Filed Pursuant to Rule 424(B)(3)
Registration File Number: 333-146586
PROSPECTUS
27,269,201 Common Units
ATLAS PIPELINE PARTNERS, L.P.
This prospectus relates to the sale of up to 27,269,201 common units representing limited partner interests for the account of the selling unitholders named in this prospectus. The common units may be sold in the open market, on the New York Stock Exchange, in privately negotiated transactions or a combination of these methods. We will not receive any of the proceeds from the sale of the common units covered by this prospectus.
Our common units are quoted on the New York Stock Exchange under the symbol “APL.” The last reported sales price of our common units was $45.81 per unit on November 28, 2007.
Investing in our common units involves risks. You should carefully consider the risks described under “ Risk Factors” beginning on page 3 of this prospectus before you make an investment in our securities.
Our principal executive offices are located at Westpointe Corporate Center One, 1550 Coraopolis Heights Road, Moon Township, PA 15108. Our telephone number is (412) 262-2830.
Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.
Prospectus date November 28, 2007
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No dealer, salesperson or other individual has been authorized to give any information or make any representations not contained in this prospectus in connection with the offering made by this prospectus. If given or made, such information or representations must not be relied upon as having been authorized by us. This prospectus does not constitute an offer to sell, or a solicitation of an offer to buy, any of our securities in any jurisdiction in which such an offer or solicitation is not authorized or in which the person making such offer or solicitation is not qualified to do so, or to any person to whom it is unlawful to make such offer or solicitation. Neither the delivery of this prospectus nor any sale made hereunder shall, under any circumstances, create an implication that there has not been any change in the facts set forth in this prospectus or in the affairs of our company since the date hereof.
GUIDE TO READING THIS PROSPECTUS
This prospectus is part of a registration statement that we filed with the Securities and Exchange Commission, or SEC, utilizing a “shelf” registration process or continuous offering process. Under this shelf registration process, the selling unitholders may, from time to time, sell the securities described in this prospectus in one or more offerings. This prospectus provides you with a general description of the securities which may be offered by the selling unitholders. Additional information, including our financial statements and the notes thereto, is incorporated in this prospectus by reference to our reports filed with the SEC. See “Where You Can Find More Information.” You are urged to read this prospectus, including the “Risk Factors,” and our SEC reports in their entirety.
The following information should help you understand some of the terms used in this prospectus. Unless the context indicates otherwise:
| • | the terms “the Partnership,” “we,” “our” and “us” refer to Atlas Pipeline Partners, L.P. and its subsidiaries; |
| • | the term “our general partner” refers to Atlas Pipeline Partners GP, LLC; |
| • | we refer to natural gas liquids, such as ethane, propane, normal butane, isobutane and natural gasoline, as “NGLs”; and |
| • | we refer to the Federal Energy Regulatory Commission as “FERC.” |
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INFORMATION ABOUT ATLAS PIPELINE PARTNERS, L.P.
We are a publicly-traded midstream energy services provider engaged in the transmission, gathering and processing of natural gas. We are a leading provider of natural gas gathering services in the Anadarko, Arkoma, Golden Trend and Permian Basins in the southwestern and mid-continent United States, and the Appalachian Basin in the eastern United States. In addition, we provide natural gas processing and treatment services in Oklahoma and Texas. We also provide interstate gas transmission services in southeast Oklahoma, Arkansas and southeast Missouri. We conduct our business through two operating segments: our Mid-Continent operations and our Appalachian operations.
We own and operate through our Mid-Continent operations:
| • | a Federal Energy Regulatory Commission, or FERC, -regulated, 565-mile interstate pipeline system, which we refer to as “Ozark Gas Transmission,” that extends from southeastern Oklahoma through Arkansas and into southeastern Missouri; |
| • | three natural gas processing plants and one treating facility, each located in Oklahoma; and |
| • | 1,900 miles of active natural gas gathering systems located in Oklahoma, Arkansas, northern Texas and the Texas panhandle, which transport gas from wells and central delivery points in the Mid-Continent region to our natural gas processing plants or Ozark Gas Transmission. |
In addition, as a result of our recent acquisitions from Anadarko Petroleum Corporation, we also operate the following:
| • | The Chaney Dell system is located in northwest Oklahoma and southern Kansas, near the center of the Anadarko Basin. This system consists of two active processing facilities: |
| • | the Waynoka plant, a 200 Mmcf/d cryogenic unit in Woods County, OK; |
| • | the Chester plant, a 30 Mmcf/d cryogenic expander unit in Woodward County, OK; and |
| • | approximately 3,470 miles of gathering pipeline covering six counties in the Anadarko Basin across northwestern Oklahoma and southern Kansas. |
| • | The Midkiff/Benedum system is located in the Spraberry Trend of the Permian Basin, near Midland, Texas. This system consists of the following: |
| • | the Midkiff plant, a 130 Mmcf/d cryogenic facility in Reagan County, TX; |
| • | the Benedum plant, a 43 Mmcf/d cryogenic facility in Upton County, TX; and |
| • | approximately 2,500 miles of gathering pipeline located across four counties in the Permian Basin of west Texas. |
Through our Appalachian operations, we own and operate 1,600 miles of intrastate natural gas gathering systems in eastern Ohio, western New York and western Pennsylvania. Through an omnibus agreement and other agreements between us and Atlas America, Inc. (NASDAQ: ATLS) and its affiliates, including Atlas Energy Resources, LLC (NYSE: ATN), a leading sponsor of natural gas drilling investment partnerships in the Appalachian Basin, we
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gather substantially all of the natural gas for our Appalachian Basin operations from wells operated by Atlas Energy. Among other things, the omnibus agreement requires Atlas Energy to connect to our gathering systems wells it operates that are located within 2,500 feet of our gathering systems. We are also party to natural gas gathering agreements with Atlas America and Atlas Energy under which we receive gathering fees, generally equal to a percentage, typically 16%, of the selling price of the natural gas we transport.
Our principal executive offices are located at Westpointe Corporate Center One, 1550 Coraopolis Heights Road, Moon Township, PA 15108 and our telephone number is (412) 262-2830.
Our website is www.atlaspipelinepartners.com. The information found on, or otherwise accessible through, our website is not incorporated into, and does not form a part of, this prospectus or any other report or document we file with or furnish to the SEC.
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You should consider the following risk factors together with all of the other information included in this prospectus in evaluating an investment in our securities. If any of the following risks actually occurs, our business, financial condition or results of operations could be materially adversely affected. In that case, the trading price of our securities could decline and you may lose some or all of your investment.
Risks Relating to Our Business
The amount of cash we generate depends in part on factors beyond our control.
The amounts of cash that we generate may not be sufficient for us to pay distributions at our current or any other level of distribution. Our ability to make cash distributions depends primarily on our cash flow. Cash distributions do not depend directly on our profitability, which is affected by non-cash items. Therefore, cash distributions may be made during periods when we record losses and may not be made during periods when we record profits. The actual amounts of cash we generate will depend upon numerous factors relating to our business which may be beyond our control, including:
| • | the demand for and price of natural gas and NGLs; |
| • | the volume of natural gas we transport; |
| • | expiration of significant contracts; |
| • | continued development of wells for connection to our gathering systems; |
| • | the availability of local, intrastate and interstate transportation systems; |
| • | the expenses we incur in providing our gathering services; |
| • | the cost of acquisitions and capital improvements; |
| • | our issuance of equity securities; |
| • | required principal and interest payments on our debt; |
| • | fluctuations in working capital; |
| • | prevailing economic conditions; |
| • | fuel conservation measures; |
| • | alternate fuel requirements; |
| • | government regulation and taxation; and |
| • | technical advances in fuel economy and energy generation devices. |
In addition, the actual amount of cash that we will have available for distribution will depend on other factors, including:
| • | the level of capital expenditures we make; |
| • | the sources of cash used to fund our acquisitions; |
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| • | our debt service requirements and requirements to pay dividends on our outstanding preferred units, and restrictions on distributions contained in our current or future debt agreements; and |
| • | the amount of cash reserves established by our general partner for the conduct of our business. |
We cannot borrow under our credit facility to pay distributions of available cash to unitholders because such borrowings would not constitute “working capital borrowings” under our partnership agreement. Because we cannot borrow money to pay distributions unless we establish a facility that meets the definition contained in our partnership agreement, our ability to pay a distribution in any quarter is solely dependent on our ability to generate sufficient operating surplus with respect to that quarter.
Our financial and operating performance may fluctuate significantly from quarter to quarter. We may be unable to continue to generate sufficient cash flow to make distributions to our unitholders or to meet our working capital, capital expenditure or debt service requirements. If we are unable to do so, we may be required to sell assets or equity, reduce capital expenditures, refinance all or a portion of our existing indebtedness or obtain additional financing. We may be unable to do so on acceptable terms, or at all.
The scope and costs of the risks involved in making acquisitions may prove greater than estimated at the time of the acquisition.
Any acquisition involves potential risks, including, among other things:
| • | the risk that reserves expected to support the acquired assets may not be of the anticipated magnitude or may not be developed as anticipated; |
| • | mistaken assumptions about revenues and costs, including synergies; |
| • | significant increases in our indebtedness and working capital requirements; |
| • | an inability to integrate successfully or timely the businesses we acquire; |
| • | the assumption of unknown liabilities; |
| • | limitations on rights to indemnity from the seller; |
| • | the diversion of management’s attention from other business concerns; |
| • | increased demands on existing personnel; |
| • | customer or key employee losses at the acquired businesses; and |
| • | the failure to realize expected growth or profitability. |
The scope and cost of these risks may ultimately be materially greater than estimated at the time of the acquisition. Further, our future acquisition costs may be higher than those we have achieved historically. Any of these factors could adversely impact our future growth and our ability to increase distributions.
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We have significant indebtedness under our credit facility. Our credit facility has substantial restrictions and financial covenants and we may have difficulty obtaining additional credit, which could adversely affect our operations and our ability to pay distributions to our unitholders.
We have significant indebtedness under our credit facility. As of September 30, 2007, we had approximately $33.5 million outstanding under our revolving credit facility and $830.0 million outstanding under our term loan. As a result of our indebtedness, we will use a portion of our cash flow to pay interest and principal when due, which will reduce the cash available to finance our operations and other business activities and could limit our flexibility in planning for or reacting to changes in our business and the industry in which we operate. The amount of our indebtedness may also cause us to be more vulnerable to economic downturns and adverse developments in our business. Our ability to access the capital markets to raise capital on favorable terms will be affected by our debt level and by adverse market conditions resulting from, among other things, general economic conditions, contingencies and uncertainties that are difficult to predict and impossible to control. Such a development could adversely affect our ability to obtain financing for working capital, capital expenditures or acquisitions or to refinance existing indebtedness.
