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Sunoco Logistics Partners LP 10-Q 2012 Table of Contents
UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
For the quarterly period ended March 31, 2012 OR
For the transition period from to Commission file number 1-31219
SUNOCO LOGISTICS PARTNERS L.P. (Exact name of registrant as specified in its charter)
Registrant’s telephone number, including area code: (866) 248-4344 Former name, former address and formal fiscal year, if changed since last report: Not Applicable
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨ Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No ¨ Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act.:
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x At March 31, 2012, the number of the registrant’s Common Units and Class A Units outstanding were 99,601,231 and 3,939,435, respectively.
Table of ContentsSUNOCO LOGISTICS PARTNERS L.P. INDEX
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Table of ContentsPART I FINANCIAL INFORMATION
SUNOCO LOGISTICS PARTNERS L.P. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (in millions, except per unit amounts)
(See Accompanying Notes)
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Table of ContentsSUNOCO LOGISTICS PARTNERS L.P. CONDENSED CONSOLIDATED BALANCE SHEETS (in millions)
(See Accompanying Notes)
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Table of ContentsSUNOCO LOGISTICS PARTNERS L.P. CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (in millions)
(See Accompanying Notes)
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Table of ContentsSUNOCO LOGISTICS PARTNERS L.P. CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) (in millions)
(See Accompanying Notes)
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Table of ContentsSUNOCO LOGISTICS PARTNERS L.P. NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 1. Basis of Presentation Sunoco Logistics Partners L.P. (“the Partnership”) is a publicly traded Delaware limited partnership that owns and operates a logistics business, consisting of refined products and crude oil pipelines, terminalling and storage assets, and refined products and crude oil acquisition and marketing assets. The Partnership is principally engaged in the transport, terminalling and storage of refined products and crude oil and the purchase and sale of crude oil, in 29 states located throughout the United States. Sunoco, Inc. and its wholly-owned subsidiaries including Sunoco, Inc. (R&M) are collectively referred to as “Sunoco.” Sunoco accounted for 3.7 percent of the Partnership’s total revenues for the three months ended March 31, 2012. The consolidated financial statements reflect the results of Sunoco Logistics Partners L.P. and its wholly-owned subsidiaries, including Sunoco Logistics Partners Operations L.P., and include the accounts of entities in which the Partnership has a controlling financial interest. A controlling financial interest is evidenced by either a voting interest greater than 50 percent or a risk and rewards model that identifies the Partnership or one of its subsidiaries as the primary beneficiary of a variable interest entity. The Partnership holds a controlling financial interest in Inland Corporation (“Inland”), Mid-Valley Pipeline Company (“Mid-Valley”) and West Texas Gulf Pipe Line Company (“West Texas Gulf”), and as such, these joint ventures are reflected as consolidated subsidiaries of the Partnership from the respective dates of acquisition. All significant intercompany accounts and transactions are eliminated in consolidation and noncontrolling interests in equity and net income are shown separately in the condensed consolidated balance sheets and statements of comprehensive income. Equity ownership interests in corporate joint ventures, in which the Partnership does not have a controlling financial interest, are accounted for under the equity method of accounting. In June 2011, the Financial Accounting Standards Board (“FASB”) codified guidance related to the presentation of comprehensive income. The guidance requires entities to present net income and other comprehensive income in a single continuous statement of comprehensive income or in two separate, but consecutive, statements. For the first quarter 2012, the Partnership presents the components of net income and total comprehensive income in its consolidated statements of comprehensive income. The new guidance does not change the components that are recognized in net income and the components that are recognized in other comprehensive income. The revised presentation has been retroactively applied to all periods presented. The accompanying condensed consolidated financial statements are presented in accordance with the requirements of Form 10-Q and accounting principles generally accepted in the United States for interim financial reporting. They do not include all disclosures normally made in financial statements contained in Form 10-K. In management’s opinion, all adjustments necessary for a fair presentation of the results of operations, financial position and cash flows for the periods shown have been made. All such adjustments are of a normal recurring nature. The Partnership expects the interim increase in quantities of crude oil inventory to decline by year end and therefore, has adjusted its interim LIFO calculation to produce a reasonable matching of the most recently incurred costs with current revenues. Results for the three months ended March 31, 2012 are not necessarily indicative of results for the full year 2012.
