PAA NATURAL GAS STORAGE, L.P. 
By PAA Natural Gas Storage, L.P. (NYSE: PNG) reported third-quarter 2013 results as summarized below:
Summary Financial Information(1) | |||||||||||||||||||||||
| (in millions, except per unit data) | |||||||||||||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||||||||
| 2013 | 2012 | % Change | 2013 | 2012 | % Change | ||||||||||||||||||
| Net income | $ | 12.1 | $ | 17.9 | (32.2)% | $ | 46.7 | $ | 50.9 | (8.3)% | |||||||||||||
| Net income per diluted limited partner unit (2) | $ | 0.16 | $ | 0.24 | (33.3)% | $ | 0.62 | $ | 0.69 | (10.1)% | |||||||||||||
| EBITDA | $ | 24.5 | $ | 29.3 | (16.6)% | $ | 83.6 |
| $ | 84.1 | (0.6)% | ||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||||||||
| 2013 | 2012 | % Change | 2013 | 2012 | % Change | ||||||||||||||||||
| Adjusted net income | $ | 15.0 | $ | 18.3 | (17.8)% | $ | 52.6 | $ | 54.0 | (2.7)% | |||||||||||||
| Adjusted net income per diluted limited partner unit (2) | $ | 0.20 | $ | 0.25 | (20.0)% | $ | 0.70 | $ | 0.73 | (4.1)% | |||||||||||||
| Adjusted EBITDA | $ | 27.3 | $ | 29.7 | (8.0)% | $ | 89.5 | $ | 87.2 | 2.6 % | |||||||||||||
| Distribution declared for the period (2) | $ | 0.3575 | $ | 0.3575 | - | ||||||||||||||||||
| (1) The Partnership's reported results include the impact of items that affect comparability between reporting periods. The impact of these items is excluded from adjusted results. See the section of this release entitled "Non-GAAP Financial Measures, Segment Financial Measures and Selected Items Impacting Comparability" and the tables attached hereto for information regarding selected items that the Partnership believes impact comparability 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 GAAP measures. | |||||||||||||||||||||||
| (2) Series B subordinated units are not entitled to cash distributions unless and until they convert to Series A subordinated units or common units, which conversion is contingent on our meeting both certain distribution levels and certain in-service operational tests at our Pine Prairie facility. As a result, the Series B subordinated units are not included in the calculation of basic or diluted net income per unit amounts. | |||||||||||||||||||||||
The following table summarizes selected financial data for the third quarter and first nine months of 2013:
Summary of Selected Financial Data: | |||||||||||||||||
| (in thousands) | |||||||||||||||||
| Three Months Ended |
Nine Months Ended | |||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| Revenues | |||||||||||||||||
| Firm storage services | $ | 35,463 | $ | 36,364 | $ | 107,020 | $ | 105,646 | |||||||||
| Hub services and merchant storage (1) | 19,346 | 28,176 | 188,290 | 166,268 | |||||||||||||
| Other | 658 | 1,587 | 4,648 | 3,076 | |||||||||||||
| Total revenues | 55,467 | 66,127 | 299,958 | 274,990 | |||||||||||||
| Storage-related costs (2) | (22,675) | (29,184) | (189,984) | (167,549) | |||||||||||||
| Field operating costs | (3,372) | (2,974) | (10,625) | (9,030) | |||||||||||||
| General and administrative expenses | (4,959) | (4,641) | (15,713) | (14,304) | |||||||||||||
| Other income / (expense), net | (8) | (5) | (23) | 12 | |||||||||||||
| EBITDA | $ | 24,453 | $ | 29,323 | $ | 83,613 | $ | 84,119 | |||||||||
| Selected items impacting comparability | 2,893 | 388 | 5,872 | 3,076 | |||||||||||||
| Adjusted EBITDA | $ | 27,346 | $ | 29,711 | $ | 89,485 | $ | 87,195 | |||||||||
| (1) Includes revenues associated with sales of natural gas through commercial marketing activities. | |||||||||||||||||
| (2) Includes costs associated with sales of natural gas through commercial marketing activities. | |||||||||||||||||
Third-quarter 2013 adjusted EBITDA decreased 8.0% from comparable 2012 results. This decrease is primarily related to the timing of market opportunities in 2013 as compared to 2012. During 2013, market conditions facilitated the realization of merchant storage revenues to a greater extent during the first half of 2013, whereas during 2012 merchant storage revenues were realized more predominately during the latter half of the year.