We depend on our credit facility for future capital needs. The credit facility restricts our ability to obtain additional financing, make investments, lease equipment, sell assets and engage in business combinations. We also are required to comply with certain financial covenants and ratios. Our ability to comply with these restrictions and covenants in the future is uncertain and will be affected by the levels of cash flow from our operations and events or circumstances beyond our control. Our failure to comply with any of the restrictions and covenants under our credit facility could result in a default under our credit facility, which could cause all of our existing indebtedness to be immediately due and payable.
Our profitability is affected by the volatility of prices for natural gas and NGL products.
We derive a majority of our gross margin from percentage-of-proceeds and keep-whole contracts. As a result, our income depends to a significant extent upon the prices at which we buy and sell natural gas and at which we sell natural gas liquids, or NGLs, and condensate. A 10% change in the average price of NGLs, natural gas and condensate we process and sell would result in a change to our consolidated income for the year ended December 31, 2007 of approximately $5.3 million. Additionally, changes in natural gas prices may indirectly impact our profitability since prices can influence drilling activity and well operations and thus the volume of gas we gather and process. Historically, the price of both natural gas and NGLs has been subject to significant volatility in response to relatively minor changes in the supply and demand for natural gas and NGL products, market uncertainty and a variety of additional factors beyond our control, including those we describe in “––The amount of cash we generate depends in part on factors beyond our control,” above. We expect this volatility to continue. This volatility may cause our gross margin and cash flows to vary widely from period to period. Our hedging strategies may not be sufficient to offset price volatility risk and, in any event, do not cover all of the throughput volumes. Moreover, hedges are subject to inherent risks, which we describe in “— Our hedging strategies may fail to protect us and could reduce our gross margin and cash flow.”
The amount of natural gas we transport will decline over time unless we are able to attract new wells to connect to our gathering systems.
Production of natural gas from a well generally declines over time until the well can no longer economically produce natural gas and is plugged and abandoned. Failure to connect new
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wells to our gathering systems could, therefore, result in the amount of natural gas we transport reducing substantially over time and could, upon exhaustion of the current wells, cause us to abandon one or more of our gathering systems and, possibly, cease operations. The primary factors affecting our ability to connect new supplies of natural gas to our gathering systems include our success in contracting for existing wells that are not committed to other systems, the level of drilling activity near our gathering systems and, in the Mid-Continent region, our ability to attract natural gas producers away from our competitors’ gathering systems. Over time, fluctuations in energy prices can greatly affect production rates and investments by third parties in the development of new oil and natural gas reserves. Drilling activity generally decreases as oil and natural gas prices decrease. We have no control over the level of drilling activity in our service areas, the amount of reserves underlying wells that connect to our systems and the rate at which production from a well will decline. In addition, we have no control over producers or their production decisions, which are affected by, among other things, prevailing and projected energy prices, demand for hydrocarbons, the level of reserves, geological considerations, governmental regulation and the availability and cost of capital. Because our operating costs are fixed to a significant degree, a reduction in the natural gas volumes we transport or process would result in a reduction in our gross margin and cash flows.
The success of our Mid-Continent operations depends upon our ability to continually find and contract for new sources of natural gas supply from unrelated third parties.
Unlike our Appalachian operations, none of the drillers or operators in our Mid-Continent service area is an affiliate of ours. Moreover, our agreements with most of the drillers and operators with which our Mid-Continent operations do business do not require them to dedicate significant amounts of undeveloped acreage to our systems. As a result, we do not have assured sources to provide us with new wells to connect to our Mid-Continent gathering systems. Failure to connect new wells to our Mid-Continent operations will, as described in “— The amount of natural gas we transport will decline over time unless we are able to attract new wells to connect to our gathering systems,” above, reduce our gross margin and cash flows.
Our Mid-Continent operations currently depend on certain key producers for their supply of natural gas; the loss of any of these key producers could reduce our revenues.
During 2007, Chesapeake Energy Corporation, Kaiser-Francis Oil Company, Burlington Resources Inc., St. Mary Land and Exploration Company, Sanguine Gas Exploration, LLC and Pioneer supplied our Mid-Continent systems with a majority of their natural gas supply. If these producers reduce the volumes of natural gas that they supply to us, our gross margin and cash flows would be reduced unless we obtain comparable supplies of natural gas from other producers.
The curtailment of operations at, or closure of, any of our processing plants could harm our business.
If operations at any of our processing plants were to be curtailed, or closed, whether due to accident, natural catastrophe, environmental regulation or for any other reason, our ability to process natural gas from the relevant gathering system and, as a result, our ability to extract and sell NGLs, would be harmed. If this curtailment or stoppage were to extend for more than a short period, our gross margin and cash flows would be materially reduced.
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We may face increased competition in the future in our Mid-Continent service areas.
Our Mid-Continent operations may face competition for well connections. Duke Energy Field Services, LLC, ONEOK, Inc., Carrera Gas Company, Cimmarron Transportation, LLC and Enogex, Inc. operate competing gathering systems and processing plants in our Velma service area. In our Elk City and Sweetwater service area, ONEOK Field Services, Eagle Rock Midstream Resources, L.P., Enbridge Energy Partners, L.P., CenterPoint Energy, Inc. and Enogex Inc. operate competing gathering systems and processing plants. CenterPoint Energy, Inc.’s interstate system is the nearest direct competitor to our Ozark Gas Transmission system. CenterPoint and Hiland Partners operate competing gathering systems in Ozark Gas Gathering’s service area. Hiland Partners, DCP Midstream, Mustang Fuel Corporation and ONEOK Partners operate competing gathering systems and processing plants in our Chaney Dell service area. DCP Midstream, J.L. Davis, and Targa Resources operate competing gathering systems and processing plants in our Midkiff/Benedum service area. Some of our competitors have greater financial and other resources than we do. If these companies become more active in our Mid-Continent service areas, we may not be able to compete successfully with them in securing new well connections or retaining current well connections. If we do not compete successfully, the amount of natural gas we transport, process and treat will decrease, reducing our gross margin and cash flows.
The amount of natural gas we transport, treat or process may be reduced if the public utility and interstate pipelines to which we deliver gas cannot or will not accept the gas.
Our gathering systems principally serve as intermediate transportation facilities between sales lines from wells connected to our systems and the public utility or interstate pipelines to which we deliver natural gas. If one or more of these pipelines has service interruptions, capacity limitations or otherwise does not accept the natural gas we transport, and we cannot arrange for delivery to other pipelines, local distribution companies or end users, the amount of natural gas we transport may be reduced. Since our revenues depend upon the volumes of natural gas we transport, this could result in a material reduction in our gross margin and cash flows.
The amount of natural gas we transport, treat or process may be reduced if the natural gas liquids pipelines to which we deliver NGLs cannot or will not accept the gas.
If one or more of the pipelines to which we deliver NGLs has service interruptions, capacity limitations or otherwise does not accept the NGLs we sell to or transport on, and we cannot arrange for delivery to other pipelines, the amount of NGLs we sell or transport may be reduced. Since our revenues depend upon the volumes of NGLs we sell or transport, this could result in a material reduction in our gross margin and cash flows.
We may be unsuccessful in integrating the operations from our recent acquisitions or any future acquisitions with our operations and in realizing all of the anticipated benefits of these acquisitions.
We acquired our interest in the Chaney Dell and Midkiff/Benedum systems in July 2007 and are currently in the process of integrating their operations with ours. We also have an active, on-going program to identify other potential acquisitions. The integration of previously independent operations with ours can be a complex, costly and time-consuming process. The difficulties of combining the Chaney Dell and Midkiff/Benedum systems, as well as any operations we may acquire in the future, with us include, among other things:
| • | operating a significantly larger combined entity; |
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| • | the necessity of coordinating geographically disparate organizations, systems and facilities; |
| • | integrating personnel with diverse business backgrounds and organizational cultures; |
| • | consolidating operational and administrative functions; |
| • | integrating internal controls, compliance under Sarbanes-Oxley Act of 2002 and other corporate governance matters; |
| • | the diversion of management’s attention from other business concerns; |
| • | customer or key employee loss from the acquired businesses; |
| • | a significant increase in our indebtedness; and |
| • | potential environmental or regulatory liabilities and title problems. |
The process of combining companies or the failure to integrate them successfully could harm our business or future prospects, and result in significant decreases in our gross margin and cash flows.
The acquisitions of our interests in the Chaney Dell and Midkiff/Benedum systems have substantially changed our business, making it difficult to evaluate our business based upon our historical financial information.
The acquisitions of our interests in the Chaney Dell and Midkiff/Benedum systems have significantly increased our size and substantially redefined our business plan, expanded our geographic market and resulted in large changes to our revenues and expenses. As a result of these acquisitions, and our continued plan to acquire and integrate additional companies that we believe present attractive opportunities, our financial results for any period or changes in our results across periods may continue to dramatically change. Our historical financial results, therefore, should not be relied upon to accurately predict our future operating results, thereby making the evaluation of our business more difficult.
The success of our Appalachian operations depends upon Atlas Energy Resources, LLC’s ability to drill and complete commercial producing wells.
Substantially all of the wells we connect to our gathering systems in our Appalachian service area are drilled and operated by Atlas Energy Resources, LLC for drilling investment partnerships sponsored by it. As a result, our Appalachian operations depend principally upon the success of Atlas Energy in sponsoring drilling investment partnerships and completing wells for these partnerships. Atlas Energy operates in a highly competitive environment for acquiring undeveloped leasehold acreage and attracting capital. Atlas Energy may not be able to compete successfully in the future in acquiring undeveloped leasehold acreage or in raising additional capital through its drilling investment partnerships. Furthermore, Atlas Energy is not required to connect wells for which it is not the operator to our gathering systems. If Atlas Energy cannot or does not continue to sponsor drilling investment partnerships, if the amount of money raised by those partnerships decreases, or if the number of wells actually drilled and completed as commercially producing wells decreases, the amount of natural gas transported by our Appalachian gathering systems would substantially decrease and could, upon exhaustion of the wells currently connected to our gathering systems, cause us to abandon one or more of our Appalachian gathering systems, thereby materially reducing our gross margin and cash flows.
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The failure of Atlas Energy to perform its obligations under our natural gas gathering agreements with it may adversely affect our business.
