May 8, 2017   SOURCE: BusinessWire

Plains All American Pipeline, L.P. and Plains GP Holdings Report First-Quarter 2017 Results

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.