The Partnership's common units and Series A subordinated units outstanding as of September 30, 2013 totaled 73.1 million. An additional 13.5 million Series B subordinated units (which are not currently entitled to receive distributions) are outstanding and do not convert to Series A subordinated units unless certain performance conditions are met.
As of September 30, 2013, the Partnership had total debt outstanding of approximately $550 million, long-term debt of approximately $503 million, and committed liquidity of approximately $198 million. $200 million of the Partnership's debt is owed to Plains All American Pipeline, L.P.
The Partnership will hold a joint conference call with Plains All American Pipeline, L.P. ("PAA") on November 5, 2013 (see details below).
Conference Call
The Partnership's joint conference call with PAA will be held at 11 a.m. EST on Tuesday, November 5, 2013. The following items will be addressed:
- The Partnership's third-quarter 2013 performance;
- Capitalization and liquidity; and
- Status of pending merger with PAA.
Conference Call Access Instructions
To access the Internet webcast of the conference call, please go to the Partnership's website at www.pnglp.com, select "Investor Relations," and then select "Conference Calls." Following the live webcast, the call will be archived for a period of sixty (60) days on the Partnership's website.
Alternatively, access to the live conference call is available by dialing toll free (877) 531-2988. International callers should dial (612) 332-0228. No password is required. The slide presentation accompanying the conference call will be available a few minutes prior to the call under the "Conference Call Summaries" portion of the "Conference Calls" tab of the "Investor Relations" section of the PNG website at www.pnglp.com.
Telephonic Replay Instructions
To listen to a telephonic replay of the conference call, please dial (800) 475-6701 or (320) 365-3844 for international callers and enter replay access code 303548. The replay will be available beginning Tuesday, November 5, 2013, at approximately 1:00 p.m. EST and will continue until 12:59 a.m. EST on December 6, 2013.
Non-GAAP Financial Measures, Segment Financial Measures and Selected Items Impacting Comparability
To supplement our financial information presented in accordance with GAAP, management uses adjusted EBITDA and distributable cash flow in its evaluation of past performance and prospects for the future. Management believes that the presentation of such additional financial measures provides useful information to investors regarding our financial condition and results of operations because these measures, when used in conjunction with related GAAP financial measures, (i) provide additional information about our core operations and ability to generate and distribute cash flow, (ii) provide investors with the financial analytical framework upon which management bases financial, operational, compensation and planning decisions and (iii) present measurements that investors, rating agencies and debt holders have indicated are useful in assessing us and our results of operations. Adjusted EBITDA and/or distributable cash flow may exclude, for example, the impact of unique and infrequent items, items outside of management's control and/or items that are not indicative of our core operating results and business outlook, which we define as "selected items impacting comparability." We consider an understanding of these selected items impacting comparability to be material to our evaluation of our operating results and prospects.
Although we present selected items that we consider 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, mechanical interruptions, acquisitions and numerous other factors. These types of variations are not fully identified and discussed 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.
Adjusted EBITDA and other non-GAAP financial measures are reconciled to net income, the most comparable GAAP measure, for the periods presented in the tables attached to this release, and should be viewed in addition to, and not in lieu of, our consolidated financial statements and notes thereto. In addition, the Partnership maintains on its website (www.pnglp.com) a reconciliation of adjusted EBITDA and certain commonly used non-GAAP financial information to the most comparable GAAP measures. To access the information, investors should click on the "Investor Relations" link on the Partnership's home page and then the "Non-GAAP Reconciliations" link on the Investor Relations page.
