| |
-
|
| |
| Implied DCF (2) | | $ | 1,474 |
| | $ | 1,414 |
| | $ | 1,370 |
| | $1,725 - $1,925 |
| Operating Data | | | | | | | | | Transportation | | | | | | | | |
Average daily volumes (MBbls/d)
| |
4,453
| | |
4,637
| | |
5,295
| | | |
Segment Adjusted EBITDA per barrel
| |
$
|
0.65
| | |
$
|
0.67
| | |
$
|
0.67
| | | | | | | | | | | |
| Facilities | | | | | | | | |
Average capacity (MMBbls/Mo)
| |
126
| | |
129
| | |
130
| | | |
Segment Adjusted EBITDA per barrel
| |
$
|
0.39
| | |
$
|
0.43
| | |
$
|
0.45
| | | | | | | | | | | |
| Supply and Logistics | | | | | | | | |
Average daily volumes (MBbls/d)
| |
1,168
| | |
1,160
| | |
1,230
| | | |
Segment Adjusted EBITDA per barrel
| |
$
|
1.33
| | |
$
|
0.85
| | |
$
|
0.17
| | | | | | | | | | | |
| Expansion Capital | | $ | 2,170 | | | $ | 1,405 | | | $ | 950 | | | | | | | | | | | |
| Third-Quarter Adjusted EBITDA as Percentage of Full Year | | 23% | | 21% | | 21% - 22% | | |
| | |
(G)
|
| 2017 Guidance forecasts are intended to be + / - amounts. | (1) | | Represents 2018 preliminary forecast as provided on May 24,
2017 at PAA 2017 Investor Day adjusted for updated Supply and
Logistics segment forecast. | (2) | | 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 and, for the
historical 2015 and 2016 periods, their 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. | (3) | | 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:
| |
| Q2 2017 |
| Q1 2017 |
| Q2 2016 | Distribution per Class A share declared for the period (1) | |
$
|
0.55
| | |
$
|
0.55
|
| |
$
|
0.62
|
| Q2 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 5:00 p.m. CT on Monday,
August 7, 2017 to discuss the following items:
-
PAA's second-quarter 2017 performance;
-
Financial and operating guidance for the full year of 2017;
-
Capitalization and liquidity; and
-
PAA and PAGP's outlook for the future.
Conference Call Webcast Instructions
To access the internet webcast please go tohttps://event.webcasts.com/starthere.jsp?ei=1153900&tp_key=0fe580a410
Alternatively, the webcast can be accessed at 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 and gains or losses
on significant asset sales 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 and NGL
market structure, grade differentials and volatility (or lack thereof);
maintenance of our credit rating and ability to receive open credit from
our suppliers and trade counterparties; environmental liabilities or
events that are not covered by an indemnity, insurance or existing
reserves; 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 failure to consummate, or significant delay in
consummating, sales of assets or interests as a part of our strategic
divestiture program; 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 approximately 5
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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | REVENUES | |
$
|
6,078
| | |
$
|
4,950
| | |
$
|
12,745
| | |
$
|
9,060
| |
| COSTS AND EXPENSES | | | | | | | | | | |
Purchases and related costs
| |
5,320
| | |
4,224
| | |
10,912
| | |
7,571
| |
Field operating costs
| |
304
| | |
303
| | |
593
| | |
603
| |
General and administrative expenses
| |
68
| | |
73
| | |
142
| | |
140
| |
Depreciation and amortization
| |
129
|
| |
204
|
|
|
250
|
| |
319
|
|
Total costs and expenses
| |
5,821
| | |
4,804
| | |
11,897
| | |
8,633
| |
| OPERATING INCOME | |
257
| | |
146
| | |
848
| | |
427
| |
| OTHER INCOME/(EXPENSE) | | | | | | | | | | |
Equity earnings in unconsolidated entities
| |
68
| | |
40
| | |
121
| | |
87
| |
Interest expense, net
| |
(127
|
)
| |
(114
|
)
| |
(256
|
)
| |
(227
|
)
|
Other income/(expense), net
| |
1
|
| |
25
|
| |
(4
|
)
| |
30
|
|
| INCOME BEFORE TAX | |
199
| | |
97
| | |
709
| | |
317
| |
Current income tax expense
| |
(1
|
)
| |
(9
|
)
| |
(11
|
)
| |
(40
|
)
|
Deferred income tax benefit/(expense)
| |
(9
|
)
| |
14
|
| |
(65
|
)
| |
27
|
|
| NET INCOME | |
189
| | |
102
| | |
633
| | |
304
| |
Net income attributable to noncontrolling interests
| |
(1
|
)
| |
(1
|
)
| |
(1
|
)
| |
(2
|
)
| NET INCOME ATTRIBUTABLE TO PAA | |
$
|
188
|
| |
$
|
101
|
| |
$
|
632
|
| |
$
|
302
|
|
| NET INCOME PER COMMON UNIT: | | | | | | | | | | |