Substantially all of our Appalachian operating system revenues currently consist of the fees we receive under the master natural gas gathering agreement and other transportation agreements we have with Atlas Energy and its affiliates. We expect to derive a material portion of our gross margin from the services we provide under our contracts with Atlas Energy for the foreseeable future. Any factor or event adversely affecting Atlas Energy’s business or its ability to perform under its contracts with us or any default or nonperformance by Atlas Energy of its contractual obligations to us, could reduce our gross margin and cash flows.
Due to our lack of asset diversification, negative developments in our operations would reduce our ability to make distributions to our unitholders.
We rely exclusively on the revenues generated from our transportation, gathering and processing operations, and as a result, our financial condition depends upon prices of, and continued demand for, natural gas and NGLs. Due to our lack of asset-type diversification, a negative development in one of these businesses would have a significantly greater impact on our financial condition and results of operations than if we maintained more diverse assets.
Our construction of new assets may not result in revenue increases and is subject to regulatory, environmental, political, legal and economic risks, which could impair our results of operations and financial condition.
One of the ways we may grow our business is through the construction of new assets, such as the Sweetwater plant. The construction of additions or modifications to our existing systems and facilities, and the construction of new assets, involve numerous regulatory, environmental, political and legal uncertainties beyond our control and require the expenditure of significant amounts of capital. Any projects we undertake may not be completed on schedule at the budgeted cost, or at all. Moreover, our revenues may not increase immediately upon the expenditure of funds on a particular project. For instance, if we expand a gathering system, the construction may occur over an extended period of time, and we will not receive any material increase in revenues until the project is completed. Moreover, we may construct facilities to capture anticipated future growth in production in a region in which growth does not materialize. Since we are not engaged in the exploration for and development of natural gas reserves, we often do not have access to estimates of potential reserves in an area before constructing facilities in the area. To the extent we rely on estimates of future production in our decision to construct additions to our systems, the estimates may prove to be inaccurate because there are numerous uncertainties inherent in estimating quantities of future production. As a result, new facilities may not be able to attract enough throughput to achieve our expected investment return, which could impair our results of operations and financial condition. In addition, our actual revenues from a project could materially differ from expectations as a result of the price of natural gas, the NGL content of the natural gas processed and other economic factors described in this section.
We recently completed construction of our Sweetwater natural gas processing plant, from which we expect to generate additional incremental cash flow. We also continue to expand the natural gas gathering system surrounding Sweetwater in order to maximize its plant throughput.
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In addition to the risks discussed above, expected incremental revenue from the Sweetwater natural gas processing plant could be reduced or delayed due to the following reasons:
| • | difficulties in obtaining equity or debt financing for additional construction and operating costs; |
| • | difficulties in obtaining permits or other regulatory or third-party consents; |
| • | additional construction and operating costs exceeding budget estimates; |
| • | revenue being less than expected due to lower commodity prices or lower demand; |
| • | difficulties in obtaining consistent supplies of natural gas; and |
| • | terms in operating agreements that are not favorable to us. |
If we are unable to obtain new rights-of-way or the cost of renewing existing rights-of-way increases, then we may be unable to fully execute our growth strategy and our cash flows could be reduced.
The construction of additions to our existing gathering assets may require us to obtain new rights-of-way before constructing new pipelines. We may be unable to obtain rights-of-way to connect new natural gas supplies to our existing gathering lines or capitalize on other attractive expansion opportunities. Additionally, it may become more expensive for us to obtain new rights-of-way or to renew existing rights-of-way. If the cost of obtaining new rights-of-way or renewing existing rights-of-way increases, then our cash flows could be reduced.
Regulation of our gathering operations could increase our operating costs, decrease our revenues, or both.
Currently our gathering and processing of natural gas is exempt from regulation under the Natural Gas Act of 1938. However, the implementation of new laws or policies, or interpretations of existing laws, could subject us to regulation by FERC under the Natural Gas Act, the Natural Gas Policy Act, or other laws enacted after the date of this prospectus. Any such regulation would increase our costs, decrease our gross margin and cash flows, or both.
Nonetheless, FERC regulation will still affect our business and the market for our products. FERC’s policies and practices affect a range of our natural gas pipeline activities, including, for example, its policies on open access transportation, ratemaking, capacity release, environmental protection and market center promotion, which indirectly affect intrastate markets. In recent years, FERC has pursued pro-competitive policies in its regulation of interstate natural gas pipelines. However, we cannot assure you that FERC will continue this approach as it considers matters such as pipeline rates and rules and policies that may affect rights of access to natural gas transportation capacity.
Since federal law generally leaves any economic regulation of natural gas gathering to the states, state and local regulations may also affect our business. Matters subject to such regulation include access, rates, terms of service and safety. For example, our gathering lines are subject to ratable take, common purchaser, and similar statutes in one or more jurisdictions in which we operate. Common purchaser statutes generally require gatherers to purchase without undue discrimination as to source of supply or producer, while ratable take statutes generally require gatherers to take, without undue discrimination, natural gas production that may be tendered to the gatherer for handling. Texas and Oklahoma have adopted complaint-based
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regulation of natural gas gathering activities, which allows natural gas producers and shippers to file complaints with state regulators in an effort to resolve grievances relating to natural gas gathering access and discrimination with respect to rates or terms of service. Should a complaint be filed or regulation by the Texas Railroad Commission or Oklahoma Corporation Commission become more active, our revenues could decrease. Any of these laws may restrict our right as an owner of gathering facilities to decide with whom we contract to purchase or transport natural gas.
Increased regulatory requirements relating to the integrity of the Ozark Gas Transmission pipeline and our other assets could require us to spend additional money to comply with these requirements. In particular, Ozark Gas Transmission is subject to extensive laws and regulations related to pipeline integrity. Federal legislation signed into law in December 2002 includes guidelines for the U.S. Department of Transportation and pipeline companies in the areas of testing, education, training and communication. Compliance with existing and recently enacted regulations requires significant expenditures. Additional laws and regulations that may be enacted in the future, such as U.S. Department of Transportation implementation of additional hydrostatic testing requirements, could significantly increase the amount of these expenditures.
Ozark Gas Transmission is subject to FERC rate-making policies that could have an adverse impact on our ability to establish rates that would allow us to recover the full cost of operating the pipeline.
Rate-making policies by FERC could affect Ozark Gas Transmission’s ability to establish rates, or to charge rates that would cover future increases in its costs, or even to continue to collect rates that cover current costs. Natural gas companies may only charge rates that have been determined to be just and reasonable by FERC. The rates, terms and conditions of service provided by natural gas companies are required to be on file with FERC in FERC-approved tariffs. Pursuant to FERC’s jurisdiction over rates, existing rates may be challenged by complaint and proposed rate increases may be challenged by protest. We cannot assure you that FERC will continue to pursue its approach of pro-competitive policies as it considers matters such as pipeline rates and rules and policies that may affect rights of access to natural gas capacity and transportation facilities. Any successful complaint or protest against Ozark Gas Transmission’s rates could reduce our revenues associated with providing transmission services. We cannot assure you that we will be able to recover all of Ozark Gas Transmission’s costs through existing or future rates.
Ozark Gas Transmission is subject to regulation by FERC in addition to FERC rules and regulations related to the rates it can charge for its services.
FERC’s regulatory authority also extends to:
| • | operating terms and conditions of service; |
| • | the types of services Ozark Gas Transmission’s may offer to its customers; |
| • | construction of new facilities; |
| • | acquisition, extension or abandonment of services or facilities; |
| • | accounts and records; and |
| • | relationships with affiliated companies involved in all aspects of the natural gas and energy businesses. |
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FERC action in any of these areas or modifications of its current regulations can impair Ozark Gas Transmission’s ability to compete for business, the costs it incurs in its operations, the construction of new facilities or its ability to recover the full cost of operating its pipeline. For example, revisions to interstate gas quality standards by FERC could create two distinct markets for natural gas—an interstate market subject to minimum quality standards and an intrastate market with different minimum quality standards. Such a bifurcation of markets could make it difficult for our pipelines to compete in both markets or to attract certain gas supplies away from the intrastate market. The time FERC takes to approve the construction of new facilities could raise the costs of our projects to the point where they are no longer economic.
FERC has authority over the terms and conditions of interstate pipeline services. Under FERC’s open access requirements, service generally must be undertaken pursuant to the terms and conditions of the pipeline’s open access tariff. Contracts for such services that deviate in a material manner from a pipeline’s tariff must be filed for approval by FERC or, alternatively, the pipeline must amend its generally available tariff to include the deviating terms, thereby offering it to all shippers. If FERC audits a pipeline’s contracts and finds deviations that appear to be unduly discriminatory, FERC could conduct a formal enforcement investigation, resulting in serious penalties and/or onerous ongoing compliance obligations.
Should Ozark Gas Transmission fail to comply with all applicable FERC administered statutes, rules, regulations and orders, it could be subject to substantial penalties and fines. Under the recently enacted Energy Policy Act of 2005, FERC has civil penalty authority under the Natural Gas Act to impose penalties for current violations of up to $1,000,000 per day for each violation.
Finally, we cannot give any assurance regarding the likely future regulations under which we will operate Ozark Gas Transmission or the effect such regulation could have on our business, financial condition, and results of operations.
Compliance with pipeline integrity regulations issued by the DOT and state agencies could result in substantial expenditures for testing, repairs and replacement.
DOT and state agency regulations require pipeline operators to develop integrity management programs for transportation pipelines located in “high consequence areas.” The regulations require operators to:
| • | perform ongoing assessments of pipeline integrity; |
| • | identify and characterize applicable threats to pipeline segments that could impact a high consequence area; |
| • | improve data collection, integration and analysis; |
| • | repair and remediate the pipeline as necessary; and |
| • | implement preventative and mitigating actions. |
We do not believe that the cost of implementing integrity management program testing along certain segments of our pipeline will have a material effect on our results of operations. This does not include the costs, if any, of any repair, remediation, preventative or mitigating actions that may be determined to be necessary as a result of the testing program, which costs could be substantial.
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Our midstream natural gas operations may incur significant costs and liabilities resulting from a failure to comply with new or existing environmental regulations or a release of hazardous substances into the environment.
The operations of our gathering systems, plant and other facilities are subject to stringent and complex federal, state and local environmental laws and regulations. These laws and regulations can restrict or impact our business activities in many ways, including restricting the manner in which we dispose of substances, requiring remedial action to remove or mitigate contamination, and requiring capital expenditures to comply with control requirements. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements, and the issuance of orders enjoining future operations. Certain environmental statutes impose strict, joint and several liability for costs required to clean up and restore sites where substances and wastes have been disposed or otherwise released. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of substances or wastes into the environment.