Forward Looking Statements
Except for the historical information contained herein, the matters discussed in this release are forward-looking statements that involve certain risks and uncertainties that could cause actual results to differ materially from results anticipated in the forward looking statements. These risks and uncertainties include, among other things, factors affecting demand for natural gas storage services and the rates we are able to charge for such services, including the balance between the supply of and demand for natural gas, the number of customers competing to acquire such services and the availability of alternatives to the services we offer; our ability to maintain or replace expiring storage contracts, or enter into new storage contracts, in either case at attractive rates and on otherwise favorable terms; a continuation of reduced volatility and/or lower spreads in natural gas markets for an extended period of time; factors affecting our ability to realize revenues from hub services and merchant storage transactions involving uncontracted or unutilized capacity at our facilities; operational, geologic or other factors that affect the timing or amount of crude oil and other liquid hydrocarbons that we are able to produce in conjunction with the operation of our Bluewater facility; the occurrence of a natural disaster, catastrophe, terrorist attack or other event, including attacks on our electronic and computer systems; market or other factors that affect the prices we are able to realize for crude oil and other liquid hydrocarbons produced in conjunction with the operation of our Bluewater facility; our ability to obtain and/or maintain all permits, approvals and authorizations that are necessary to conduct our business and execute our capital projects; the impact of operational, geologic and commercial factors that could result in an inability on our part to satisfy our contractual commitments and obligations, including the impact of equipment performance, cavern operating pressures and cavern temperature variances, salt creep and subsurface conditions or events; risks related to the ownership, development and operation of natural gas storage facilities, including the risk of explosions at our facilities; failure to implement or execute planned internal growth projects on a timely basis and within targeted cost projections; the effectiveness of our risk management activities; the effects of competition; interruptions in service and fluctuations in tariffs or volumes on third-party pipelines; general economic, market or business conditions and the amplification of other risks caused by volatile financial markets, capital constraints and pervasive liquidity concerns; the successful integration and future performance of acquired assets or businesses; 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 impact of current and future laws, rulings, governmental regulations, accounting standards and statements and related interpretations; shortages or cost increases of supplies, materials or labor; weather interference with business operations or project construction; our ability to receive open credit from our suppliers and trade counterparties; continued creditworthiness of, and performance by, our counterparties, including financial institutions and trading companies with which we do business; the availability of, and our ability to consummate, acquisition or combination opportunities; the operations or financial performance of assets or businesses that we acquire; environmental liabilities or events that are not covered by an indemnity, insurance or existing reserves; increased costs or unavailability of insurance; fluctuations in the debt and equity markets, including the price of our units at the time of vesting under our long-term incentive plan; and other factors and uncertainties inherent in the ownership, development and operation of natural gas storage facilities discussed in the Partnership's filings with the Securities and Exchange Commission.