Net income/(loss) allocated to common unitholders - Basic
| |
$
|
148
| | |
$
|
(81
|
)
| |
$
|
555
| | |
$
|
(53
|
)
|
Basic weighted average common units outstanding
| |
725
| | |
398
| | |
708
| | |
398
| |
Basic net income/(loss) per common unit
| |
$
|
0.21
|
| |
$
|
(0.20
|
)
| |
$
|
0.78
|
| |
$
|
(0.13
|
)
|
|
Net income/(loss) allocated to common unitholders - Diluted
| |
$
|
148
| | |
$
|
(81
|
)
| |
$
|
555
| | |
$
|
(53
|
)
|
Diluted weighted average common units outstanding
| |
727
| | |
398
| | |
710
| | |
398
| |
Diluted net income/(loss) per common unit
| |
$
|
0.21
|
| |
$
|
(0.20
|
)
| |
$
|
0.78
|
| |
$
|
(0.13
|
)
|
| NON-GAAP ADJUSTED RESULTS |
(in millions, except per unit data)
|
| | | Three Months Ended | | Six Months Ended | | | June 30, | | June 30, | | | 2017 | | 2016 | | 2017 | | 2016 |
Adjusted net income attributable to PAA
| |
$
|
189
|
| |
$
|
136
|
| |
$
|
414
|
| |
$
|
491
|
| | |
|
Diluted adjusted net income/(loss) per common unit
| |
$
|
0.21
|
| |
$
|
(0.12
|
)
| |
$
|
0.47
|
| |
$
|
0.33
|
| | |
|
Adjusted EBITDA
| |
$
|
451
|
| |
$
|
474
|
| |
$
|
963
|
| |
$
|
1,107
|
|
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
|
| CONDENSED CONSOLIDATED BALANCE SHEET DATA |
(in millions)
|
| |
| June 30, |
| December 31, | | | 2017 | | 2016 | ASSETS | | | | |
Current assets
| |
$
|
3,528
| |
$
|
4,272
|
Property and equipment, net
| |
14,322
| |
13,872
|
Goodwill
| |
2,596
| |
2,344
|
Investments in unconsolidated entities
| |
2,626
| |
2,343
|
Linefill and base gas
| |
894
| |
896
|
Long-term inventory
| |
117
| |
193
|
Other long-term assets, net
| |
921
| |
290
|
Total assets
| |
$
|
25,004
| |
$
|
24,210
| | | | |
| LIABILITIES AND PARTNERS' CAPITAL | | | | |
Current liabilities
| |
$
|
3,757
| |
$
|
4,664
|
Senior notes, net of unamortized discounts and debt issuance costs
| |
9,878
| |
9,874
|
Other long-term debt
| |
162
| |
250
|
Other long-term liabilities and deferred credits
| |
706
| |
606
|
Total liabilities
| |
$
|
14,503
| |
$
|
15,394
| | | | |
|
Partners' capital excluding noncontrolling interests
| |
10,444
| |
8,759
|
Noncontrolling interests
| |
57
| |
57
|
Total partners' capital
| |
10,501
| |
8,816
|
Total liabilities and partners' capital
| |
$
|
25,004
| |
$
|
24,210
|
| DEBT CAPITALIZATION RATIOS |
(in millions)
|
| | | June 30, | | December 31, | | | 2017 | | 2016 | | | | | | | |
|
Short-term debt (1) | |
$
|
1,114
| | |
$
|
1,715
| |
Long-term debt
| |
10,040
|
| |
10,124
|
|
Total debt
| |
$
|
11,154
|
| |
$
|
11,839
|
| | | | |
|
Long-term debt
| |
$
|
10,040
| | |
$
|
10,124
| |
Partners' capital
| |
10,501
|
| |
8,816
|
|
Total book capitalization
| |
$
|
20,541
|
| |
$
|
18,940
|
|
Total book capitalization, including short-term debt
| |
$
|
21,655
|
| |
$
|
20,655
|
|
|
Long-term debt-to-total book capitalization
| |
49
|
%
| |
53
|
%
|
Total debt-to-total book capitalization, including short-term debt
| |
52
|
%
| |
57
|
%
|
| | |
(1) |
| As of June 30, 2017 and December 31, 2016, short-term debt
includes borrowings of approximately $1,099 million and $1,303
million, respectively, for short-term hedged inventory purchases
and borrowings of approximately $12 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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Transportation segment (average daily volumes in thousands of
barrels per day): | | | | | | | | |
Tariff activities volumes
| | | | | | | | |
Crude oil pipelines (by region):
| | | | | | | | |
Permian Basin (2) | |
2,761
| |
2,178
| |
2,614
| |
2,112
|
South Texas / Eagle Ford (2) | |
349
| |
274
| |
330
| |
294
|
Western
| |
179
| |
211
| |
184
| |
193
|
Rocky Mountain (2) | |
444
| |
431
| |
415
| |
434
|
Gulf Coast
| |
385
| |
613
| |
364
| |
597
|
Central (2) | |
427
| |
398
| |
416
| |
388
|
Canada
| |
363
| |
379
| |
363
| |
386
|
Crude oil pipelines
| |
4,908
| |
4,484
| |
4,686
| |
4,404
|
NGL pipelines
| |
156
| |
182
| |
168
| |
180
|
Tariff activities total volumes
| |
5,064
| |
4,666
| |
4,854
| |
4,584
|
Trucking volumes
| |
99
| |
115
| |
106
| |
110
|
Transportation segment total volumes
| |
5,163
| |
4,781
| |
4,960
| |
4,694
|
| Facilities segment (average monthly volumes): | | | | | | | | |