There is inherent risk of the incurrence of environmental costs and liabilities in our business due to our handling of natural gas and other petroleum products, air emissions related to our operations, historical industry operations including releases of substances into the environment, and waste disposal practices. For example, an accidental release from one of our pipelines or processing facilities could subject us to substantial liabilities arising from environmental cleanup, restoration costs and natural resource damages, claims made by neighboring landowners and other third parties for personal injury and property damage, and fines or penalties for related violations of environmental laws or regulations. Moreover, the possibility exists that stricter laws, regulations or enforcement policies could significantly increase our compliance costs and the cost of any remediation that may become necessary. We may not be able to recover some or any of these costs from insurance.
Limitations on our access to capital or the market for our common units will impair our ability to execute our growth strategy.
Our ability to raise capital for acquisitions and other capital expenditures depends upon ready access to the capital markets. Historically, we have financed our acquisitions, and to a much lesser extent, expansions of our gathering systems by bank credit facilities and the proceeds of public and private equity offerings of our common units and preferred units of our operating partnership. If we are unable to access the capital markets, we may be unable to execute our strategy of growth through acquisitions.
We may issue additional units, which may increase the risk of not having sufficient available cash to maintain or increase our per unit distribution level.
We have wide discretion to issue additional units, including units that rank senior to our common units as to quarterly cash distributions, on the terms and conditions established by our general partner. The payment of distributions on these additional units may increase the risk that we will not be able to maintain or increase our per unit distribution level. To the extent new units are senior to our common units, their issuance will increase the uncertainty of the payment of distributions on the common units.
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Our hedging strategies may fail to protect us and could reduce our gross margin and cash flow.
We pursue various hedging strategies to seek to reduce our exposure to losses from adverse changes in the prices for natural gas, condensate and NGLs. Our hedging activities will vary in scope based upon the level and volatility of natural gas, condensate and NGL prices and other changing market conditions. Our hedging activity may fail to protect or could harm us because, among other things:
| • | hedging can be expensive, particularly during periods of volatile prices; |
| • | available hedges may not correspond directly with the risks against which we seek protection; |
| • | the duration of the hedge may not match the duration of the risk against which we seek protection; and |
| • | the party owing money in the hedging transaction may default on its obligation to pay. |
Litigation or governmental regulation relating to environmental protection and operational safety may result in substantial costs and liabilities.
Our operations are subject to federal and state environmental laws under which owners of natural gas pipelines can be liable for clean-up costs and fines in connection with any pollution caused by their pipelines. We may also be held liable for clean-up costs resulting from pollution which occurred before our acquisition of the gathering systems. In addition, we are subject to federal and state safety laws that dictate the type of pipeline, quality of pipe protection, depth, methods of welding and other construction-related standards. Any violation of environmental, construction or safety laws could impose substantial liabilities and costs on us.
We are also subject to the requirements of the Occupational Health and Safety Act, or OSHA, and comparable state statutes. Any violation of OSHA could impose substantial costs on us.
We cannot predict whether or in what form any new legislation or regulatory requirements might be enacted or adopted, nor can we predict our costs of compliance. In general, we expect that new regulations would increase our operating costs and, possibly, require us to obtain additional capital to pay for improvements or other compliance action necessitated by those regulations.
We are subject to operating and litigation risks that may not be covered by insurance.
Our operations are subject to all operating hazards and risks incidental to transporting and processing natural gas and NGLs. These hazards include:
| • | damage to pipelines, plants, related equipment and surrounding properties caused by floods and other natural disasters; |
| • | inadvertent damage from construction and farm equipment; |
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| • | leakage of natural gas, NGLs and other hydrocarbons; |
| • | fires and explosions; |
| • | other hazards, including those associated with high-sulfur content, or sour gas, that could also result in personal injury and loss of life, pollution and suspension of operations; and |
| • | acts of terrorism directed at our pipeline infrastructure, production facilities, transmission and distribution facilities and surrounding properties. |
As a result, we may be a defendant in various legal proceedings and litigation arising from our operations. We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for some of our insurance policies have increased substantially, and could escalate further. In some instances, insurance could become unavailable or available only for reduced amounts of coverage. For example, insurance carriers are now requiring broad exclusions for losses due to war risk and terrorist acts. If we were to incur a significant liability for which we were not fully insured, our gross margin and cash flows would be materially reduced.
Risks Related to Our Structure
Atlas America and its affiliates, including Atlas Energy, have conflicts of interest and limited fiduciary responsibilities, which may permit them to favor their own interests to the detriment of our unitholders.
Atlas America and its affiliates own and control our general partner, which also owns an 14% limited partner interest in us. We do not have any employees and rely solely on employees of Atlas America and its affiliates who serve as our agents, including all of the senior managers who operate our business. A number of officers and employees of Atlas America also own interests in us. Conflicts of interest may arise between Atlas America, our general partner and their affiliates, on the one hand, and us, on the other hand. As a result of these conflicts, our general partner may favor its own interests and the interests of its affiliates over our interests and the interests of our unitholders. These conflicts include, among others, the following situations:
| • | Employees of Atlas America who provide services to us also devote significant time to the businesses of Atlas America in which we have no economic interest. If these separate activities are significantly greater than our activities, there could be material competition for the time and effort of the employees who provide services to our general partner, which could result in insufficient attention to the management and operation of our business. |
| • | Neither our partnership agreement nor any other agreement requires Atlas America to pursue a future business strategy that favors us or, apart from our agreements with Atlas America relating to our Appalachian region operations, use our assets for transportation or processing services we provide. Atlas America’s directors and officers have a fiduciary duty to make these decisions in the best interests of the stockholders of Atlas America. |
| • | Our general partner is allowed to take into account the interests of parties other than us, such as Atlas America, in resolving conflicts of interest, which has the effect of limiting its fiduciary duty to us. |
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| • | Our general partner controls the enforcement of obligations owed to us by our general partner and its affiliates, including our agreements with Atlas Energy. |
Conflicts of interest with Atlas America and its affiliates, including the foregoing factors, could exacerbate periods of lower or declining performance, or otherwise reduce our gross margin and cash flows.
Cost reimbursements due our general partner may be substantial and will reduce the cash available for distributions to our unitholders.
We reimburse Atlas America, our general partner and their affiliates, including officers and directors of Atlas America, for all expenses they incur on our behalf. Our general partner has sole discretion to determine the amount of these expenses. In addition, Atlas America and its affiliates provide us with services for which we are charged reasonable fees as determined by Atlas America in its sole discretion. The reimbursement of expenses or payment of fees could adversely affect our ability to make distributions to our unitholders.
You will have very limited voting rights and ability to control management, which may diminish the price at which the common units will trade.
Unlike the holders of common stock in a corporation, you will have only limited voting rights on matters affecting our business. You will have no right to elect our general partner or its managing board on an annual or other continuing basis. The managing board of our general partner is chosen by Atlas America.
In addition, our general partner may be removed only upon the vote of the holders of at least 66 2/3% of the outstanding common units, excluding common units held by our general partner and its affiliates, and a successor general partner must be elected by a vote of the holders of at least a majority of the outstanding common units, excluding common units held by our general partner and its affiliates. Further, if any person or group, other than our general partner or its affiliates, acquires beneficial ownership of 20% or more of any class of units, that person or group will lose voting rights for all of its units. These provisions have the practical effect of making removal of our general partner difficult. Our partnership agreement requires that amendments to our partnership agreement must first be proposed or consented to by our general partner before they can be considered by unitholders. As a result, unitholders will not be able to initiate amendments to our partnership agreement not supported by our general partner. These provisions may diminish the price at which the common units trade.
Our partnership agreement contains provisions that will discourage attempts to change control of us, which may diminish the price at which the common units trade and may prevent a change of control even if doing so would be beneficial to the holders of common units.
Our partnership agreement contains provisions that may discourage a person or group from attempting to remove our general partner or otherwise seeking to change our management. As described in the immediately preceding risk factor, any person or group, other than our general partner or its affiliates, that acquires beneficial ownership of 20% or more of any class of units will lose voting rights for all of its units. In addition, if our general partner is removed under circumstances where cause does not exist and our general partner does not consent to that removal, then:
| • | the obligations of Atlas Energy under the omnibus agreement to connect wells to our Appalachian Basin gathering systems and to provide assistance for the expansion of our Appalachian Basin gathering systems will terminate; |
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| • | the obligations of Atlas Energy under the master natural gas gathering agreement will terminate as to any future wells drilled and completed by Atlas Energy; and |
| • | our general partner will have the right to convert its general partner interest and incentive distribution rights into common units or receive cash in exchange for those interests. |
These provisions may diminish the price at which the common units trade. These provisions may also prevent a change of control of us even if a change of control would be beneficial to the holders of the common units.
We may issue additional common units or securities senior to the common units without your approval, which would dilute existing unitholders’ interests.
Our general partner can cause us to issue additional common units without the approval of unitholders. We may also issue securities senior to the common units without the approval of unitholders. The issuance of additional common units or senior securities may dilute the value of the interests of the existing unitholders in our net assets and dilute the interests of unitholders in distributions by us.
Future sales of our common units may depress the price of our units.
Our general partner owns 5,476,253 of our common units which are being registered for public resale by this prospectus. While our general partner has no present intention to sell these units, it is not restricted from doing so. We cannot predict the effect, if any, that future sales of our common units or the availability of units for future sales will have on the market price of our common units. Sales of substantial amounts of common units or the perception that such sales could occur could reduce the price that our common units might otherwise obtain.
Tax Risks to Common Unitholders
For a discussion of the expected material federal income tax consequences of owning and disposing of common units, see “Tax Considerations” in this prospectus.
The IRS could treat us as a corporation, which would substantially reduce the cash available for distribution to unitholders.
The federal income tax benefit of an investment in the common units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested, and do not plan to request, a ruling from the IRS on this or any other matter affecting us. We have, however, received an opinion of Ledgewood, counsel to us and our general partner, that we will be classified as a partnership for federal income tax purposes. Opinions of counsel are based on specific factual assumptions and are not binding on the IRS or any court.
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If we were classified as a corporation for federal income tax purposes, we would pay tax on our income at the corporate tax rate, which is currently 35%. Distributions would generally be taxed again to the unitholders as corporate distributions, and no income, gains, losses or deductions would flow through to unitholders. Because a tax would be imposed upon us as an entity, the cash available for distribution to you would be substantially reduced, likely causing a substantial reduction in the value of the common units.