PAA Natural Gas Storage, L.P. is a publicly traded master limited partnership engaged in the development, acquisition, operation and commercial management of natural gas storage facilities. The Partnership currently owns and operates three natural gas storage facilities located in Louisiana, Mississippi and Michigan. The Partnership's general partner, as well as the majority of the Partnership's limited partner interests, is owned by Plains All American Pipeline, L.P. PNG is headquartered in Houston, TX.
| PAA NATURAL GAS STORAGE, L.P. AND SUBSIDIARIES | |||||||||||||||||
| FINANCIAL SUMMARY (unaudited) | |||||||||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS | |||||||||||||||||
| (in thousands, except per unit data) | |||||||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| REVENUES (1) | $ | 55,467 | $ | 66,127 | $ | 299,958 | $ | 274,990 | |||||||||
| COSTS AND EXPENSES: | |||||||||||||||||
| Storage-related costs (2) | 22,675 | 29,184 | 189,984 | 167,549 | |||||||||||||
| Field operating costs | 3,372 | 2,974 | 10,625 | 9,030 | |||||||||||||
| General and administrative expenses | 4,959 | 4,641 | 15,713 | 14,304 | |||||||||||||
| Depreciation, depletion and amortization | 9,693 | 9,461 | 29,177 | 27,855 | |||||||||||||
| Total costs and expenses | 40,699 | 46,260 | 245,499 | 218,738 | |||||||||||||
| Operating income | 14,768 | 19,867 | 54,459 | 56,252 | |||||||||||||
| OTHER INCOME / (EXPENSE): | |||||||||||||||||
| Interest expense, net of capitalized interest | (2,624) | (1,973) | (7,752) | (5,350) | |||||||||||||
| Other income / (expense), net | (8) | (5) | (23) | 12 | |||||||||||||
| Net income | $ | 12,136 | $ | 17,889 | $ | 46,684 | $ | 50,914 | |||||||||
| CALCULATION OF LIMITED PARTNER NET INCOME: | |||||||||||||||||
| Net income | $ | 12,136 | $ | 17,889 | $ | 46,684 | $ | 50,914 | |||||||||
| General partner's incentive distribution | (228) | (222) | (682) | (666) | |||||||||||||
| General partner's 2% ownership interest | (238) | (353) | (920) | (1,005) | |||||||||||||
| Net income available to limited partners | 11,670 | 17,314 | 45,082 | 49,243 | |||||||||||||
| Undistributed earnings allocated and distributions to participating securities(3) | (149) | (83) | (464) | (248) | |||||||||||||
Net income available to limited partners in accordance with application of the two-class method for MLPs | $ | 11,521 | $ | 17,231 | $ | 44,618 | $ | 48,995 | |||||||||
| Basic weighted average number of limited partner units outstanding (4) | 73,086 | 71,136 | 72,223 | 71,131 | |||||||||||||
| Effect of dilutive securities: | |||||||||||||||||
| Weighted average LTIP units | 315 | 117 | 276 | 117 | |||||||||||||
| Weighted average number of diluted limited partner units outstanding (4) | 73,401 | 71,253 | 72,499 | 71,248 | |||||||||||||
| Net income per basic limited partner unit (4) | $ | 0.16 | $ | 0.24 | $ | 0.62 | $ | 0.69 | |||||||||
| Net income per diluted limited partner unit (4) | $ | 0.16 | $ | 0.24 | $ | 0.62 | $ | 0.69 | |||||||||
ADJUSTED RESULTS | |||||||||||||||||
| (In thousands, except per unit data) | |||||||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| Adjusted net income | $ | 15,029 | $ | 18,277 | $ | 52,556 | $ | 53,990 | |||||||||
| Adjusted net income per diluted limited partner unit (4) | $ | 0.20 | $ | 0.25 | $ | 0.70 | $ | 0.73 | |||||||||
| Adjusted EBITDA | $ | 27,346 | $ | 29,711 | $ | 89,485 | $ | 87,195 | |||||||||
| (1) Includes revenues associated with sales of natural gas through commercial marketing activities. | |||||||||||||||||
| (2) Includes costs associated with sales of natural gas through commercial marketing activities. | |||||||||||||||||
| (3) Participating securities consist of LTIP awards containing vested distribution equivalent rights which entitle the grantee to a cash payment equal to the cash distribution paid on our outstanding common units. | |||||||||||||||||
| (4) The calculation includes common units and Series A subordinated units. Series B subordinated units are not entitled to cash distributions unless and until they convert to Series A subordinated units or common units, which conversion is contingent on our meeting both certain distribution levels and certain in-service operational tests at our Pine Prairie facility. As a result, the Series B subordinated units are not included in the calculation of basic or diluted net income per unit amounts. | |||||||||||||||||
| PAA NATURAL GAS STORAGE, L.P. AND SUBSIDIARIES | |||||||||||||||||