Crude oil, refined products and NGL terminalling and storage
(average monthly capacity in millions of barrels)
| |
112
| |
105
| |
112
| |
105
|
Rail load / unload volumes (average volumes in thousands of barrels
per day)
| |
48
| |
127
| |
41
| |
109
|
Natural gas storage (average monthly working capacity in billions of
cubic feet)
| |
97
| |
97
| |
97
| |
97
|
NGL fractionation (average volumes in thousands of barrels per day)
| |
119
| |
105
| |
122
| |
110
|
Facilities segment total volumes (average monthly volumes in
millions of barrels) (3) | |
134
| |
128
| |
133
| |
128
|
| Supply and Logistics segment (average daily volumes in thousands
of barrels per day): | | | | | | | | |
Crude oil lease gathering purchases
| |
940
| |
885
| |
929
| |
899
|
NGL sales
| |
210
| |
176
| |
280
| |
242
|
Waterborne cargos
| |
-
| |
5
| |
3
| |
6
|
Supply and Logistics segment total volumes
| |
1,150
| |
1,066
| |
1,212
| |
1,147
|
| | |
(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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Basic Net Income per Common Unit | | | | | | | | |
Net income attributable to PAA
| |
$
|
188
| | |
$
|
101
| | |
$
|
632
| | |
$
|
302
| |
Distributions to Series A preferred units
| |
(35
|
)
| |
(33
|
)
| |
(69
|
)
| |
(55
|
)
|
Distributions to general partner
| |
-
| | |
(155
|
)
| |
-
| | |
(310
|
)
|
Other
| |
(5
|
)
| |
6
|
| |
(8
|
)
| |
10
|
|
Net income/(loss) allocated to common unitholders
| |
$
|
148
|
| |
$
|
(81
|
)
| |
$
|
555
|
| |
$
|
(53
|
)
| | | | | | | | |
|
Basic weighted average common units outstanding
| |
725
| | |
398
| | |
708
| | |
398
| | | | | | | | | |
|
Basic net income/(loss) per common unit
| |
$
|
0.21
|
| |
$
|
(0.20
|
)
| |
$
|
0.78
|
| |
$
|
(0.13
|
)
| | | | | | | | |
| Diluted Net Income per Common Unit | | | | | | | | |
Net income attributable to PAA
| |
$
|
188
| | |
$
|
101
| | |
$
|
632
| | |
$
|
302
| |
Distributions to Series A preferred units
| |
(35
|
)
| |
(33
|
)
| |
(69
|
)
| |
(55
|
)
|
Distributions to general partner
| |
-
| | |
(155
|
)
| |
-
| | |
(310
|
)
|
Other
| |
(5
|
)
| |
6
|
| |
(8
|
)
| |
10
|
|
Net income/(loss) allocated to common unitholders
| |
$
|
148
|
| |
$
|
(81
|
)
| |
$
|
555
|
| |
$
|
(53
|
)
| | | | | | | | |
|
Basic weighted average common units outstanding
| |
725
| | |
398
| | |
708
| | |
398
| |
Effect of dilutive securities:
| | | | | | | | |
LTIP units (2) | |
2
|
| |
-
|
| |
2
|
| |
-
|
|
Diluted weighted average common units outstanding
| |
727
|
| |
398
|
| |
710
|
| |
398
|
| | | | | | | | |
|
Diluted net income/(loss) per common unit (3) | |
$
|
0.21
|
| |
$
|
(0.20
|
)
| |
$
|
0.78
|
| |
$
|
(0.13
|
)
|
| | |
(1) |
| We calculate net income/(loss) 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) | | 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. Such LTIP awards were excluded
from the calculation of diluted net loss per common unit for the
three and six months ended June 30, 2016 as the effect was
antidilutive. | (3) | | The possible conversion of our Series A preferred units was
excluded from the calculation of diluted net income/(loss) per
common unit for the three and six months ended June 30, 2017 and
2016 as the effect was antidilutive. |
|
| 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 | | | June 30, 2017 | | June 30, 2016 | | | |
| |
| Supply and | | |
| |
| Supply and | | | Transportation | | Facilities | | Logistics | | Transportation | | Facilities | | Logistics |
Revenues (2) | |
$
|
425
| | |
$
|
289
| | |
$
|
5,783
| | |
$
|
403
| | |
$
|
270
| | |
$
|
4,652
| |
Purchases and related costs (2) | |
(21
|
)
| |
(6
|
)
| |
(5,708
|
)
| |
(24
|
)
| |
(6
|
)
| |
(4,566
|
)
|
Field operating costs (2) (3) | |
(155
|
)
| |
(85
|
)
| |
(65
|
)
| |
(136
|
)
| |
(88
|
)
| |
(74
|
)
|
Equity-indexed compensation expense - field operating costs
| |
(3
|
)
| |
-
| | |
-
| | |
(5
|
)
| |
(2
|
)
| |
(1
|
)
|
Segment general and administrative expenses (3) (4) | |
(21
|
)
| |
(16
|
)
| |
(23
|
)
| |
(21
|
)
| |
(14
|
)
| |
(24
|
)
|
Equity-indexed compensation expense - general and administrative
| |
(3
|
)
| |
(2
|
)
| |
(3
|
)
| |
(5
|
)
| |
(4
|
)
| |
(5
|
)
|
Equity earnings in unconsolidated entities