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Table of Contents2. Change in Business and Other Matters In February 2012, the Partnership sold its refined product terminal and pipeline assets in Big Sandy, Texas for $11 million. The buyer also assumed a $1 million environmental liability associated with the assets. The net book value of the assets sold and liability transferred approximated the sale price. In connection with the sale, the Partnership also agreed to cancel existing throughput and deficiency agreements in exchange for cash payments of $11 million. The Partnership recognized a total gain of $11 million, which primarily related to the contract settlement. The gain was recorded as $5 and $6 million within the Refined Products Pipelines and Terminal Facilities segments, respectively. 3. Related Party Transactions Advances to/from Affiliate The Partnership has a treasury services agreement with Sunoco pursuant to which it, among other things, participates in Sunoco’s centralized cash management program. Under this program, all of the Partnership’s cash receipts and cash disbursements are processed, together with those of Sunoco and its other subsidiaries, through Sunoco’s cash accounts with a corresponding credit or charge to an intercompany account. The intercompany balances are settled periodically, but no less frequently than monthly. Amounts due from Sunoco earn interest at a rate equal to the average rate of the Partnership’s third-party money market investments, while amounts due to Sunoco bear interest at a rate equal to the interest rate provided in the Operating Partnership’s $350 million Credit Facility (see Note 8). Administrative Services Under the Omnibus Agreement, the Partnership pays Sunoco or the general partner an annual administrative fee that includes expenses incurred by Sunoco and its affiliates to perform certain centralized corporate functions, such as legal, accounting, treasury, engineering, information technology, insurance, and other corporate services, including the administration of employee benefit plans. This fee was $13 million for the year ended December 31, 2011. The fee increased to $18 million for 2012 to cover additional consolidation of services provided by Sunoco that were previously provided by third parties and includes an allocation of management costs for the Chief Executive Officer through March 2012; Vice President, Chief Financial Officer; Vice President, Chief Human Resources Officer; and others from Sunoco that were previously included in the Partnership’s direct costs. This fee does not include the cost of shared insurance programs (which are allocated to the Partnership based upon its share of the cash premiums incurred), the salaries of pipeline and terminal personnel or other employees of the general partner or the cost of their employee benefits. The Partnership has no employees, and reimburses Sunoco and its affiliates for these costs and other direct expenses incurred on the Partnership’s behalf. These costs may be increased if the acquisition or construction of new assets or businesses requires an increase in the level of general and administrative services received by the Partnership. In addition to the fees for the centralized corporate functions, selling, general and administrative expenses in the consolidated statements of comprehensive income include the allocation of shared insurance costs. The Partnership’s share of allocated Sunoco employee benefit plan expenses, including noncontributory defined benefit retirement plans, defined contribution 401(k) plans, employee and retiree medical, dental and life insurance plans, incentive compensation plans and other such benefits are reflected in cost of products sold and operating expenses and selling, general and administrative expenses in the consolidated statements of comprehensive income. Affiliated Revenues and Accounts Receivable, Affiliated Companies The Partnership is party to various agreements with Sunoco to supply crude oil and refined products and to provide pipeline and terminalling services. Affiliated revenues in the consolidated statements of comprehensive income consist of sales of refined products and crude oil as well as the related provision, and services including pipeline transportation, terminalling, and storage and blending for Sunoco. Affiliated revenues include sales of crude oil to Sunoco which were priced using market-based rates and sales of refined products which are priced using market based rates under agreements that are negotiated annually. Service revenues are recognized based on published tariffs or negotiated rates. During 2011, Sunoco continued to execute its strategy to exit its refining operations which included selling its Toledo, Ohio refinery in March 2011 and initiating a process to sell its northeast refineries located in Philadelphia and Marcus Hook, Pennsylvania. In December 2011, the main processing units at the Marcus Hook refinery were idled indefinitely. Sunoco continues to pursue a sale of both the Philadelphia and Marcus Hook facilities, however Sunoco does not believe that the Marcus Hook facility will be sold and restarted as an operating refinery. In April 2012, Sunoco announced that it has entered into exclusive discussions with The Carlyle Group regarding a potential joint venture at its Philadelphia refinery. If a suitable transaction cannot be consummated, Sunoco also announced its intention to permanently idle the main processing units at the Philadelphia refinery no later than August 2012. Management assessed the impact that Sunoco’s decision to exit its refining business in the northeast will have on the Partnership’s assets that have historically served the refineries and determined that the Partnership’s refined products pipeline and
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Table of Contentsterminal assets continue to have expected future cash flows that support their carrying values. However, the Partnership recognized a $42 million charge in the fourth quarter 2011 for certain crude oil terminal assets which would be negatively impacted if the Philadelphia refinery is permanently idled. This included a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled. The Partnership continues to assess the impact that Sunoco’s exit from refining in the northeast will have on the Partnership’s operations. Capital Contributions In February 2012 and 2011, the Partnership issued 0.2 million limited partnership units to participants in the Sunoco Partners LLC Long-Term Incentive Plan (“LTIP”) upon completion of award vesting requirements. As a result of these issuances of limited partnership units, the general partner contributed less than $1 million during the first quarter 2012 and 2011 to maintain its 2 percent general partner interest. The Partnership recorded these amounts as capital contributions to Equity within its condensed consolidated balance sheets. Recent Developments In April 2012, Sunoco announced that it has entered into a definitive merger agreement to be acquired by Energy Transfer Partners, L.P (“ETP”). By acquiring Sunoco, ETP will also become the owner of the general partner and the incentive distribution rights, as well as Sunoco’s 32.4 percent interest in the Partnership’s limited partner units. The transaction is expected to close in the third or fourth quarter 2012, subject to approval of the Sunoco shareholders and customary regulatory approvals. In addition, under the merger agreement, Sunoco will continue its plans to exit its refining business, including the proposed joint venture with the Philadelphia refinery. The Partnership continues to assess the impact that the proposed acquisition will have on its operations. 4. Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit Data The general partner’s interest in net income attributable to Sunoco Logistics Partners L.P. (“net income attributable to the Partnership”) consists of its 2 percent general partner interest and “incentive distributions,” which are increasing percentages, up to 50 percent of quarterly distributions in excess of $0.1667 per common unit (see Note 11). The general partner was allocated net income attributable to the Partnership of $15 and $12 million (representing 16 and 25 percent respectively of total net income attributable to the Partnership) for the three months ended March 31, 2012 and 2011, respectively. Diluted net income attributable to the Partnership per common unit is calculated by dividing net income attributable to the Partnership by the sum of the weighted average number of common and Class A units outstanding and the dilutive effect of incentive unit awards (see Note 12). In July 2011, the Partnership issued 3.9 million Class A units to Sunoco in connection with the acquisition of the Eagle Point tank farm and related assets. These deferred distribution units represent a new class of units that will convert to common units, on a one-to-one basis, on the one-year anniversary of their issuance. The Class A units participate in the allocation of net income on a pro-rata basis with the common units. The following table sets forth the reconciliation of the weighted average number of common and Class A units used to compute basic net income attributable to the Partnership per common unit to those used to compute diluted net income attributable to the Partnership per common unit for the three months ended March 31, 2012 and 2011:
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Table of Contents5. Inventories The components of inventories are as follows:
6. Income Taxes The Partnership is not a taxable entity for U.S. federal income tax purposes, or for the majority of states that impose income taxes. Rather, income taxes are generally assessed at the partner level. There are some states in which the Partnership operates where it is subject to state and local income taxes. Substantially all of the income tax reflected in the Partnership’s consolidated financial statements is derived from the operations of Inland, Mid-Valley and West Texas Gulf, all of which are entities subject to income taxes for federal and state purposes at the corporate level. The effective tax rates for these entities approximate the federal statutory rate of 35 percent. In taxable jurisdictions, the Partnership records deferred income taxes on all significant temporary differences between the book basis and the tax basis of assets and liabilities. The net deferred tax liabilities reflected on the condensed consolidated balance sheets are derived principally from the difference in the book and tax bases of properties, plants and equipment associated with the Inland, Mid-Valley and West Texas Gulf acquisitions. 7. Investment in Affiliates The Partnership’s corporate joint ventures own refined products pipeline systems. The Partnership’s ownership percentages in corporate joint ventures as of March 31, 2012 and December 31, 2011 are as follows:
The following table provides summarized, unaudited income statement information on a 100 percent basis for the Partnership’s equity ownership interests for the three months ended March 31, 2012 and 2011:
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Table of ContentsThe following table provides summarized, unaudited balance sheet information on a 100 percent basis for the Partnership’s equity ownership interests as of March 31, 2012 and December 31, 2011:
8. Debt The components of the Partnership’s debt balances are as follows:
Credit Facilities The Partnership maintains two credit facilities totaling $550 million. The credit facilities consist of a five-year $350 million unsecured credit facility (the “$350 million Credit Facility”) and a $200 million 364-day unsecured credit facility (the “$200 million Credit Facility”). Outstanding borrowings under these credit facilities were $135 million at March 31, 2012. At December 31, 2011 there were no outstanding borrowings under these credit facilities. The credit facilities contain various covenants limiting the Partnership’s ability to incur indebtedness; grant certain liens; make certain loans, acquisitions and investments; make any material change to the nature of its business; or enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership’s subsidiaries. The credit facilities also limit the Partnership, on a rolling four-quarter basis, to a maximum total consolidated debt to consolidated EBITDA, as defined in the underlying credit agreements, ratio of 5.0 to 1, which can generally be increased to 5.5 to 1 during an acquisition period. The Partnership’s ratio of total debt to EBITDA was 2.5 to 1 at March 31, 2012, as calculated in accordance with the credit agreements. In April 2012, Sunoco announced that it has entered into a definitive merger agreement to be acquired by ETP. Successful completion of the acquisition would represent an event of default under the Partnership’s credit facilities as the general partner interests would no longer be owned by Sunoco. The Partnership continues to monitor the progress of the proposed transaction and, as necessary, will negotiate with the lending group for its credit facilities to amend the credit agreements. In May 2012, West Texas Gulf entered into a $35 million revolving credit facility (the “$35 million Credit Facility”), which matures in May 2015. The facility is available to fund the company’s general corporate purposes including working capital and capital expenditures. The facility may be repaid at any time and bears interest at LIBOR or the Base Rate (defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the prime rate or (c) LIBOR plus 1.0%), each plus an applicable margin. 9. Commitments and Contingent Liabilities The Partnership is subject to numerous federal, state and local laws which regulate the discharge of materials into the environment or that otherwise relate to the protection of the environment. These laws and regulations can result in liabilities and loss contingencies for remediation at the Partnership’s facilities and at third-party or formerly owned sites. At March 31, 2012 and December 31, 2011, there were accrued liabilities for environmental remediation in the condensed consolidated balance sheets of $5 and $4 million, respectively. The accrued liabilities for environmental remediation do not include any amounts attributable to unasserted
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Table of Contentsclaims, since no unasserted claims are probable of settlement or reasonably estimable, nor have any recoveries from insurance been assumed. Charges against income for environmental remediation totaled $4 and $2 million for the three months ended March 31, 2012 and 2011, respectively. The Partnership maintains insurance programs that cover certain of its existing or potential environmental liabilities. Claims for recovery of environmental liabilities that are probable of realization totaled $12 million at March 31, 2012 and are included in other assets in the condensed consolidated balance sheets. Total future costs for environmental remediation activities will depend upon, among other things, the identification of any additional sites, the determination of the extent of the contamination at each site, the timing and nature of required remedial actions, the technology available and needed to meet the various existing legal requirements, the nature and extent of future environmental laws, inflation rates and the determination of the Partnership’s liability at multi-party sites, if any, in light of uncertainties with respect to joint and several liability, and the number, participation levels and financial viability of other parties. Sunoco has indemnified the Partnership for 30 years from environmental and toxic tort liabilities related to the assets contributed to the Partnership that arose from the operation of such assets prior to the closing of the February 2002 initial public offering (“IPO”). Sunoco has indemnified the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the IPO. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent per year. For example, for a claim asserted during the twenty-third year after closing of the IPO, Sunoco would be required to indemnify the Partnership for 80 percent of its loss. There is no monetary cap on the amount of indemnity coverage provided by Sunoco. The Partnership has agreed to indemnify Sunoco for events and conditions associated with the operation of the Partnership’s assets that occur on or after the closing of the IPO and for environmental and toxic tort liabilities to the extent Sunoco is not required to indemnify the Partnership. Management of the Partnership does not believe that any liabilities which may arise from claims indemnified by Sunoco would be material in relation to the results of operations, financial position or cash flows of the Partnership at March 31, 2012. There are certain other pending legal proceedings related to matters arising after the IPO that are not indemnified by Sunoco. Management believes that any liabilities that may arise from these legal proceedings will not be material in relation to the Partnership’s results of operations, financial position or cash flows at March 31, 2012.
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Table of Contents10. Equity The changes in the number of common units outstanding from January 1, 2011 through March 31, 2012 are as follows:
11. Cash Distributions Within 45 days after the end of each quarter, the Partnership distributes all cash on hand at the end of the quarter, less reserves established by the general partner at its discretion. This is defined as “available cash” in the partnership agreement. The general partner has broad discretion to establish cash reserves that it determines are necessary or appropriate to properly conduct the Partnership’s business. The Partnership will make quarterly distributions to the extent there is sufficient cash from operations after the establishment of cash reserves and the payment of fees and expenses, including payments to the general partner. If cash distributions exceed $0.1667 per unit in a quarter, the general partner will receive increasing percentages, up to 50 percent, of the cash distributed in excess of that amount. These distributions are referred to as “incentive distributions.” The percentage interests for the unitholders and the general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The following table shows the target distribution levels and distribution “splits” between the general partner and the holders of the Partnership’s common units:
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Table of ContentsThe distributions paid by the Partnership for the period from January 1, 2011 through March 31, 2012 are summarized below.