| FINANCIAL SUMMARY (unaudited) | |||||||||||||||||
OPERATING DATA | |||||||||||||||||
| (in thousands, except capacity and operating metric data) | |||||||||||||||||
Three Months Ended |
| Nine Months Ended | |||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| Net revenue margin (1)(2) | $ | 34,582 | $ | 36,315 | $ | 111,955 | $ | 107,369 | |||||||||
| Field operating costs / G&A / Other | (7,236) | (6,604) | (22,470) | (20,174) | |||||||||||||
| Adjusted EBITDA | $ | 27,346 | $ | 29,711 | $ | 89,485 | $ | 87,195 | |||||||||
| Average working storage capacity (Bcf) | 97 | 89 | 96 | 82 | |||||||||||||
| Monthly Operating Metrics ($/Mcf): | |||||||||||||||||
| Net revenue margin (1)(2) | $ | 0.12 | $ | 0.14 | $ | 0.13 | $ | 0.15 | |||||||||
| Field operating costs / G&A / Other | (0.03) | (0.03) | (0.03) | (0.03) | |||||||||||||
| Adjusted EBITDA | $ | 0.09 | $ | 0.11 | $ | 0.10 | $ | 0.12 | |||||||||
| (1) Net revenue margin equals revenues minus storage-related costs. | |||||||||||||||||
| (2) Excludes the impact of mark-to-market of open derivative positions. | |||||||||||||||||
| PAA NATURAL GAS STORAGE, L.P. AND SUBSIDIARIES | |||||||||
| FINANCIAL SUMMARY (unaudited) | |||||||||
CONDENSED BALANCE SHEET DATA | |||||||||
| (in thousands) | |||||||||
| September 30, | December 31, | ||||||||
| 2013 | 2012 | ||||||||
| ASSETS | |||||||||
| Current assets | $ | 82,233 | $ | 94,393 | |||||
| Property and equipment, net | 1,327,241 | 1,313,918 | |||||||
| Base gas | 60,912 | 54,091 | |||||||
| Goodwill, intangibles and other assets, net | 393,162 | 406,667 | |||||||
| Total assets | $ | 1,863,548 | $ | 1,869,069 | |||||
| LIABILITIES AND PARTNERS' CAPITAL | |||||||||
| Current liabilities | $ | 77,939 | $ | 104,336 | |||||
| Note payable to PAA | 200,000 | 200,000 | |||||||
| Long-term debt under credit agreements | 303,263 | 305,385 | |||||||
| Other long-term liabilities | 9,351 | 8,406 | |||||||
| Total liabilities | 590,553 | 618,127 | |||||||
| Total partners' capital | 1,272,995 | 1,250,942 | |||||||
| Total liabilities and partners' capital | $ | 1,863,548 | $ | 1,869,069 | |||||
CREDIT RATIO | |||||||||
| Long-term debt / Total long-term book capitalization(1) | 28% | 29% | |||||||
| (1) Total long-term book capitalization is the sum of PNG's long-term debt and total partners' capital. | |||||||||
| PAA NATURAL GAS STORAGE, L.P. AND SUBSIDIARIES | |||||||||||||||||||||
| FINANCIAL SUMMARY (unaudited) | |||||||||||||||||||||
SELECTED ITEMS IMPACTING COMPARABILITY | |||||||||||||||||||||
| (in thousands, except per unit data) | |||||||||||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||||||
| Selected Items Impacting Comparability - Income / (Expense): | |||||||||||||||||||||
| Equity-indexed compensation expense | $ | (388 | ) | $ | (1,016 | ) | $ | (3,176 | ) | $ | (3,148 | ) | |||||||||
| Merger proposal evaluation costs (1) | (715 | ) | - | (715 | ) | - | |||||||||||||||
| Gains/(losses) from derivative activities (2) | (1,790 | ) | 628 | (1,981 | ) | 72 | |||||||||||||||
| Selected items impacting comparability | $ | (2,893 | ) | $ | (388 | ) | $ | (5,872 | ) | $ | (3,076 | ) | |||||||||
| Selected items impacting comparability | $ | (2,893 | ) | $ | (388 | ) | $ | (5,872 | ) | $ | (3,076 | ) | |||||||||
| Less: GP 2% share of selected items impacting comparability | 58 | 8 | 117 | 62 | |||||||||||||||||
| LP 98% share of selected items impacting comparability | $ | (2,835 | ) | $ | (380 | ) | $ | (5,755 | ) | $ | (3,014 | ) | |||||||||
| Impact to net income per basic limited partner unit (3) | $ | (0.04 | ) | $ | (0.01 | ) | $ | (0.08 | ) | $ | (0.04 | ) | |||||||||
| Impact to net income per diluted limited partner unit (3) | $ | (0.04 | ) | $ | (0.01 | ) | $ | (0.08 | ) | $ | (0.04 | ) | |||||||||
| (1) Costs associated with evaluating the now pending merger with a subsidiary of Plains All American Pipeline. | |||||||||||||||||||||
(2) Includes gains and losses resulting from certain derivative instruments that are related to underlying activities in future periods or the reversal of gains and losses adjusted for in prior periods to match underlying activities which occur in the current period. | |||||||||||||||||||||