| |
68
| | |
-
| | |
-
| | |
40
| | |
-
| | |
-
| |
|
Adjustments: (5) | | | | | | | | | | | | |
Depreciation and amortization of unconsolidated entities
| |
4
| | |
-
| | |
-
| | |
13
| | |
-
| | |
-
| |
(Gains)/losses from derivative activities net of inventory valuation
adjustments
| |
-
| | |
(1
|
)
| |
(12
|
)
| |
-
| | |
(2
|
)
| |
121
| |
Long-term inventory costing adjustments
| |
-
| | |
-
| | |
7
| | |
-
| | |
-
| | |
(67
|
)
|
Deficiencies under minimum volume commitments, net
| |
(14
|
)
| |
-
| | |
-
| | |
4
| | |
4
| | |
-
| |
Equity-indexed compensation expense
| |
5
| | |
1
| | |
3
| | |
5
| | |
3
| | |
3
| |
Net gain on foreign currency revaluation
| |
-
| | |
-
| | |
(10
|
)
| |
-
| | |
-
| | |
-
| |
Line 901 incident
| |
12
| | |
-
| | |
-
| | |
-
| | |
-
| | |
-
| |
Significant acquisition-related expenses
| |
1
|
| |
-
|
| |
-
|
| |
-
|
| |
-
|
| |
-
|
|
Segment adjusted EBITDA
| |
$
|
298
|
| |
$
|
180
|
| |
$
|
(28
|
)
| |
$
|
274
|
| |
$
|
161
|
| |
$
|
39
|
|
|
Maintenance capital
| |
$
|
27
|
| |
$
|
39
|
| |
$
|
5
|
| |
$
|
23
|
| |
$
|
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 for
additional discussion. |
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
|
| SELECTED FINANCIAL DATA BY SEGMENT(1) |
(in millions)
|
| |
| Six Months Ended |
| Six Months Ended | | | June 30, 2017 | | June 30, 2016 | | | |
| |
| Supply and | | |
| |
| Supply and | | | Transportation | | Facilities | | Logistics | | Transportation | | Facilities | | Logistics |
Revenues (2) | |
$
|
814
| | |
$
|
582
| | |
$
|
12,184
| | |
$
|
787
| | |
$
|
535
| | |
$
|
8,473
| |
Purchases and related costs (2) | |
(45
|
)
| |
(17
|
)
| |
(11,678
|
)
| |
(45
|
)
| |
(11
|
)
| |
(8,243
|
)
|
Field operating costs (2) (3) | |
(293
|
)
| |
(168
|
)
| |
(131
|
)
| |
(274
|
)
| |
(173
|
)
| |
(155
|
)
|
Equity-indexed compensation expense - field operating costs
| |
(6
|
)
| |
(1
|
)
| |
(1
|
)
| |
(5
|
)
| |
(2
|
)
| |
(1
|
)
|
Segment general and administrative expenses (3) (4) | |
(48
|
)
| |
(34
|
)
| |
(46
|
)
| |
(44
|
)
| |
(30
|
)
| |
(48
|
)
|
Equity-indexed compensation expense - general and administrative
| |
(5
|
)
| |
(3
|
)
| |
(6
|
)
| |
(7
|
)
| |
(4
|
)
| |
(7
|
)
|
Equity earnings in unconsolidated entities
| |
121
| | |
-
| | |
-
| | |
87
| | |
-
| | |
-
| |
|
Adjustments: (5) | | | | | | | | | | | | |
Depreciation and amortization of unconsolidated entities
| |
18
| | |
-
| | |
-
| | |
25
| | |
-
| | |
-
| |
(Gains)/losses from derivative activities net of inventory valuation
adjustments
| |
-
| | |
1
| | |
(303
|
)
| |
-
| | |
(1
|
)
| |
243
| |
Long-term inventory costing adjustments
| |
-
| | |
-
| | |
14
| | |
-
| | |
-
| | |
(44
|
)
|
Deficiencies under minimum volume commitments, net
| |
(9
|
)
| |
6
| | |
-
| | |
24
| | |
10
| | |
-
| |
Equity-indexed compensation expense
| |
6
| | |
2
| | |
4
| | |
7
| | |
3
| | |
5
| |
Net (gain)/loss on foreign currency revaluation
| |
-
| | |
-
| | |
(14
|
)
| |
-
| | |
-
| | |
1
| |
Line 901 incident
| |
12
| | |
-
| | |
-
| | |
-
| | |
-
| | |
-
| |
Significant acquisition-related expenses
| |
6
|
| |
-
|
| |
-
|
| |
-
|
| |
-
|
| |
-
|
|
Segment adjusted EBITDA
| |
$
|
571
|
| |
$
|
368
|
| |
$
|
23
|
| |
$
|
555
|
| |
$
|
327
|
| |
$
|
224
|
|
|
Maintenance capital
| |
$
|
57
|
| |
$
|
66
|
| |
$
|
8
|
| |
$
|
57
|
| |
$
|
18
|
| |
$
|
6
|
|
| | |
(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 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 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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Selected Items Impacting Comparability: (1) | | | | | | | | |
Gains/(losses) from derivative activities net of inventory valuation
adjustments (2) | |
$
|
15
| | |
$
|
(93
|
)
| |
$
|
300
| | |
$
|
(216
|
)
|
Long-term inventory costing adjustments (3) | |
(7
|
)
| |
67
| | |
(14
|
)
| |
44
| |
Deficiencies under minimum volume commitments, net (4) | |
14
| | |
(8
|
)
| |
3
| | |
(34
|
)
|
Equity-indexed compensation expense (5) | |
(9
|
)
| |
(11
|
)
| |
(12
|
)
| |
(15
|
)
|
Net gain/(loss) on foreign currency revaluation (6) | |
8
| | |
(1
|
)
| |
11
| | |
2
| |
Line 901 incident (7) | |