On April 24, 2012, Sunoco Partners LLC, the general partner of Sunoco Logistics Partners L.P., declared a cash distribution of $0.4275 per common unit ($1.71 annualized), representing the distribution for the first quarter 2012. The $57 million distribution, including $14 million to the general partner, will be paid on May 15, 2012 to common unitholders of record on May 9, 2012. 12. Management Incentive Plan Sunoco Partners LLC, the general partner of the Partnership, has adopted the Sunoco Partners LLC LTIP for directors, officers and employees of the general partner who perform services for the Partnership. The LTIP is administered by the independent directors of the Compensation Committee of the general partner’s board of directors with respect to employee and officer awards, and by the non-independent members of the general partner’s board of directors with respect to awards granted to the independent members. The LTIP currently permits the grant of restricted units and unit options covering an additional 0.7 million common units. Restricted unit awards may also include tandem distribution equivalent rights (“DERs”) at the discretion of the Compensation Committee. During the three months ended March 31, 2012 and 2011, the Partnership issued 215 and 189 thousand common units, respectively, under the LTIP. The Partnership recognized share-based compensation expense of $3 million for both three-month periods ended March 31, 2012 and 2011. Each of the restricted unit grants also have tandem DERs which are recognized as a reduction of equity when earned. 13. Derivatives and Risk Management The Partnership is exposed to various market risks, including volatility in crude oil and refined product prices, counterparty credit risk and interest rate risk. In order to manage such exposure, the Partnership’s policy is to (i) only purchase crude oil and refined products for which sales contracts have been executed or for which ready markets exist, (ii) structure sales contracts so that price fluctuations do not materially impact the margins earned, and (iii) not acquire and hold physical inventory, futures contracts or other derivative instruments for the purpose of speculating on commodity price changes. Although the Partnership seeks to maintain a balanced inventory position within its commodity inventories, net unbalances may occur for short periods of time due to production, transportation and delivery variances. When temporary physical inventory builds or draws do occur, the Partnership continuously manages the variances to a balanced position over a period of time. Pursuant to the Partnership’s approved risk management policy, derivative contracts may be used to hedge or reduce exposure to price risk associated with acquired inventory or forecasted physical transactions. Price Risk Management The Partnership is exposed to risks associated with changes in the market price of crude oil and refined products as a result of the forecasted purchase or sale of these products. These risks are primarily associated with price volatility related to pre-existing or anticipated purchases, sales and storage. Price changes are often caused by shifts in the supply and demand for these commodities, as well as their locations. The physical contracts related to the Partnership’s crude oil and refined products businesses that qualify as derivates have been designated as normal purchases and sales and are accounted for using traditional accrual accounting. The Partnership accounts for derivatives that do not qualify as normal purchases and sales at fair value. The Partnership does utilize derivatives such as swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products. These derivative contracts act as a hedging mechanism against the volatility of prices by allowing the Partnership to transfer this price risk to counterparties who are able and willing to bear it.
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Table of ContentsWhile all derivative instruments utilized by the Partnership represent economic hedges, certain of these derivatives are not designated as hedges for accounting purposes. Such derivatives include certain contracts that were entered into and closed during the same accounting period and a limited number of contracts for which there is not sufficient correlation to the related items being economically hedged. For refined product derivative contracts that are not designated as hedges for accounting purposes, all realized and unrealized gains and losses are recognized in the statement of comprehensive income during the current period. For refined product derivative contracts that are designated and qualify as cash flow hedges, the portion of the gain or loss on the derivative contract that is effective in offsetting the variable cash flows associated with the hedged forecasted transaction is reported as a component of other comprehensive income and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. The remaining gain or loss on the derivative contract in excess of the cumulative change in the present value of future cash flows of the hedged item, if any (i.e., the ineffective portion), is recognized in earnings during the current period. All realized gains and losses associated with refined product derivative contracts are recorded in earnings in the same line item as the forecasted transaction being hedged, either sales and other operating revenue or cost of products sold and operating expenses. The Partnership had open derivative positions of approximately 0.4 and 1.5 million barrels of refined products at March 31, 2012 and December 31, 2011, respectively. The derivatives outstanding as of March 31, 2012 vary in duration but do not extend beyond one year. The Partnership records its derivatives at fair value based on observable market prices (levels 1 and 2). The fair values of the Partnership’s derivative assets were less than $1 million and $6 million as of March 31, 2012 and December 31, 2011, respectively. The fair values of the Partnership’s derivative liabilities were less than $1 million and $2 million as of March 31, 2012 and December 31, 2011, respectively. Derivative asset and liability balances are recorded in accounts receivable and accrued liabilities, respectively, in the accompanying condensed consolidated balance sheets. The Partnership’s derivative positions are comprised primarily of commodity contracts. The following tables set forth the impact of derivatives on the Partnership’s financial performance for the three months ended March 31, 2012 and 2011:
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Table of ContentsCredit Risk Management The Partnership faces counterparty credit risk as a result of our use of financial derivative contracts. The Partnership’s counterparties consist primarily of financial institutions and major integrated oil companies. This concentration of counterparties may impact the Partnership’s overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions. The Partnership maintains credit policies with regard to its counterparties that management believes minimize the overall credit risk. The credit positions of the Partnership’s customers’ are analyzed prior to the extension of credit and periodically after credit has been extended. The Partnership manages its exposure to derivative counterparty credit risk through credit analysis, credit approvals, credit limits, and monitoring procedures. The Partnership’s over-the-counter derivatives are entered into with counterparties outside of organized exchanges. While management actively monitors the risk associated with entering into such transactions, it is possible that losses can result from counterparty credit risk in the future. At March 31, 2012 and December 31, 2011, the Partnership did not hold any over-the-counter derivatives. Interest Rate Risk Management The Partnership has interest rate risk exposure for changes in interest rates related to its outstanding borrowings. The Partnership manages its exposure to changes in interest rates through the use of a combination of fixed- rate and variable-rate debt. At March 31, 2012, the Partnership had $135 million of variable-rate borrowings under its revolving credit facilities. 