We cannot assure you that the law will not be changed and cause us to be treated as a corporation for federal income tax purposes or otherwise to be subject to entity-level taxation. Our partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, then specified provisions of the partnership agreement will be subject to change, including a decrease in distributions to reflect the impact of that law on us.
We may incur significant legal, accounting and related costs if the IRS challenges the federal income tax positions we take.
We have not requested a ruling from the IRS with respect to any matter affecting us. The IRS may adopt positions that differ from the conclusions of our counsel expressed in this prospectus supplement or from the positions we take. It may be necessary to resort to administrative or court proceedings to sustain counsel’s conclusions or the positions we take. A court may not concur with our conclusions. Any contest with the IRS may materially and negatively impact the market for the common units and the prices at which common units trade. In addition, the costs of any contest with the IRS, principally legal, accounting and related fees and expenses, will be borne directly or indirectly by our unitholders and our general partner.
You may be required to pay taxes on income from us even if you do not receive cash distributions.
You will be required to pay federal income taxes and, in certain cases, state and local income taxes on your allocable share of our income, whether or not you receive cash distributions from us. We cannot assure you that you will receive cash distributions equal to your allocable share of our taxable income or even equal to the tax liability to you resulting from that income. Further, you may incur a tax liability in excess of the amount of cash received upon the sale of your common units or upon our liquidation.
In prior taxable years, unitholders received cash distributions that exceeded the amount of taxable income allocated to the unitholders. This excess was partially the result of depreciation deductions, but was primarily the result of special allocations to our general partner of taxable income earned by our operating subsidiary, which caused a corresponding reduction in the amount of taxable income allocable to us. Since these special allocations increased our general partner’s capital account, it will receive an increased distribution upon our liquidation and distributions to unitholders will be correspondingly reduced.
Tax gain or loss on disposition of common units could be different than expected.
Upon the sale of common units, you will recognize gain or loss equal to the difference between the amount realized and your adjusted tax basis in those common units. Prior distributions in excess of the net taxable income you were allocated for a common unit which decreased your tax basis in that common unit will, in effect, become taxable income if you sell the common unit at a price greater than your tax basis in that common unit, even if the price is less than your original cost. A substantial portion of the amount realized, whether or not
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representing gains, may be ordinary income. Furthermore, should the IRS successfully contest our conventions, including our method of allocating income and loss as between transferors and transferees, you could realize more gain on the sale of common units than would be the case under those conventions without the benefit of decreased income in prior years.
Investors, other than individuals who are U.S. residents, may have adverse tax consequences from owning units.
Investment in common units by tax-exempt entities, regulated investment companies and foreign persons raises issues unique to them. For example, virtually all of our income will be unrelated business taxable income and will be taxable to organizations exempt from federal income tax, including IRAs and other retirement plans. Distributions to foreign persons will be reduced by withholding taxes.
We treat a purchaser of common units as having the same tax benefits without regard to the actual common units purchased; the IRS may challenge this treatment which could reduce the value of the units.
Because we cannot match transferors and transferees of common units, we will take certain tax positions that may not conform with all aspects of proposed and final Treasury regulations. For example, upon a transfer of units, we treat a portion of the Section 743(b) adjustment to a common unitholder’s tax basis in our assets as amortizable over the same remaining life and by the same method as the underlying assets, or nonamortizable if the underlying assets are nonamortizable. A successful IRS challenge to those conventions, including our method of amortizing Section 743(b) adjustments, could reduce the amount of tax benefits available to you. It also could affect the timing of these tax benefits or the amount of gain from your sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to your tax returns.
You will likely be subject to state and local taxes as a result of an investment in common units.
In addition to federal income taxes, you will likely be subject to other taxes, including state and local taxes, unincorporated business taxes and estate, inheritance or intangible taxes imposed by the various jurisdictions in which we do business or own property. You will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of the various jurisdictions in which we do business or own property. Further, you may be subject to penalties for failure to comply with those requirements. We currently own assets and do business in Arkansas, Kansas, Missouri, Ohio, Oklahoma, Pennsylvania, Texas and New York. Each of these states, except Texas, currently imposes a personal income tax. It is your responsibility to file all United States federal, state and local tax returns. Our counsel has not rendered an opinion on the state or local tax consequences of an investment in the common units.
The sale or exchange of 50% or more of our capital and profits interests during any 12-month period will result in the termination of our partnership for federal income tax purposes.
We will be considered to have terminated for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a 12-month period. Our termination would, among other things, result in the closing of our taxable year for all unitholders and could result in a deferral of depreciation deductions allowable in computing our taxable income.
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INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
The matters discussed or incorporated by reference in this prospectus may include forward-looking statements. These statements may be identified by the use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. In particular, statements about our expectations, beliefs, plans, objectives, assumptions or future events or performance contained in this report are forward-looking statements. We have based these forward-looking statements on our current expectations, assumptions, estimates and projections. While we believe these expectations, assumptions, estimates and projections are reasonable, such forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. These and other important factors may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements. Some of the key factors that could cause actual results to differ from our expectations include:
| • | the volatility of natural gas prices and demand for natural gas and NGLs; |
| • | our ability to connect new wells to our gathering systems; |
| • | our ability to integrate newly acquired businesses with our operations; |
| • | adverse effects of governmental and environmental regulation; |
| • | limitations on our access to capital or on the market for our common units; and |
| • | the strength and financial resources of our competitors. |
Other factors that could cause actual results to differ from those implied by the forward-looking statements in this report are more fully described in the “Risk Factors” section of this prospectus. Given these risks and uncertainties, you are cautioned not to place undue reliance on these forward-looking statements. The forward-looking statements included or incorporated by reference in this prospectus are made only as of the date hereof. We do not undertake and specifically decline any obligation to update any such statements or to publicly announce the results of any revisions to any of these statements to reflect future events or developments.
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This prospectus relates to our common units that may be offered and sold from time to time by the selling unitholders referred to in this prospectus. We will not receive any of the proceeds from the sale of the common units contemplated by this prospectus.
We describe our common units under the heading “Our Partnership Agreement.”
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The selling unitholders may from time to time offer and sell any or all of the common units set forth below pursuant to this prospectus. When we refer to “selling unitholders” in this prospectus, we mean those persons listed in the table below, and the pledges, donees, permitted transferees, assignees, successors and others who later come to hold any of the selling unitholders’ interests in our common units other than through a public sale.
The following table sets forth, as of the date of this prospectus, the name of each selling unitholder for whom we are registering units for resale to the public, and the number of common units that each selling unitholder may offer pursuant to this prospectus. Unless otherwise noted, the common units being offered by the selling unitholders were acquired from us in the private placement that was completed on July 27, 2007. The common units offered by the selling unitholders were issued pursuant to exemptions from the registration requirements of the Securities Act. We have agreed to file a registration statement covering the common units received by the selling unitholders. Except as noted below, none of the selling unitholders has, or within the past three years has had, any material relationship with us or any of our predecessors or affiliates and none of the selling unitholders is or was affiliated with registered broker-dealers.
Based on the information provided to us at the time of the initial filing of the registration statement of which this prospectus is a part by each selling unitholder and as of the date the same was provided to us, assuming that the selling unitholders sell all of the common units beneficially owned by them that have been registered by us and do not acquire any additional units during the offering, each selling unitholder will not own any units other than those appearing in the column entitled “Number of common units owned after the offering.” We cannot advise you as to whether the selling unitholders will in fact sell any or all of such common units. In addition, the selling unitholders may have sold, transferred or otherwise disposed of, or may sell, transfer or otherwise dispose of, at any time and from time to time, the commons unit in transactions exempt from the registration requirements of the Securities Act after the date on which they provided the information set forth on the table below.