(12
|
)
| |
-
| | |
(12
|
)
| |
-
| |
Significant acquisition-related expenses (8) | |
(1
|
)
| |
-
|
| |
(6
|
)
| |
-
|
|
Selected items impacting comparability - Adjusted EBITDA
| |
$
|
8
| | |
$
|
(46
|
)
| |
$
|
270
| | |
$
|
(219
|
)
|
Losses from derivative activities (2) | |
(2
|
)
| |
-
| | |
(2
|
)
| |
-
| |
Tax effect on selected items impacting comparability
| |
(7
|
)
| |
11
|
| |
(50
|
)
| |
30
|
|
Selected items impacting comparability - Adjusted net income
attributable to PAA
| |
$
|
(1
|
)
| |
$
|
(35
|
)
| |
$
|
218
|
| |
$
|
(189
|
)
|
| | |
(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 costs recognized during the period related to the
Line 901 incident that occurred in May 2015, net of amounts we
believe are probable of recovery from insurance. | (8) | | Includes acquisition-related expenses associated with the
Alpha Crude Connector acquisition. |
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
|
| NON-GAAP RECONCILIATIONS |
(in millions, except per unit data)
|
| |
| Three Months Ended |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Net Income to Adjusted EBITDA and Implied DCF Reconciliation | | | | | | | | |
Net Income
| |
$
|
189
| | |
$
|
102
| | |
$
|
633
| | |
$
|
304
| |
Interest expense, net
| |
127
| | |
114
| | |
256
| | |
227
| |
Income tax (benefit)/expense
| |
10
| | |
(5
|
)
| |
76
| | |
13
| |
Depreciation and amortization
| |
129
| | |
204
| | |
250
| | |
319
| |
Depreciation and amortization of unconsolidated entities (1) | |
4
| | |
13
| | |
18
| | |
25
| |
Selected items impacting comparability - Adjusted EBITDA (2) | |
(8
|
)
| |
46
|
| |
(270
|
)
| |
219
|
|
Adjusted EBITDA
| |
$
|
451
| | |
$
|
474
| | |
$
|
963
| | |
$
|
1,107
| |
Interest expense, net (3) | |
(121
|
)
| |
(110
|
)
| |
(246
|
)
| |
(219
|
)
|
Maintenance capital
| |
(71
|
)
| |
(35
|
)
| |
(131
|
)
| |
(81
|
)
|
Current income tax expense
| |
(1
|
)
| |
(9
|
)
| |
(11
|
)
| |
(40
|
)
|
Adjusted equity earnings in unconsolidated entities, net of
distributions (4) | |
32
| | |
(5
|
)
| |
18
| | |
(11
|
)
|
Distributions to noncontrolling interests (5) | |
(1
|
)
| |
(1
|
)
| |
(1
|
)
| |
(2
|
)
|
Implied DCF (6) | |
$
|
289
|
| |
$
|
314
|
| |
$
|
592
|
| |
$
|
754
|
|
| | |
(1) |
| Adjustment to add back our proportionate share of
depreciation and amortization expense and gains or losses on
significant asset sales 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 gains or losses on significant
asset sales) and cash distributions received from such entities. | (5) | | Includes cash distributions that pertain to the current
period's net income, which are paid in the subsequent period. | (6) | | Including net costs recognized during the periods related to
the Line 901 incident that occurred in May 2015, Implied DCF would
have been $277 million and $580 million for the three and six
months ended June 30, 2017, respectively. |
|
| |
| Three Months Ended |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Net Income Per Common Unit to Adjusted Net Income Per Common Unit
Reconciliation | | | | | | | | |
Basic net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.20
|
)
| |
$
|
0.78
| | |
$
|
(0.13
|
)
|
Selected items impacting comparability (1) | |
-
|
| |
0.08
|
| |
(0.31
|
)
| |
0.46
|
|
Basic adjusted net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.12
|
)
| |
$
|
0.47
| | |
$
|
0.33
| |
|
Diluted net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.20
|
)
| |
$
|
0.78
| | |
$
|
(0.13
|
)
|
Selected items impacting comparability (1) | |
-
|
| |
0.08
|
| |
(0.31
|
)
| |
0.46
|
|
Diluted adjusted net income/(loss) per common unit
| |
$
|
0.21
| | |
$
|
(0.12
|
)
| |
$
|
0.47
| | |
$
|
0.33
| |
| | |
(1) |
| See the "Selected Items Impacting Comparability" and the
"Computation of Basic and Diluted Adjusted Net Income Per Common
Unit" tables for additional information. |
|
| PLAINS ALL AMERICAN PIPELINE, L.P. AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
|
| NON-GAAP RECONCILIATIONS (continued) |
(in millions, except per unit data)
|
| |
| Twelve Months Ended | | | December 31, | | | 2016 |
| 2015 | Net Income to Adjusted EBITDA and Implied DCF Reconciliation | | | | |
Net Income