14. Fair Value Measurements The Partnership applies fair value accounting for all financial assets and liabilities that are required to be measured at fair value under current accounting rules, primarily derivatives. The assets and liabilities that are measured at fair value on a recurring basis are not material to the Partnership’s condensed consolidated balance sheets. The Partnership determines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Partnership utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy established by the FASB. The Partnership generally applies a “market approach” to determine fair value. This method uses pricing and other information generated by market transactions for identical or comparable assets and liabilities. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety. The estimated fair value of financial instruments has been determined based on the Partnership’s assessment of available market information and appropriate valuation methodologies. The Partnership’s current assets (other than derivatives and inventories) and current liabilities are financial instruments and most of these items are recorded at cost in the condensed consolidated balance sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. The Partnership’s derivatives are measured and recorded at fair value based on observable market prices (Note 13). The estimated fair values of the Senior Notes are determined using observable market prices, as these notes are actively traded. The estimated aggregate fair value of the Senior Notes at March 31, 2012 is $1.60 billion, compared to the carrying amount of $1.45 billion. The estimated aggregate fair value of the Senior Notes at December 31, 2011 was $1.91 billion, compared to the carrying amount of $1.70 billion. In May 2011, the FASB issued a new accounting standard update, which amended the fair value measurement guidance and includes some enhanced disclosure requirements. The most significant change in disclosures is an expansion of the information required for level 3 measurements based on unobservable inputs. The Partnership adopted the amended guidance on January 1, 2012. The adoption of the amended guidance did not have a material impact on the Partnership’s consolidated financial statements and disclosures. 15. Business Segment Information The following tables summarize condensed statement of income information concerning the Partnership’s business segments and reconcile total segment operating income to net income attributable to Sunoco Logistics Partners L.P. for the three months ended March 31, 2012 and 2011, respectively.
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Table of ContentsThe following table provides the identifiable assets for each segment as of March 31, 2012 and December 31, 2011:
16. Supplemental Condensed Consolidating Financial Information The Partnership serves as guarantor of the Senior Notes. These guarantees are full and unconditional. For purposes of the following footnote, Sunoco Logistics Partners L.P. is referred to as “Parent Guarantor” and Sunoco Logistics Partners Operations L.P. is referred to as “Subsidiary Issuer.” All other consolidated subsidiaries of the Partnership are collectively referred to as “Non-Guarantor Subsidiaries.” The following supplemental condensed consolidating financial information reflects the Parent Guarantor’s separate accounts, the Subsidiary Issuer’s separate accounts, the combined accounts of the Non-Guarantor Subsidiaries, the combined consolidating adjustments and eliminations and the Parent Guarantor’s consolidated accounts for the dates and periods indicated. For purposes of the following condensed consolidating information, the Parent Guarantor’s investments in its subsidiaries and the Subsidiary Issuer’s investments in its subsidiaries are accounted for under the equity method of accounting.
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Table of ContentsConsolidating Statement of Comprehensive Income Three Months Ended March 31, 2012 (in millions, unaudited)
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Table of ContentsConsolidating Statement of Comprehensive Income Three Months Ended March 31, 2011 (in millions, unaudited)
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Table of ContentsCondensed Consolidating Balance Sheet March 31, 2012 (in millions, unaudited)
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Table of ContentsCondensed Consolidating Balance Sheet December 31, 2011 (in millions)
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Table of ContentsConsolidating Statement of Cash Flows Three Months Ended March 31, 2012 (in millions, unaudited)
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Table of ContentsConsolidating Statement of Cash Flows Three Months Ended March 31, 2011 (in millions, unaudited)
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Results of Operations The following table presents our consolidated operating results for the three months ended March 31, 2012 and 2011:
Non-GAAP Financial Measures To supplement our financial information presented in accordance with United States generally accepted accounting principles (“GAAP”), management uses additional measures that are known as “non-GAAP financial measures” in its evaluation of past performance and prospects for the future. The primary measures used by management are earnings before interest, taxes, depreciation and amortization expenses and other non-cash items (“Adjusted EBITDA”) and distributable cash flow (“DCF”). Our management believes Adjusted EBITDA and distributable cash flow information enhances an investor’s understanding of a business’s ability to generate cash for payment of distributions and other purposes. In addition, EBITDA calculations are also defined and used as a measure in determining our compliance with certain revolving credit facility covenants. However, there may be contractual, legal, economic or other reasons which may prevent us from satisfying principal and interest obligations with respect to indebtedness and may require us to allocate funds for other purposes. Adjusted EBITDA and distributable cash flow do not represent and should not be considered alternatives to net income or cash flows from operating activities as determined under GAAP and may not be comparable to other similarly titled measures of other businesses.
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Table of ContentsThe following table reconciles the difference between net income, as determined under GAAP, and Adjusted EBITDA and distributable cash flows:
The following table reconciles the difference between net cash provided by operating activities and Adjusted EBITDA:
Analysis of Consolidated Operating Results Net income attributable to the partnership interests was $95 and $48 million for the three months ended March 31, 2012 and 2011, respectively. Net income attributable to partnership interests for the first three months of 2012 increased $47 million compared to the prior year period due primarily to improved operating performance which benefited from strong demand for crude oil transportation services and contributions from our 2011 acquisitions and organic projects. Higher income from our operations was partially offset by higher interest expense related to debt offerings in 2011 which were used to fund various growth initiatives. Analysis of Segment Operating Income We manage our operations through four operating segments: Refined Products Pipelines, Terminal Facilities, Crude Oil Pipelines and Crude Oil Acquisition and Marketing. Refined Products Pipelines Our Refined Products Pipelines segment consists of refined products pipelines, including a two-thirds undivided interest in the Harbor pipeline and joint venture interests in four refined products pipelines in selected areas of the United States. The Refined Products Pipelines earn revenues by transporting refined products from refineries in the northeast, midwest and southwest United States to markets in 6 states and Canada. Rates for shipments on these pipelines are regulated by the Federal Energy Commission (“FERC”) and the Pennsylvania Public Utility Commission (“PA PUC”).