| (3) The calculation includes common units and Series A subordinated units. Series B subordinated units are not entitled to cash distributions unless and until they convert to Series A subordinated units or common units, which conversion is contingent on our meeting both certain distribution levels and certain in-service operational tests at our Pine Prairie facility. As a result, the Series B subordinated units are not included in the calculation of basic or diluted net income per unit amounts. | |||||||||||||||||||||
| PAA NATURAL GAS STORAGE, L.P. AND SUBSIDIARIES | |||||||||||||||||
| FINANCIAL SUMMARY (unaudited) | |||||||||||||||||
FINANCIAL DATA RECONCILIATIONS | |||||||||||||||||
| (in thousands, except per unit data) | |||||||||||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| Distributable cash flow ("DCF") | |||||||||||||||||
| Net Income | $ | 12,136 | $ | 17,889 | $ | 46,684 | $ | 50,914 | |||||||||
| Depreciation, depletion and amortization | 9,693 | 9,461 | 29,177 | 27,855 | |||||||||||||
| Equity-indexed compensation expense, net of cash payments | 357 | 1,141 | 2,235 | 2,595 | |||||||||||||
| Maintenance capital expenditures | (122) | (84) | (339) | (457) | |||||||||||||
| Merger proposal evaluation costs (1) | 715 | - | 715 | - | |||||||||||||
| (Gains)/losses from derivative activities (2) | 1,790 | (628) | 1,981 | (72) | |||||||||||||
| DCF | $ | 24,569 | $ | 27,779 | $ | 80,453 | $ | 80,835 | |||||||||
Three Months Ended |
Nine Months Ended | ||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| Net income and earnings per limited partner unit excluding selected items impacting comparability: | |||||||||||||||||
| Net Income | $ | 12,136 | $ | 17,889 | $ | 46,684 | $ | 50,914 | |||||||||
| Selected items impacting comparability | 2,893 | 388 | 5,872 | 3,076 | |||||||||||||
| Adjusted Net Income | $ | 15,029 | $ | 18,277 | $ | 52,556 | $ | 53,990 | |||||||||
| Depreciation, depletion and amortization | $ | 9,693 | $ | 9,461 | $ | 29,177 | $ | 27,855 | |||||||||
| Interest expense, net of capitalized interest | 2,624 | 1,973 | 7,752 | 5,350 | |||||||||||||
| Adjusted EBITDA | $ | 27,346 | $ | 29,711 | $ | 89,485 | $ | 87,195 | |||||||||
| Selected items impacting comparability | (2,893) | (388) | (5,872) | (3,076) | |||||||||||||
| EBITDA | $ | 24,453 | $ | 29,323 | $ | 83,613 | $ | 84,119 | |||||||||
| Net income available to limited partners in accordance with application of the two-class method for MLPs | $ | 11,521 | $ | 17,231 | $ | 44,618 | $ | 48,995 | |||||||||
| Limited partners' 98% of selected items impacting comparability | 2,835 | 380 | 5,755 | 3,014 | |||||||||||||
| Adjusted limited partners' net income | $ | 14,356 | $ | 17,611 | $ | 50,373 | $ | 52,009 | |||||||||
| Adjusted net income per basic limited partner unit (3) | $ | 0.20 | $ | 0.25 | $ | 0.70 | $ | 0.73 | |||||||||
| Adjusted net income per diluted limited partner unit (3) | $ | 0.20 | $ | 0.25 | $ | 0.70 | $ | 0.73 | |||||||||
| Basic weighted average units outstanding (3) | 73,086 | 71,136 | 72,223 | 71,131 | |||||||||||||
| Diluted weighted average units outstanding (3) | 73,401 | 71,253 | 72,499 | 71,248 | |||||||||||||
| (1) Costs associated with evaluating the now pending merger with a subsidiary of Plains All American Pipeline. | |||||||||||||||||
(2) Includes gains and losses resulting from certain derivative instruments that are related to underlying activities in future periods or the reversal of gains and losses adjusted for in prior periods to match underlying activities which occur in the current period. | |||||||||||||||||
| (3) The calculation includes common units and Series A subordinated units. Series B subordinated units are not entitled to cash distributions unless and until they convert to Series A subordinated units or common units, which conversion is contingent on our meeting both certain distribution levels and certain in-service operational tests at our Pine Prairie facility. As a result, the Series B subordinated units are not included in the calculation of basic or diluted net income per unit amounts. | |||||||||||||||||
PAA Natural Gas Storage, L.P.
Roy I. Lamoreaux, 713-646-4222 or
800-564-3036
Director, Investor Relations
or
Al Swanson,
800-564-3036
Executive Vice President, CFO