| |
$
|
730
| | |
$
|
906
| |
Interest expense, net
| |
467
| | |
432
| |
Income tax expense
| |
25
| | |
100
| |
Depreciation and amortization
| |
494
| | |
432
| |
Depreciation and amortization of unconsolidated entities (1) | |
50
| | |
45
| |
Selected items impacting comparability - Adjusted EBITDA
| |
403
|
| |
298
|
|
Adjusted EBITDA
| |
$
|
2,169
| | |
$
|
2,213
| |
Interest expense, net (2) | |
(451
|
)
| |
(417
|
)
|
Maintenance capital
| |
(186
|
)
| |
(220
|
)
|
Current income tax expense
| |
(85
|
)
| |
(84
|
)
|
Adjusted equity earnings in unconsolidated entities, net of
distributions (3) | |
(29
|
)
| |
(14
|
)
|
Distributions to noncontrolling interests (4) | |
(4
|
)
| |
(4
|
)
|
Implied DCF
| |
$
|
1,414
|
| |
$
|
1,474
|
|
| | |
(1) |
| Adjustment to add back our proportionate share of
depreciation and amortization expense and gains or losses on
significant asset sales of unconsolidated entities. | (2) | | Excludes certain non-cash items impacting interest expense
such as amortization of debt issuance costs and terminated
interest rate swaps. | (3) | | Represents the difference between non-cash equity earnings in
unconsolidated entities (adjusted for our proportionate share of
depreciation and amortization and gains or losses on significant
asset sales) and cash distributions received from such entities. | (4) | | Includes cash 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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Basic Adjusted Net Income per Common Unit | | | | | | | | |
Net income attributable to PAA
| |
$
|
188
| | |
$
|
101
| | |
$
|
632
| | |
$
|
302
| |
Selected items impacting comparability - Adjusted net income
attributable to PAA (2) | |
1
|
| |
35
|
| |
(218
|
)
| |
189
|
|
Adjusted net income attributable to PAA
| |
189
| | |
136
| | |
414
| | |
491
| |
Distributions to Series A preferred units
| |
(35
|
)
| |
(33
|
)
| |
(69
|
)
| |
(55
|
)
|
Distributions to general partner
| |
-
| | |
(155
|
)
| |
-
| | |
(310
|
)
|
Other
| |
(5
|
)
| |
5
|
| |
(8
|
)
| |
6
|
|
Adjusted net income/(loss) allocated to common unitholders
| |
$
|
149
|
| |
$
|
(47
|
)
| |
$
|
337
|
| |
$
|
132
|
|
|
Basic weighted average common units outstanding
| |
725
| | |
398
| | |
708
| | |
398
| | | | | | | | | |
|
Basic adjusted net income/(loss) per common unit
| |
$
|
0.21
|
| |
$
|
(0.12
|
)
| |
$
|
0.47
|
| |
$
|
0.33
|
|
| Diluted Adjusted Net Income per Common Unit | | | | | | | | |
Net income attributable to PAA
| |
$
|
188
| | |
$
|
101
| | |
$
|
632
| | |
$
|
302
| |
Selected items impacting comparability - Adjusted net income
attributable to PAA (2) | |
1
|
| |
35
|
| |
(218
|
)
| |
189
|
|
Adjusted net income attributable to PAA
| |
189
| | |
136
| | |
414
| | |
491
| |
Distributions to Series A preferred units
| |
(35
|
)
| |
(33
|
)
| |
(69
|
)
| |
(55
|
)
|
Distributions to general partner
| |
-
| | |
(155
|
)
| |
-
| | |
(310
|
)
|
Other
| |
(5
|
)
| |
5
|
| |
(8
|
)
| |
6
|
|
Adjusted net income/(loss) allocated to common unitholders
| |
$
|
149
|
| |
$
|
(47
|
)
| |
$
|
337
|
| |
$
|
132
|
|
|
Basic weighted average common units outstanding
| |
725
| | |
398
| | |
708
| | |
398
| |
Effect of dilutive securities:
| | | | | | | | |
LTIP units (3) | |
2
|
| |
-
|
| |
2
|
| |
1
|
|
Diluted weighted average common units outstanding
| |
727
|
| |
398
|
| |
710
|
| |
399
|
|
|
Diluted adjusted net income/(loss) per common unit (4) | |
$
|
0.21
|
| |
$
|
(0.12
|
)
| |
$
|
0.47
|
| |
$
|
0.33
|
|
| | |
(1) |
| We calculate adjusted net income/(loss) 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 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. Such LTIP
awards were excluded from the calculation of diluted adjusted net
loss per common unit for the three months ended June 30, 2016 as
the effect was antidilutive. | (4) | | The possible conversion of our Series A preferred units was
excluded from the calculation of diluted adjusted net
income/(loss) per common unit for the three and six months ended
June 30, 2017 and 2016 as the effect was antidilutive. |
|
| PLAINS GP HOLDINGS AND SUBSIDIARIES | FINANCIAL SUMMARY (unaudited)
|
|
| CONDENSED CONSOLIDATING STATEMENTS OF
OPERATIONS(1) |