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Table of ContentsThe following table presents the operating results and key operating measures for our Refined Products Pipelines for the three months ended March 31, 2012 and 2011:
Operating income for the Refined Products Pipelines increased $1 million to $6 million for the three months ended March 31, 2012 as compared to $5 million for the three months ended March 31, 2011. The increase was due primarily to contributions from the second quarter 2011 acquisition of a controlling financial interest in the Inland pipeline ($3 million) and a gain recognized on a contract settlement associated with the sale of our Big Sandy refined products terminal and pipeline assets in Texas ($5 million). Partially offsetting these amounts were lower pipeline volumes in our refined products pipelines due to the idling of Sunoco’s Marcus Hook refinery in the fourth quarter 2011 ($3 million), higher environmental remediation expenses ($3 million) and a non-cash impairment charge related to the cancellation of a refined products pipeline project in Texas ($1 million). Terminal Facilities Our Terminal Facilities segment consists primarily of crude oil and refined product terminals and a refined product acquisition and marketing business. The Terminal Facilities earn revenue by providing storage, terminalling, blending and other ancillary services to our customers, as well as through the sale of refined products.
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Table of ContentsThe following table presents the operating results and key operating measures for our Terminal Facilities for the three months ended March 31, 2012 and 2011:
Operating income for the Terminal Facilities increased $8 million to $37 million for the three months ended March 31, 2012 as compared to $29 million for the three months ended March 31, 2011. The increase in operating income is due primarily to a gain recognized on a contract settlement associated with the Partnership’s sale of the Big Sandy terminal and pipeline assets ($6 million). Also contributing to the increase were contributions from the 2011 acquisitions of the Eagle Point tank farm and a refined products terminal in Boston, Massachusetts ($5 million). Partially offsetting these increases were reduced volumes at the Partnership’s refinery terminals related to the idling of Sunoco’s Marcus Hook refinery in the fourth quarter 2011 ($2 million). Crude Oil Pipelines Our Crude Oil Pipelines consists of crude oil trunk and gathering pipelines in the southwest and midwest United States. Revenues are generated from tariffs and the associated fees paid by shippers utilizing our transportation services to deliver crude oil and other feedstocks to refineries within those regions. Rates for shipments on these pipelines are regulated by the FERC, Oklahoma Corporation Commission (“OCC”) and the Railroad Commission of Texas (“Texas R.R.C.”).
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Table of ContentsThe following table presents the operating results and key operating measures for our Crude Oil Pipelines for the three months ended March 31, 2012 and 2011:
Operating income for the Crude Oil Pipelines increased $13 million to $52 million for the three months ended March 31, 2012 as compared to $39 million for the three months ended March 31, 2011. The increase in operating income was driven primarily by higher pipeline fees which benefited from tariff increases relative to the prior year period and increased demand for West Texas crude oil ($9 million). Operating results were further improved by reduced operating expenses related primarily to increased pipeline operating gains ($5 million) and lower environmental remediation expenses ($2 million). Partially offsetting these improvements were higher costs associated with operating supplies ($1 million). Crude Oil Acquisition and Marketing Our Crude Oil Acquisition and Marketing segment reflects the sale of gathered and bulk purchased crude oil. The crude oil acquisition and marketing operations generate substantial revenue and cost of products sold as a result of the significant volume of crude oil bought and sold. However, the absolute price levels of crude oil normally do not bear a relationship to gross margin, although the price levels significantly impact revenue and costs of products sold. As a result, period-to-period variations in revenue and cost of products sold are not generally meaningful in analyzing the variation in gross margin for the Crude Oil Acquisition and Marketing segment. The operating results of the Crude Oil Acquisition and Marketing segment are affected by overall levels of supply and demand for crude oil and relative fluctuations in market related indices. Generally, we expect a base level of earnings from our Crude Oil Acquisition and Marketing segment that may be optimized and enhanced when there is a high level of market volatility, favorable basis differentials and/or a steep contango or backwardated structure. Our management believes gross margin, which is equal to sales and other operating revenue less cost of products sold, operating expenses and depreciation and amortization, is a key measure of financial performance for the Crude Oil Acquisition and Marketing segment. Although we employ risk management activities, these margins are not fixed and will vary from period to period.