| Name of selling unitholder |
Number of common units owned before the offering |
Number of common units being registered |
Number of common units owned after the offering(1) |
Percentage of common units owned after the offering | ||||
| Robert R. Firth(2) |
48,500 | 24,000 | 24,500 | * | ||||
| David Hall(2) |
21,000 | 21,000 | 0 | — | ||||
| Tom B. Williams(2) |
12,000 | 12,000 | 0 | — | ||||
| Mark B. Wade(2) |
3,000 | 3,000 | 0 | — | ||||
| Atlas Pipeline Partners GP, LLC(3) |
1,641,026 | 1,641,026 | 0 | — | ||||
| Atlas Pipeline Holdings, L.P. (3) |
3,835,227 | 3,835,227 | 0 | — | ||||
| Lehman Brothers Inc. (4) |
1,471,004 | 1,321,363 | 149,641 | * | ||||
| LB I GROUP, Inc. (5) |
965,909 | 965,909 | 0 | — | ||||
| Lehman Brothers MLP Opportunity Fund L.P. (6) |
193,182 | 193,182 | 0 | — | ||||
| Magnetar Capital Fund, LP(7) |
772,727 | 772,727 | 0 | — | ||||
| Swank MLP Convergence Fund, LP(8) |
289,772 | 289,772 | 0 | — | ||||
| The Cushing MLP Opportunity Fund I, LP(8) |
1,642,045 | 1,642,045 | 0 | — | ||||
| ZLP Fund, L.P. (9) |
772,727 | 772,727 | 0 | — | ||||
| Cobalt Partners, LP(10) |
309,136 | 309,136 | 0 | — | ||||
| Cobalt Capital SPV 2 LLC(10) |
295,900 | 295,900 | 0 | — | ||||
| Cobalt Partners II, LP(10) |
26,900 | 26,900 | 0 | — |
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| Name of selling unitholder |
Number of common units owned before the offering |
Number of common units being registered |
Number of common units owned after the offering(1) |
Percentage of offering | ||||
| Guggenheim Portfolio Company XI, LLC(10) |
44,200 | 44,200 | 0 | — | ||||
| Omega Capital Partners, L.P. (11) |
621,018 | 621,018 | 0 | — | ||||
| Omega Capital Investors, L.P. (11) |
116,300 | 116,300 | 0 | — | ||||
| Omega SPV Partners II, L.P. (11) |
471,900 | 471,900 | 0 | — | ||||
| Omega Equity Investors, L.P. (11) |
160,200 | 160,200 | 0 | — | ||||
| Beta Equities, Inc. (11) |
391,700 | 391,700 | 0 | — | ||||
| GS&Co Profit Sharing Master Trust(11) |
103,700 | 103,700 | 0 | — | ||||
| Presidential Life Corporation(11) |
8,000 | 8,000 | 0 | — | ||||
| The Ministers and Missionaries Benefit Board of America Baptist Churches(11) |
59,000 | 59,000 | 0 | — | ||||
| Brahman Partners II, LP(12) |
104,047 | 104,047 | 0 | — | ||||
| Brahman Partners III, LP(12) |
180,973 | 180,973 | 0 | — | ||||
| BY Partners, LP(12) |
292,090 | 292,090 | 0 | — | ||||
| Brahman C.P.F. Partners, LP(12) |
69,082 | 69,082 | 0 | — | ||||
| Brahman Partners IV, LP(12) |
174,830 | 174,830 | 0 | — | ||||
| UBS AG London Branch(13) |
965,909 | 965,909 | 0 | — | ||||
| Iridian Principals Fund, LP(14) |
19,318 | 19,318 | 0 | — | ||||
| First Eagle Fund of America(15) |
270,455 | 270,455 | 0 | — | ||||
| Leon G. Cooperman |
193,182 | 193,182 | 0 | — | ||||
| Toby Cooperman(16) |
38,636 | 38,636 | 0 | — | ||||
| Michael Cooperman(17) |
19,318 | 19,318 | 0 | — | ||||
| Watchung Road Associates, L.P. (11) |
96,591 | 96,591 | 0 | — | ||||
| Morgan Stanley Strategic Investments, Inc. (18) |
1,757,954 | 1,757,954 | 0 | — | ||||
| Structured Finance Americas, LLC(19) |
3,084,282 | 2,868,749 | 215,533 | * | ||||
| TPG-Axon Partners, LP(20) |
127,500 | 127,500 | 0 | — | ||||
| Royal Bank of Canada(21) |
1,444,445 | 1,429,545 | 14,900 | * | ||||
| Sunlight Capital Partners, LLC(22) |
676,136 | 676,136 | 0 | — | ||||
| Credit Suisse Management LLC(23) |
772,727 | 772,727 | 0 | — | ||||
| Baupost Limited Partnership 1983 A-1(24) |
230,000 | 230,000 | 0 | — | ||||
| Baupost Limited Partnership 1983 B-1(24) |
100,900 | 100,900 | 0 | — | ||||
| Baupost Limited Partnership 1983 C-1(24) |
569,563 | 569,563 | 0 | — | ||||
| HB Institutional Limited Partnership(24) |
251,500 | 251,500 | 0 | — | ||||
| PB Institutional Limited Partnership(24) |
118,700 | 118,700 | 0 | — | ||||
| YB Institutional Limited Partnership(24) |
82,800 | 82,800 | 0 | — | ||||
| Baupost Value Partnership, L.P. - I(24) |
140,700 | 140,700 | 0 | — | ||||
| Baupost Value Partnership, L.P. - II(24) |
104,600 | 104,600 | 0 | — | ||||
| Baupost Value Partnership, L.P. – III(24) |
62,600 | 62,600 | 0 | — | ||||
| Natixis Financial Products Inc. (25) |
1,448,864 | 1,448,864 | 0 | — |
| * | Less than 1%. |
| (1) | Assumes the selling unitholder sells all of the common units he or it is offering pursuant to this prospectus. |
| (2) | Mr. Firth has been the Chief Operating Officer and President of Atlas Pipeline Mid-Continent, LLC, our mid-continent subsidiary, since 2004; Mr. Hall has been its Chief Financial Officer since 2004; Mr. Williams has been its Senior Vice President, Technical Services since 2004 and Mr. Wade has been its Vice President, Optimization since 2005. Amounts shown in “Number of common units being registered” column represents common units issuable under the base incentive and additional incentive components of our executive group incentive program no later than December 31, 2007. For a description of our executive group incentive program, please see Item 11: Executive Compensation in our annual report on Form 10-K for the year ended December 31, 2006. |
| (3) | Atlas Pipeline Partners GP, LLC is our general partner and its managing board has voting and investment power over the securities held by it. The common units held by Atlas Pipeline Partners GP, LLC were issued to it in connection with our initial public offering. Atlas Pipeline Holdings, L.P. owns all of the outstanding membership interests of our general partner. Both selling unitholders are affiliates of us and may be deemed to be underwriters with respect to the securities they sell pursuant to this prospectus. |
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| (4) | The selling unitholder is a broker-dealer registered under the Securities Exchange Act of 1934. Any selling unitholder that is a broker-dealer may be deemed to be an underwriter with respect to the securities it sells pursuant to this prospectus. Lehman Brothers Holdings Inc., a public reporting company and the parent of the selling unitholder, may be deemed to have voting and investment power over these securities. |
| (5) | The selling unitholder is a wholly-owned subsidiary of Lehman Brothers Inc., which is a registered broker-dealer. The selling unitholder has represented to us that it is not acting as an underwriter with respect to securities sold pursuant to this prospectus, it purchased the units it is offering under this prospectus in the ordinary course of business, and, at the time of such purchase, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. Lehman Brothers Inc. and Lehman Brothers Holdings Inc., a public reporting company and the parent of Lehman Brothers Inc., may be deemed to have voting and investment power over these securities. |
| (6) | The selling unitholder is an “affiliate” of a broker-dealer and has represented to us that it is not acting as an underwriter with respect to securities sold pursuant to this prospectus, it purchased the units it is offering under this prospectus in the ordinary course of business, and, at the time of such purchase, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. The selling unitholder’s general partner is Lehman Brothers MLP Opportunity Associates LP, which is wholly-owned by Lehman Brothers MLP Opportunity Associates LLC. Lehman Brothers MLP Opportunity Associates LLC and its parent, Lehman Brothers Holdings Inc., a public reporting company, may be deemed to have voting and investment power over these securities. |
| (7) | Magnetar Financial LLC is the investment advisor of the selling unitholder and consequently has voting control and investment discretion over securities held by it. Magnetar Financial LLC disclaims beneficial ownership of the units held by the selling unitholder. Alec Litowitz has voting control over Supernova Management LLC, the general partner of Magnetar Capital Partners LP, the sole managing member of Mangetar Financial LLC. As a result, Mr. Litowitz may be considered the beneficial owner of any units deemed to be beneficially owned by Magnetar Financial LLC. Mr. Litowitz disclaims beneficial ownership of these units. |
| (8) | Jerry V. Swank, managing member of Swank Capital, LLC, the general partner of the investment advisor to the selling unitholder, has voting and investment power over these securities. |
| (9) | Stuart Zimmer and Craig Lucas share voting and investment power over these securities. |
| (10) | Wayne Cooperman, managing member of Cobalt Management, LLC GP, has voting and investment power over these securities. |
| (11) | Leon G. Cooperman has voting and investment power over these securities. |
| (12) | Peter A. Hochfelder, Mitchell A. Kuflik and Robert J. Sobel share voting and investment power over these securities. |
| (13) | The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. Chris Coward has voting and investment power over these securities. |
| (14) | David Cohen has voting and investment power over these securities. |
| (15) | Iridian Asset Management LLC is investment advisor for the selling unitholder and has voting and investment power over these securities. The portfolio manager for the unitholder is Harold Levy. |
| (16) | Toby Cooperman and Leon G. Cooperman share voting and investment power over these securities. |
| (17) | Michael Cooperman and Leon G. Cooperman share voting and investment power over these securities. |
| (18) | The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. Morgan Stanley, a public reporting company, may be deemed to have voting and investment power over these securities. |
| (19) | Deutsche Bank AG, the ultimate parent of the selling unitholder, has voting and investment power over these securities. The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. |
| (20) | Dinakar Singh, managing member of the selling unitholder’s general partner, has voting and investment power over these securities. |
| (21) | Royal Bank of Canada has voting and investment power over these securities. The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. |
| (22) | Paul E. Singer, principal of the general partners of Elliott Associates, L.P., the selling unitholder’s parent, has voting and investment power over these securities. |
| (23) | Credit Suisse (USA), Inc., the controlling shareholder of the selling unitholder, has voting and investment power over these securities. The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. |
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| (24) | The Baupost Group, L.L.C. is the investment manager of the selling unitholder and consequently has voting control and investment discretion over securities held by it. |
| (25) | The selling unitholder is an “affiliate” of a broker-dealer and certifies that it bought the securities in the ordinary course of business, and at the time of the purchase of the securities to be resold, it had no agreements or understandings, directly or indirectly, with any person to distribute the securities. The selling unitholder obtained beneficial ownership of the shares via a swap arrangement with the record holder, Wingate Capital Ltd. |
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The following is a summary of our partnership agreement, as amended through the date of this prospectus. The limited partnership agreement defines the rights and obligations pertaining to the common units.
Organization and Duration
We were formed in May 1999. We will dissolve on December 31, 2098, unless sooner dissolved under the terms of our partnership agreement.
Purpose
Our purpose under our partnership agreement is limited to serving as the limited partner of our operating partnership and engaging in any business activity that may be engaged in by our operating partnership or that is approved by our general partner. The operating partnership agreement provides that our operating partnership may, directly or indirectly, engage in:
| • | operations as conducted on February 2, 2000, including the ownership and operation of our gathering systems; |
| • | any other activity approved by our general partner, but only to the extent that our general partner reasonably determines that, as of the date of the acquisition or commencement of the activity, the activity generates “qualifying income” as that term is defined in Section 7704 of the Internal Revenue Code; or |
| • | any activity that enhances the operations described above. |
The Units
Our common units represent limited partner interests in us. The holders of units are entitled to participate in partnership distributions and exercise the rights or privileges available to limited partners under our partnership agreement.
Limited Voting Rights
Holders of our units have limited voting rights and generally are entitled to vote only with respect to the following matters:
| • | a sale or exchange of all or substantially all of our assets; |
| • | our dissolution or reconstitution; |
| • | our merger; and |
| • | termination or material modification of the omnibus agreement or master natural gas gathering agreement with Atlas America. |
Removal of our general partner requires a two-thirds vote of all outstanding common units, excluding those held by our general partner and its affiliates. Our partnership agreement permits our general partner generally to make amendments to it that do not materially adversely affect unitholders without the approval of any unitholders.
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Cash Distribution Policy
Quarterly Distributions of Available Cash. Our operating partnership is required by the operating partnership agreement to distribute to us, within 45 days of the end of each fiscal quarter, all of its available cash for that quarter. We, in turn, distribute to our partners all of the available cash received from our operating partnership for that quarter.