(in millions, except per share data)
|
| |
| Three Months Ended |
| Three Months Ended | | | June 30, 2017 | | June 30, 2016 | | | |
| Consolidating |
| | | |
| Consolidating |
| | | | PAA | | Adjustments (2) | | PAGP | | PAA | | Adjustments (2) | | PAGP | REVENUES | |
$
|
6,078
| | |
$
|
-
| | |
$
|
6,078
| | |
$
|
4,950
| | |
$
|
-
| | |
$
|
4,950
| | | | | | | | | | | | | |
| COSTS AND EXPENSES | | | | | | | | | | | | |
Purchases and related costs
| |
5,320
| | |
-
| | |
5,320
| | |
4,224
| | |
-
| | |
4,224
| |
Field operating costs
| |
304
| | |
-
| | |
304
| | |
303
| | |
-
| | |
303
| |
General and administrative expenses
| |
68
| | |
1
| | |
69
| | |
73
| | |
-
| | |
73
| |
Depreciation and amortization
| |
129
|
| |
-
|
| |
129
|
| |
204
|
| |
1
|
| |
205
|
|
Total costs and expenses
| |
5,821
| | |
1
| | |
5,822
| | |
4,804
| | |
1
| | |
4,805
| |
| OPERATING INCOME | |
257
| | |
(1
|
)
| |
256
| | |
146
| | |
(1
|
)
| |
145
| |
| OTHER INCOME/(EXPENSE) | | | | | | | | | | | | |
Equity earnings in unconsolidated entities
| |
68
| | |
-
| | |
68
| | |
40
| | |
-
| | |
40
| |
Interest expense, net
| |
(127
|
)
| |
-
| | |
(127
|
)
| |
(114
|
)
| |
(4
|
)
| |
(118
|
)
|
Other income, net
| |
1
|
| |
-
|
| |
1
|
| |
25
|
| |
-
|
| |
25
|
|
| INCOME BEFORE TAX | |
199
| | |
(1
|
)
| |
198
| | |
97
| | |
(5
|
)
| |
92
| |
Current income tax expense
| |
(1
|
)
| |
-
| | |
(1
|
)
| |
(9
|
)
| |
-
| | |
(9
|
)
|
Deferred income tax benefit/(expense)
| |
(9
|
)
| |
(14
|
)
| |
(23
|
)
| |
14
|
| |
(15
|
)
| |
(1
|
)
|
| NET INCOME | |
189
| | |
(15
|
)
| |
174
| | |
102
| | |
(20
|
)
| |
82
| |
Net income attributable to noncontrolling interests
| |
(1
|
)
| |
(149
|
)
| |
(150
|
)
| |
(1
|
)
| |
(39
|
)
| |
(40
|
)
| NET INCOME ATTRIBUTABLE TO PAGP | |
$
|
188
|
| |
$
|
(164
|
)
| |
$
|
24
|
| |
$
|
101
|
| |
$
|
(59
|
)
| |
$
|
42
|
|
| BASIC NET INCOME PER CLASS A SHARE | |
$
|
0.16
|
| | | | | |
$
|
0.41
|
|
| DILUTED NET INCOME PER CLASS A SHARE | |
$
|
0.16
|
| | | | | |
$
|
0.40
|
|
| BASIC WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | |
153
|
| | | | | |
100
|
|
| DILUTED WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | |
153
|
| | | | | |
234
|
|
| | | |
(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 share and 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 STATEMENTS OF
OPERATIONS(1) |
(in millions, except per share data)
|
| |
| Six Months Ended |
| Six Months Ended | | | June 30, 2017 | | June 30, 2016 | | | |
| Consolidating |
| | | |
| Consolidating |
| | | | PAA | | Adjustments (2) | | PAGP | | PAA | | Adjustments (2) | | PAGP | REVENUES | |
$
|
12,745
| | |
$
|
-
| | |
$
|
12,745
| | |
$
|
9,060
| | |
$
|
-
| | |
$
|
9,060
| |
| COSTS AND EXPENSES | | | | | | | | | | | | |
Purchases and related costs
| |
10,912
| | |
-
| | |
10,912
| | |
7,571
| | |
-
| | |
7,571
| |
Field operating costs
| |
593
| | |
-
| | |
593
| | |
603
| | |
-
| | |
603
| |
General and administrative expenses
| |
142
| | |
3
| | |
145
| | |
140
| | |
1
| | |
141
| |
Depreciation and amortization
| |
250
|
| |
1
|
| |
251
|
| |
319
|
| |
1
|
| |
320
|
|
Total costs and expenses
| |
11,897
| | |
4
| | |
11,901
| | |
8,633
| | |
2
| | |
8,635
| |
| OPERATING INCOME | |
848
| | |
(4
|
)
| |
844
| | |
427
| | |
(2
|
)
| |
425
| |
| OTHER INCOME/(EXPENSE) | | | | | | | | | | | | |
Equity earnings in unconsolidated entities
| |
121
| | |
-
| | |
121
| | |
87
| | |
-
| | |
87
| |
Interest expense, net
| |
(256
|
)
| |
-
| | |
(256
|
)
| |
(227
|
)
| |
(6
|
)
| |
(233
|
)
|
Other income/(expense), net
| |
(4
|
)
| |
-
|
| |
(4
|
)
| |
30
|
| |
-
|
| |
30
|
|
| INCOME BEFORE TAX | |
709
| | |
(4
|
)
| |
705
| | |
317
| | |
(8
|
)
| |
309
| |
Current income tax expense
| |
(11
|
)
| |
-
| | |
(11
|
)
| |
(40
|
)
| |
-
| | |
(40
|
)
|
Deferred income tax benefit/(expense)
| |
(65
|
)
| |
(54
|
)
| |
(119
|
)
| |
27
|
| |
(37
|
)
| |
(10
|
)
|
| NET INCOME | |
633
| | |
(58
|
)
| |
575
| | |
304
| | |
(45
|
)
| |
259
| |
Net income attributable to noncontrolling interests
| |
(1
|
)
| |
(509
|
)
| |
(510
|
)
| |
(2
|
)
| |
(179
|
)
| |
(181
|
)
| NET INCOME ATTRIBUTABLE TO PAGP | |
$
|
632
|
| |
$
|
(567
|
)
| |
$
|
65
|
| |
$
|
302
|