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Table of ContentsThe following table presents the operating results and key operating measures for our Crude Oil Acquisition and Marketing for the three months ended March 31, 2012 and 2011:
Operating income for the Crude Oil Acquisition and Marketing segment increased $32 million to $34 million for the three months ended March 31, 2012 as compared to $2 million for the three months ended March 31, 2011. The increase in operating income was driven primarily by expanded crude oil volumes and margins which were the result of expansion in our crude oil trucking fleet and market related opportunities in West Texas. Operating results were further improved by increased volumes from the crude oil acquisition and marketing assets acquired from Texon L.P. in the third quarter of 2011. Partially offsetting these improvements was an $8 million non-cash impairment charge related to a cancelled software project. Related Party Transactions In April 2012, Sunoco announced that it has entered into a definitive merger agreement to be acquired by Energy Transfer Partners, L.P (“ETP”). By acquiring Sunoco, ETP will also become the owner of the general partner and the incentive distribution rights, as well as Sunoco’s 32.4 percent interest in the Partnership’s limited partner units. The transaction is expected to close in the third or fourth quarter 2012, subject to approval of the Sunoco shareholders and customary regulatory approvals. In addition, under the merger agreement, Sunoco will continue its plans to exit its refining business, including the proposed joint venture with the Philadelphia refinery. The Partnership continues to assess the impact that the proposed acquisition will have on its operations. Liquidity and Capital Resources Liquidity Cash generated from operations and borrowings under our $550 million of credit facilities are our primary sources of liquidity. At March 31, 2012, we had net working capital of $122 million and available borrowing capacity under credit facilities of $415 million. Our working capital position reflects crude oil and refined products inventories based on historical costs under the last-in, first-out (“LIFO”) method of accounting. If the inventories had been valued at their current replacement cost, we would have had working capital of $337 million at March 31, 2012. We periodically supplement our cash flows from operations with proceeds from debt and equity financing activities. Credit Facilities The Partnership maintains two credit facilities with total borrowing capacity of $550 million. The credit facilities consist of a five-year $350 million unsecured credit facility (the “$350 million Credit Facility”) and a $200 million 364 day unsecured credit facility (the “$200 million Credit Facility”). Outstanding borrowings under these credit facilities were $135 million at March 31, 2012. There were no borrowings outstanding at December 31, 2011. The credit facilities contains various covenants limiting the Partnership’s ability to incur indebtedness; grant certain liens; make certain loans, acquisitions and investments; make any material change to the nature of its business; or enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership’s subsidiaries. The credit facilities also limit the Partnership, on a rolling four-quarter basis, to a maximum total consolidated debt to consolidated EBITDA, as defined in the underlying credit agreement, ratio of 5.0 to 1, which can generally be increased to 5.5 to 1 during an acquisition period. The Partnership’s ratio of total debt to EBITDA was 2.5 to 1 at March 31, 2012, as calculated in accordance with the bank covenants. In April 2012, Sunoco announced that it has entered into a definitive merger agreement to be acquired by ETP. Successful completion of the acquisition would represent an event of default under the Partnership’s credit facilities as the general partner interests would no longer be owned by Sunoco. The Partnership continues to monitor the progress of the proposed transaction and, as necessary, will negotiate with the lending group for its credit facilities to amend the credit agreements. In May 2012, West Texas Gulf Pipe Line Company, one of the Partnership’s consolidated joint ventures, entered into a $35 million revolving credit facility (the “$35 million Credit Facility”), which matures in May 2015. The facility is available to fund the company’s general corporate purposes including working capital and capital expenditures. The facility may be repaid at any time and bears interest at LIBOR or the Base Rate (defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the prime rate or (c) LIBOR plus 1.0%), each plus an applicable margin.
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Table of ContentsCash Flows and Capital Expenditures Net cash provided by operating activities for the three months ended March 31, 2012 was $139 million compared with net cash provided by operating activities of $6 million for the first three months of 2011. Net cash provided by operating activities in 2012 related primarily to net income of $97 million, non-cash charges for depreciation and amortization of $25 million and a $21 million decrease in working capital which was the primarily the result of a reduction in account receivables from contango inventory sales at year end 2011. The net cash provided by operating activities in 2011 related to net income of $50 million and non-cash charges of depreciation and amortization of $18 million, offset by a $67 million increase in working capital. The 2011 increase in working capital was primarily the result of the Partnership’s contango inventory positions. Net cash used in investing activities for the first three months of 2012 was $39 million compared with $28 million for the first three months of 2011. Net cash used in investing activities in 2012 consisted primarily of maintenance capital and projects to expand upon the Partnership’s butane blending services, upgrade the service capacity at the Eagle Point terminal and investment in the Partnership’s crude oil infrastructure by increasing its pipeline capabilities in West Texas and expanding the trucking fleet. These uses were partially offset by $11 million of proceeds received for the sale of the Big Sandy terminal and pipeline assets and the settlement of related throughput and deficiency contracts. Net cash used in investing activities in 2011 consisted of capital expenditures to maintain the Partnership’s existing assets and expand upon the Partnership’s existing butane blending business and increase tankage at the Nederland facility. Net cash used in financing activities for the first three months of 2012 was $103 million compared with $22 million provided by financing activities for the first three months of 2011. Net cash used in financing activities for the first three months of 2012 resulted from the $250 million repayment of 7.25% senior notes in February 2012 and $55 million in distributions paid to limited partners and the general partner. The 2012 cash used in financing was offset by $135 million of net credit facility borrowings and $72 million decrease in advances to affiliates. Net cash provided by financing activities for the first three months of 2011 resulted from $51 million in net borrowings under the Partnership’s revolving credit facility and a $27 million decrease in advances to affiliates. The 2011 sources of cash were partially offset by $51 million in distributions paid to limited and general partners. Capital Requirements Our operations are capital intensive, requiring significant investment to maintain, upgrade and enhance existing assets and to meet environmental and operational regulations. The capital requirements have consisted, and are expected to continue to consist, primarily of:
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Table of ContentsThe following table summarizes maintenance and expansion capital expenditures, including amounts paid for acquisitions, for the periods presented:
Maintenance capital expenditures for both periods presented include recurring expenditures such as pipeline integrity costs, pipeline relocations, repair and upgrade of field instrumentation, including measurement devices, repair and replacement of tank floors and roofs, upgrades of cathodic protection systems, crude trucks and related equipment, and the upgrade of pump stations. The Partnership expects its maintenance capital spending to be approximately $50 million in 2012. Expansion capital expenditures for the three months ended March 31, 2012 were $43 million compared to $25 million for the first three months of 2011. Expansion capital for the three months ended March 31, 2012 includes projects to expand upon the Partnership’s butane blending services, upgrade the service capacity at the Eagle Point terminal, invest in the Partnership’s crude oil infrastructure by increasing its pipeline capabilities in West Texas and expanding the trucking fleet, and convert certain refined products pipelines as part of the Mariner West project. Expansion capital for the first three months of 2011 included projects to expand upon the Partnership’s butane blending business, increase tankage at the Nederland facility. The Partnership expects total expansion capital of approximately $300 million for 2012, excluding major acquisitions. There were no major acquisitions during the three months ended March 31, 2012 or 2011. We expect to fund capital expenditures, including any additional acquisitions, from cash provided by operations and, to the extent necessary, from the proceeds of borrowings under our credit facilities, other borrowings and the issuance of additional common units.