Available cash generally means, for any of our fiscal quarters, all cash on hand at the end of the quarter less cash reserves that our general partner determines are appropriate to provide for our operating costs, including potential acquisitions, and to provide funds for distributions to the partners for any one or more of the next four quarters. We generally make distributions of all available cash within 45 days after the end of each quarter to holders of record on the applicable record date.
Distributions of Available Cash from Operating Surplus. Cash distributions are characterized as distributions from either operating surplus or capital surplus. This distinction affects the amounts distributed to unitholders relative to our general partner.
Operating surplus means:
| • | our cash balance, excluding cash constituting capital surplus, less |
| • | all of our operating expenses, debt service payments, maintenance costs, capital expenditures and reserves established for future operations. |
Capital surplus means capital generated only by borrowings other than working capital borrowings, sales of debt and equity securities and sales or other dispositions of assets for cash, other than inventory, accounts receivable and other assets disposed of in the ordinary course of business.
We treat all available cash distributed from any source as distributed from operating surplus until the sum of all available cash distributed since we began operations equals our total operating surplus from the date we began operations until the end of the quarter that immediately preceded the distribution. This method of cash distribution avoids the difficulty of trying to determine whether available cash is distributed from operating surplus or capital surplus. We treat any excess available cash, irrespective of its source, as capital surplus, which would represent a return of capital, and we will distribute it accordingly. For a discussion of distributions of capital surplus, see “—Distributions of Capital Surplus” below.
We distribute available cash from operating surplus for any quarter in the following manner:
| • | first, 98% to the common units, pro rata, and 2% to our general partner, until we have distributed $.42 for each outstanding common unit, which we refer to as the minimum quarterly distribution; and |
| • | after that, in the manner described in “–Incentive Distribution Rights” below. |
The 2% allocation of available cash from operating surplus to our general partner includes our general partner’s percentage interest in distributions from us and our operating partnership on a combined basis.
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Adjusted operating surplus for any period generally means operating surplus generated during that period, less:
| • | any net increase in working capital borrowings during that period and |
| • | any net reduction in cash reserves for operating expenditures during that period not relating to an operating expenditure made during that period, |
and plus:
| • | any net decrease in working capital borrowings during that period and |
| • | any net increase in cash reserves for operating expenditures during that period required by any debt instrument for the repayment of principal, interest or premium. |
Operating surplus generated during a period is equal to the difference between:
| • | the operating surplus determined at the end of that period and |
| • | the operating surplus determined at the beginning of that period. |
Incentive Distribution Rights. By “incentive distribution rights” we mean our general partner’s right to receive an increasing percentage of quarterly distributions of available cash from operating surplus after we have made the minimum quarterly distributions and we have met specified target distribution levels, as described below. Our general partner may transfer its incentive distribution rights separately from its general partner interest without the consent of the unitholders.
We make incentive distributions to our general partner for any quarter in which we have distributed available cash from operating surplus to the common unitholders in an amount equal to the minimum quarterly distribution plus amounts necessary to eliminate any cumulative arrearages in payment of the minimum quarterly distribution on the common units. If this condition is satisfied, the remaining available cash will be distributed as follows:
| • | first, 85% to all units, pro rata, and 15% to our general partner, until each unitholder has received a total of $.52 per unit for that quarter; |
| • | second, 75% to all units, pro rata, and 25% to our general partner, until each unitholder has received a total of $.60 per unit for that quarter; and |
| • | after that, 50% to all units, pro rata, and 50% to our general partner. |
The distributions to our general partner that exceed its aggregate 2% general partner interest represent the incentive distribution rights.
In connection with our private placement in July 2007, we recently amended our partnership agreement to subordinate incentive distributions as follows:
| • | For each quarter from the quarter beginning July 1, 2007 until the quarter ending December 31, 2007, after the holders of the incentive distribution rights have |
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| received an aggregate of $3.7 million with respect to those rights, they will not be entitled to further distributions with respect to those rights until the amount distributable, but for the application of this provision, to the holders of the incentive distribution rights would have been $8.7 million. |
| • | For each quarter from the quarter beginning January 1, 2008 until the quarter ending June 30, 2009, after the holders of the incentive distribution rights have received an aggregate of $7.0 million with respect to those rights, they will not be entitled to further distributions with respect to those rights until the amount distributable, but for the application of this provision, to the holders of the incentive distribution rights would have been $12.0 million. |
| • | For each quarter from and after the quarter beginning July 1, 2009, after the holders of the incentive distribution rights have received an aggregate of $7.0 million with respect to those rights, they will not be entitled to further distributions with respect to those rights until the amount distributable, but for the application of this provision, to the holders of the incentive distribution rights would have been $10.75 million. |
Any amounts not distributed to the holders of incentive distribution rights because of the operation of these provisions will be distributed 1.0101% to our general partner and 98.9899% to all unitholders.
Distributions from Capital Surplus. We distribute available cash from capital surplus in the following manner:
| • | first, 98% to all units, pro rata, and 2% to our general partner, until each common unit has received distributions equal to $13.00 per unit; and |
| • | after that, we will distribute all available cash from capital surplus, as if it were from operating surplus. |
When we make a distribution from capital surplus, we will treat it as if it were a repayment of your investment in your common units. For these purposes, the partnership agreement deems the investment to be $13.00 per common unit, which is the unit price from our initial public offering, regardless of the price you actually pay for your common units in this offering. To reflect this repayment, we will reduce the amount of the minimum quarterly distribution and the distribution levels at which our general partner’s incentive distribution rights begin, which we refer to in this prospectus as “target distribution levels,” by multiplying each amount by a fraction, determined as follows:
| • | the numerator is $13.00 less all distributions from capital surplus including the distribution just made, and |
| • | the denominator is $13.00 less all distributions from capital surplus excluding the distribution just made. |
We refer to the initial public offering price of $13.00 per common unit, less any distributions from capital surplus, as the “unrecovered unit price.”
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After the minimum quarterly distribution and the target distribution levels have been reduced to zero, we will treat all distributions of available cash from all sources as if they were from operating surplus. Because the minimum quarterly distribution and the target distribution levels will have been reduced to zero, our general partner will then be entitled to receive 48% of all distributions of available cash in its capacity as general partner and holder of the incentive distribution rights, in addition to any distributions to which it may be entitled as a holder of units.
Distributions from capital surplus will not reduce the minimum quarterly distribution or target distribution levels for the quarter in which they are distributed.
Adjustment of Minimum Quarterly Distribution and Target Distribution Levels. In addition to adjustments made upon a distribution of available cash from capital surplus, we will proportionately adjust each of the following upward or downward, as appropriate, if any combination or subdivision of units occurs:
| • | the minimum quarterly distribution, |
| • | the target distribution levels, |
| • | the unrecovered unit price, |
| • | the number of common units issuable upon conversion of the subordinated units, and |
| • | other amounts calculated on a per unit basis. |
For example, if a two-for-one split of the common units occurs, we will reduce the minimum quarterly distribution, the target distribution levels and the unrecovered initial unit price of the common units to 50% of their initial levels.
We will not make any adjustment for the issuance of additional common units for cash or property.
We may also adjust the minimum quarterly distribution and the target distribution levels if legislation is enacted or if existing law is modified or interpreted in a manner that causes us or our operating partnership to become taxable as a corporation or otherwise subject to taxation as an entity for federal, state or local income tax purposes. In this event, we will reduce the minimum quarterly distribution and the target distribution levels for each quarter after that time to amounts equal to the product of:
| • | the minimum quarterly distribution and each of the target distribution levels multiplied by |
| • | one minus the sum of: |
| • | the highest marginal federal income tax rate which could apply to the partnership that is taxed as a corporation plus |
| • | any increase in the effective overall state and local income tax rate that would have been applicable in the preceding calendar year as a result of the new imposition of the entity level tax, after taking into account the benefit of any deduction allowable for federal income tax purposes for the payment of state and local income taxes, but only to the extent of the increase in rates resulting from that legislation or interpretation. |
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For example, assuming we are not previously subject to state and local income tax, if we became taxable as a corporation for federal income tax purposes and subject to a maximum marginal federal, and effective state and local, income tax rate of 40%, then we would reduce the minimum quarterly distribution and the target distribution levels to 60% of the amount immediately before the adjustment.
Distributions of Cash Upon Liquidation. When we commence dissolution and liquidation, we will sell or otherwise dispose of our assets and adjust the partners’ capital account balances to reflect any resulting gain or loss. We will first apply the proceeds of liquidation to the payment of our creditors in the order of priority provided in our partnership agreement and by law. After that, we will distribute the proceeds to the unitholders and our general partner in accordance with their capital account balances, as so adjusted.
We maintain capital accounts in order to ensure that the partnership’s allocations of income, gain, loss and deduction are respected under the Internal Revenue Code. The balance of a partner’s capital account also determines how much cash or other property the partner will receive on liquidation of the partnership. A partner’s capital account is credited with (increased by) the following items:
| • | the amount of cash and fair market value of any property (net of liabilities) contributed by the partner to the partnership, and |
| • | the partner’s share of “book” income and gain (including income and gain exempt from tax). |
A partner’s capital account is debited with (reduced by) the following items:
| • | the amount of cash and fair market value (net of liabilities) of property distributed to the partner, and |
| • | the partner’s share of loss and deduction (including some items not deductible for tax purposes). |
Partners are entitled to liquidating distributions in accordance with their capital account balances.