| |
$
|
(224
|
)
| |
$
|
78
|
|
| BASIC NET INCOME PER CLASS A SHARE | |
$
|
0.47
|
| | | | | |
$
|
0.80
|
|
| DILUTED NET INCOME PER CLASS A SHARE | |
$
|
0.47
|
| | | | | |
$
|
0.77
|
|
| BASIC WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | |
136
|
| | | | | |
98
|
|
| DILUTED WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING | |
136
|
| | | | | |
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 share and 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)
|
| |
| June 30, 2017 |
| December 31, 2016 | | | |
| Consolidating |
| | | |
| Consolidating |
| | | | PAA | | Adjustments (1) | | PAGP | | PAA | | Adjustments (1) | | PAGP | ASSETS | | | | | | | | | | | | |
Current assets
| |
$
|
3,528
| | |
$
|
3
| | |
$
|
3,531
| | |
$
|
4,272
| | |
$
|
3
| | |
$4,275
|
Property and equipment, net
| |
14,322
| | |
16
| | |
14,338
| | |
13,872
| | |
18
| | |
13,890
|
Goodwill
| |
2,596
| | |
-
| | |
2,596
| | |
2,344
| | |
-
| | |
2,344
|
Investments in unconsolidated entities
| |
2,626
| | |
-
| | |
2,626
| | |
2,343
| | |
-
| | |
2,343
|
Deferred tax asset
| |
-
| | |
2,214
| | |
2,214
| | |
-
| | |
1,876
| | |
1,876
|
Linefill and base gas
| |
894
| | |
-
| | |
894
| | |
896
| | |
-
| | |
896
|
Long-term inventory
| |
117
| | |
-
| | |
117
| | |
193
| | |
-
| | |
193
|
Other long-term assets, net
| |
921
|
| |
(2
|
)
| |
919
|
| |
290
|
| |
(4
|
)
| |
286
|
Total assets
| |
$
|
25,004
|
| |
$
|
2,231
|
| |
$
|
27,235
|
| |
$
|
24,210
|
| |
$
|
1,893
|
| |
$26,103
|
| LIABILITIES AND PARTNERS' CAPITAL | | | | | | | | | | | | |
Current liabilities
| |
$
|
3,757
| | |
$
|
2
| | |
$
|
3,759
| | |
$
|
4,664
| | |
$
|
2
| | |
$4,666
|
Senior notes, net of unamortized discounts and debt issuance costs
| |
9,878
| | |
-
| | |
9,878
| | |
9,874
| | |
-
| | |
9,874
|
Other long-term debt
| |
162
| | |
-
| | |
162
| | |
250
| | |
-
| | |
250
|
Other long-term liabilities and deferred credits
| |
706
|
| |
-
|
| |
706
|
| |
606
|
| |
-
|
| |
606
|
Total liabilities
| |
$
|
14,503
| | |
$
|
2
| | |
$
|
14,505
| | |
$
|
15,394
| | |
$
|
2
| | |
$15,396
|
|
Partners' capital excluding noncontrolling interests
| |
10,444
| | |
(7,866
|
)
| |
2,578
| | |
8,759
| | |
(7,022
|
)
| |
1,737
|
Noncontrolling interests
| |
57
|
| |
10,095
|
| |
10,152
|
| |
57
|
| |
8,913
|
| |
8,970
|
Total partners' capital
| |
10,501
|
| |
2,229
|
| |
12,730
|
| |
8,816
|
| |
1,891
|
| |
10,707
|
Total liabilities and partners' capital
| |
$
|
25,004
|
| |
$
|
2,231
|
| |
$
|
27,235
|
| |
$
|
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 |
| Six Months Ended | | | June 30, | | June 30, | | | 2017 |
| 2016 | | 2017 |
| 2016 | Basic Net Income per Class A Share | | | | | | | | |
Net income attributable to PAGP
| |
$
|
24
| | |
$
|
42
| | |
$
|
65
| | |
$
|
78
|
Basic weighted average Class A shares outstanding
| |
153
| | |
100
| | |
136
| | |
98
| | | | | | | | |
|
Basic net income per Class A share
| |
$
|
0.16
|
| |
$
|
0.41
|
| |
$
|
0.47
|
| |
$
|
0.80
| | | | | | | | |
| Diluted Net Income per Class A Share | | | | | | | | |
Net income attributable to PAGP
| |
$
|
24
| | |
$
|
42
| | |
$
|
65
| | |
$
|
78
|
Incremental net income attributable to PAGP resulting from assumed
exchange of AAP units and AAP Management Units
| |
-
|
| |
52
|
| |
-
|
| |
111
|
Net income attributable to PAGP including incremental net income
from assumed exchange of AAP units and AAP Management Units
| |
$
|
24
|
| |
$
|
94
|
| |
$
|
65
|
| |
$
|
189
| | | | | | | | |
|
Basic weighted average Class A shares outstanding
| |
153
| | |
100
| | |
136
| | |
98
|
Dilutive shares resulting from assumed exchange of AAP units and AAP
Management Units
| |
-
|
| |
134
|
| |
-
|
| |
147
|
Diluted weighted average Class A shares outstanding
| |
153
|
| |
234
|
| |
136
|
| |
245
| | | | | | | | |
|
Diluted net income per Class A share (2) | |
$
|
0.16
|
| |
$
|
0.40
|
| |
$
|
0.47
|
| |
$
|
0.77
|
| | |
(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 share and per-share amounts presented. | (2) | | For the three and six months ended June 30, 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/20170807005954/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
|
|
|
|
|