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We are exposed to various market risks, including changing interest rates and volatility in crude oil and refined products commodity prices. To manage such exposure, interest rates, inventory levels and expectations of future commodity prices are monitored when making decisions with respect to risk management. Interest Rate Risk We have interest-rate risk exposure for changes in interest rates relating to our outstanding borrowings. We manage our exposure to changing interest rates through the use of a combination of fixed- rate and variable-rate debt. At March 31, 2012, we had $135 million of variable rate borrowings under our revolving credit facilities. Outstanding borrowings bear interest cost of LIBOR plus an applicable margin. Our weighted average interest rate on our variable-rate borrowings was approximately 2 percent at March 31, 2012. A one percent change in the weighted average rate would have impacted annual interest expense by approximately $1 million. At March 31, 2012, we had $1.45 billion of fixed-rate borrowings, which had a fair value of $1.60 billion at March 31, 2012. A hypothetical one-percent decrease in interest rates would increase the fair value of our fixed-rate borrowings at March 31, 2012 by approximately $151 million. Commodity Market Risk We are exposed to volatility in crude oil and refined products commodity prices. To manage such exposures, inventory levels and expectations of future commodity prices are monitored when making decisions with respect to risk management and inventory carried. Our policy is to purchase only commodity products for which we have a market and to structure our sales contracts so that price fluctuations for those products do not materially affect the margin we receive. We also seek to maintain a position that is substantially balanced within our various commodity purchase and sales activities. We may experience net unbalanced positions for short periods of time as a result of production, transportation and delivery variances, as well as logistical issues associated with inclement weather conditions. When unscheduled physical inventory builds or draws do occur, they are monitored and managed to a balanced position over a reasonable period of time. We do not use futures or other derivative instruments to speculate on crude oil or refined products prices, as these activities could expose us to significant losses. We do use derivative contracts as economic hedges against price changes related to our forecasted refined products purchase and sale activities. These derivatives are intended to have equal and opposite effects of the purchase and sale activities. At March 31, 2012, the fair market value of our open derivative positions was less than $1 million on 0.4 million barrels of refined products. These derivative positions vary in length but do not extend beyond one year. For additional information concerning our commodity market risk activities, see Note 13 to the Consolidated Financial Statements. Forward-Looking Statements Some of the information included in this quarterly report on Form 10-Q contains “forward-looking” statements and information relating to Sunoco Logistics Partners L.P. that is based on the current beliefs of our management as well as assumptions made by, and information currently available to, our management. Forward-looking statements discuss expected future results based on current and pending business operations, and may be identified by words such as “may,” “anticipates,” “believes,” “expects,” “estimates,” “planned,” “scheduled” or similar phrases or expressions. Although we believe these forward-looking statements are reasonable, they are based upon a number of assumptions, any or all of which may ultimately prove to be inaccurate. These statements are subject to numerous assumptions, uncertainties and risks that may cause future results to be materially different from the results projected, forecasted, estimated or budgeted, including, but not limited to the following:
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These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. We undertake no obligation to update publicly any forward-looking statement whether as a result of new information or future events.
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Disclosure controls and procedures are designed to ensure that information required to be disclosed in the Partnership reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified by the rules and forms of the Securities and Exchange Commission. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in the Partnership reports under the Exchange Act is accumulated and communicated to management, including the President and Chief Executive Officer and Interim Chief Financial Officer of Sunoco Partners LLC (the Partnership’s general partner), as appropriate, to allow timely decisions regarding required disclosure. As of March 31, 2012, the Partnership carried out an evaluation, under the supervision and with the participation of the management of the general partner (including the President and Chief Executive Officer and the Interim Chief Financial Officer), of the effectiveness of the design and operation of the Partnership’s disclosure controls and procedures pursuant to Exchange Act Rule 13a-15. Based upon that evaluation, the general partner’s President and Chief Executive Officer, and its Interim Chief Financial Officer, concluded that the Partnership’s disclosure controls and procedures are effective. No change in the Partnership’s internal control over financial reporting has occurred during the fiscal quarter ended March 31, 2012 that has materially affected, or that is reasonably likely to materially affect, the Partnership’s internal control over financial reporting.
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Table of ContentsPART II OTHER INFORMATION
There are certain legal and administrative proceedings arising prior to the February 2002 initial public offering (“IPO”) pending against our Sunoco-affiliated predecessors and us (as successor to certain liabilities of those predecessors). Although the ultimate outcome of these proceedings cannot be ascertained at this time, it is reasonably possible that some of them may be resolved unfavorably. Sunoco has agreed to indemnify the Partnership for 100 percent of all losses from environmental liabilities related to the transferred assets arising prior to, and asserted within 21 years of February 8, 2002. There is no monetary cap on this indemnification from Sunoco. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent each year through the thirtieth year following the February 8, 2002 date. Any remediation liabilities not covered by this indemnity will be our responsibility. In addition, Sunoco is obligated to indemnify us under certain other agreements executed after the IPO. In 2009, the Environmental Protection Agency (“EPA”) proposed penalties based on alleged violations of the Clean Water Act associated with an October 2008 release from the Mid-Valley Pipeline. The EPA and the Partnership have agreed upon a settlement of $0.3 million, which the Partnership paid in the first quarter 2012. There are certain other pending legal proceedings related to matters arising after the IPO that are not indemnified by Sunoco. Our management believes that any liabilities that may arise from these legal proceedings will not be material to our results of operations, cash flows or financial position at March 31, 2012.
There have been no material changes from the risk factors described previously in Part I, Item IA of the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2011, filed on February 23, 2012.
None.
None.
None.
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We are pleased to furnish this Form 10-Q to unitholders who request it by writing to: Sunoco Logistics Partners L.P. Investor Relations 1818 Market Street Suite 1500 Philadelphia, PA 19103 or through our website at www.sunocologistics.com.
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Table of ContentsSIGNATURE Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
Date: May 3, 2012
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