Upon our liquidation, any gain, or unrealized gain attributable to assets distributed in kind, will be allocated to the partners in the following manner:
| • | first, to our general partner and the holders of units who have negative balances in their capital accounts to the extent of and in proportion to those negative balances; |
| • | second, 98% to the common units, pro rata, and 2% to our general partner, until the capital account for each common unit is equal to the sum of: |
| • | the unrecovered unit price, and |
| • | the amount of the minimum quarterly distribution for the quarter during which our liquidation occurs. |
| • | third, 85% to all units, pro rata, and 15% to our general partner, until there has been allocated under this paragraph an amount per unit equal to: |
| • | the excess of the $.52 target distribution per unit over the minimum quarterly distribution per unit for each quarter of our existence less |
| • | the cumulative amount per unit of any distribution of available cash from operating surplus in excess of the minimum quarterly distribution per unit that was distributed 85% to the units, pro rata, and 15% to our general partner for each quarter of our existence; |
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| • | fourth, 75% to all units, pro rata, and 25% to our general partner, until there has been allocated under this paragraph an amount per unit equal to: |
| • | the excess of the $.60 target distribution per unit over the $.52 target distribution per unit for each quarter of our existence less |
| • | the cumulative amount per unit of any distributions of available cash from operating surplus in excess of the first target distribution per unit that was distributed 75% to the units, pro rata, and 25% to our general partner for each quarter of our existence; and |
| • | after that, 50% to all units, pro rata, and 50% to our general partner. |
Upon our liquidation, any loss will generally be allocated to our general partner and the unitholders in the following manner:
| • | first, 98% to the holders of common units in proportion to the positive balances in their capital accounts and 2% to our general partner, until the capital accounts of the common unitholders have been reduced to zero; and |
| • | after that, 100% to our general partner. |
In addition, we will make interim adjustments to the capital accounts at the time we issue additional equity interests or make distributions of property. We will base these adjustments on the fair market value of the interests or the property distributed and we will allocate any gain or loss resulting from the adjustments to the unitholders and our general partner in the same manner as we allocate gain or loss upon liquidation. In the event that we make positive interim adjustments to the capital accounts, we will allocate any later negative adjustments to the capital accounts resulting from the issuance of additional equity interests, our distributions of property, or upon our liquidation, in a manner which results, to the extent possible, in the capital account balances of our general partner equaling the amount which would have been our general partner’s capital account balances if we had not made any earlier positive adjustments to the capital accounts.
Power of Attorney
Each limited partner, and each person who acquires a unit from a unitholder and executes and delivers a transfer application, grants to our general partner and, if appointed, a liquidator, a power of attorney to, among other things, execute and file documents required for our qualification, continuance or dissolution and the amendment of our partnership agreement, and to make consents and waivers under our partnership agreement.
Capital Contributions
Unitholders are not obligated to make additional capital contributions, except as described below under “—Limited Liability.”
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Limited Liability
So long as a limited partner does not participate in the control of our business within the meaning of the Delaware Revised Uniform Limited Partnership Act and otherwise acts in conformity with the provisions of our partnership agreement, the limited partner’s liability under the Delaware Act will be limited to the amount of capital he is obligated to contribute to us for his common units plus his share of any undistributed profits and assets. If it were determined that a limited partner participated in the control of our business, then the limited partner could be held personally liable for our obligations under Delaware law to the same extent as our general partner. This liability would extend only to persons who transact business with us who reasonably believe that the limited partner is a general partner. However, what constitutes participating in the control of a limited partnership’s business has not been clearly established in all states. If it were determined, for example, that the right, or exercise of a right, by the limited partners to:
| • | remove our general partner, |
| • | approve some amendments to our partnership agreement, or |
| • | take other action under our partnership agreement |
constituted participation in the control of our business, then limited partners could be held liable for our obligations to the same extent as our general partner.
Under the Delaware Act, we cannot make a distribution to a partner if, after the distribution, all our liabilities, other than liabilities to partners on account of their partnership interests and liabilities for which the recourse of creditors is limited to specific property, exceed the fair value of our assets. For the purpose of determining the fair value of the assets of a limited partnership, the Delaware Act provides that the fair value of property subject to liability for which recourse of creditors is limited shall be included in the assets of the limited partnership only to the extent that the fair value of that property exceeds the nonrecourse liability. The Delaware Act provides that a limited partner who receives a distribution and knew at the time of the distribution that the distribution was in violation of the Delaware Act is liable to the limited partnership for the amount of the distribution for three years. Under the Delaware Act, an assignee who becomes a substituted limited partner is liable for the obligations of his assignor to make contributions to the partnership, except the assignee is not obligated for liabilities unknown to him at the time he became a limited partner and which he could not ascertain from our partnership agreement.
Our operating partnership currently conducts business in Arkansas, Kansas, Missouri, New York, Ohio, Oklahoma, Pennsylvania and Texas. The limitations on the liability of limited partners for the obligations of a limited partnership have not been clearly established in many jurisdictions. If it were determined that we were, by virtue of our limited partner interest in our operating partnership or otherwise, conducting business in any state under the applicable limited partnership statute, or that the right or exercise of the right by the limited partners as a group to remove or replace our general partner, to approve some amendments to our partnership agreement, or to take other action under our partnership agreement constituted “participation in the control” of our business for purposes of the statutes of any relevant jurisdiction, then the limited partners could be held personally liable for our obligations under the law of that jurisdiction to the same extent as our general partner. We operate in a manner our general partner considers reasonable and appropriate to preserve the limited liability of the limited partners.
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Transfer Agent and Registrar
American Stock Transfer and Trust Company is the registrar and transfer agent for our common units. We pay all fees charged by the transfer agent for transfers of common units, except that the following fees must be paid by unitholders:
| • | surety bond premiums to replace lost or stolen certificates, taxes and other governmental charges, |
| • | special charges for services requested by a holder of a common unit, and |
| • | other similar fees or charges. |
There is no charge to unitholders for disbursements of cash distributions.
We have agreed to indemnify the transfer agent, its agents and each of their particular shareholders, directors, officers and employees against all claims and losses that may arise out of acts performed or omitted in its capacity as our transfer agent, except for any liability due to any negligence, gross negligence, bad faith or intentional misconduct of the indemnified person or entity.
Transfer of Common Units
The transfer agent will not record a transfer of common units, and we will not recognize the transfer, unless the transferee executes and delivers a transfer application. The form of transfer application appears on the reverse side of the certificates representing the common units. By executing and delivering a transfer application, the transferee of common units:
| • | becomes the record holder of the common units and is an assignee until admitted as a substituted limited partner; |
| • | automatically requests admission as a substituted limited partner; |
| • | agrees to be bound by the terms and conditions of our partnership agreement; |
| • | represents that the transferee has the capacity, power and authority to enter into our partnership agreement; |
| • | grants powers of attorney to officers of our general partner and, if one is ever appointed, our liquidator, as specified in our partnership agreement; and |
| • | makes the consents and waivers contained in our partnership agreement. |
An assignee will become a substituted limited partner as to the transferred common units upon the consent of our general partner and the recordation of the name of the assignee on our books and records. Our general partner may withhold its consent in its sole discretion.
A transferee’s broker, agent or nominee may complete, execute and deliver the transfer applications. We are entitled to treat the nominee holder of a common unit as the absolute owner. In that case, the beneficial holder’s rights are limited solely to those that it has against the nominee holder as a result of any agreement between the beneficial owner and the nominee holder.
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Common units are securities and are transferable according to the laws governing transfer of securities. In addition to the rights acquired upon transfer, the transferor gives the transferee the right to request admission as a substituted limited partner. A purchaser or transferee of common units who does not execute and deliver a transfer application will have only
| • | the right to assign the common units to a purchaser or other transferee and |
| • | the right to transfer the right to seek admission as a substituted limited partner. |
Thus, a purchaser or transferee of common units who does not execute and deliver a transfer application will not receive
| • | cash distributions or federal income tax allocations unless the common units are held in a nominee or “street name” account and the nominee or broker has executed and delivered a transfer application and |
| • | may not receive federal income tax information or reports furnished to record holders of common units. |
The transferor of common units must provide the transferee with all information necessary to transfer the common units. The transferor will not be required to insure the execution of the transfer application by the transferee and will have no liability or responsibility if the transferee neglects or chooses not to execute and forward the transfer application to the transfer agent. See “–Status as Limited Partner or Assignee.”
Until a common unit has been transferred on our books, we and the transfer agent may treat the record holder of the unit as the absolute owner for all purposes, except as otherwise required by law or stock exchange regulations, even if either of us has notice of an attempted transfer.
Issuance of Additional Securities
Our partnership agreement authorizes us to issue an unlimited number of additional limited partner interests, debt and other securities for the consideration and on the terms and conditions established by our general partner in its sole discretion without the approval of any limited partners. We have funded, and will likely continue to fund, acquisitions through the issuance of additional common units or other equity securities and debt securities. Holders of any additional common units we issue will be entitled to share equally with the then-existing holders of common units in our distributions of available cash. In addition, the issuance of additional common units may dilute the value of the interests of the then-existing holders of common units in our net assets.
In accordance with Delaware law and the provisions of our partnership agreement, we may also issue additional partnership securities that, in the sole discretion of our general partner, may have special voting rights to which the common units are not entitled.
Upon issuance of additional partnership securities, our general partner must make additional capital contributions to the extent necessary to maintain its combined 2% general partner interest in us and in our operating partnership. Moreover, our general partner will have the right, which it may from time to time assign in whole or in part to any of its affiliates, to purchase common units, subordinated units or other equity securities whenever, and on the same terms
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that, we issue those securities to persons other than our general partner and its affiliates, to the extent necessary to maintain its percentage interest that existed immediately before each issuance. The holders of common units will not have preemptive rights to acquire additional common units or other partnership interests.
Amendment of Our Partnership Agreement
Amendments to our partnership agreement may be proposed only by or with the consent of our general partner, which it may withhold in its sole discretion. In order to adopt a proposed amendment, other than the amendments discussed in “—No Unitholder Approval” below, our general partner must seek written approval of the holders of the number of units required to approve the amendment or call a meeting of the limited partners to consider and vote upon the proposed amendment.
Prohibited Amendments. No amendment may be made that would:
| • | change the percentage of outstanding units required to take partnership action, unless approved by the affirmative vote of unitholders constituting at least the voting requirement sought to be reduced; |
| • | enlarge the obligations of any limited partner without its consent, unless approved by at least a majority of the type or class of limited partner interests so affected; |
| • | enlarge the obligations of, restrict in any way any action by or rights of, or reduce in any way the amounts distributable, reimbursable or otherwise payable by us to our general partner or any of its affiliates without its consent, which may be given or withheld in its sole discretion; |
| • | change our term; |
| • | provide that we are not dissolved upon the expiration of our term or upon an election to dissolve us by our general partner that is approved by holders of a majority of the units of each class; or |
| • | give any person the right to dissolve us other than our general partner’s right to dissolve us with the approval of holders of a majority of the units of each class. |
The provision of our partnership agreement preventing the amendments having the effects described above can be amended upon the approval of the holders of at least 90% of the outstanding common units.
No Unitholder Approval. Our general partner may amend our partnership agreement, without the approval of the unitholders, to:
| • | change our name, the location of our principal place of business, our registered agent or registered office; |
| • | reflect the admission, substitution, withdrawal or removal of partners in accordance with our partnership agreement; |
| • | qualify us or continue our qualification as a limited partnership under the laws of any state or to ensure that neither we nor our operating partnership will be taxed as a corporation or otherwise taxed as an entity for federal income tax purposes; |
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| • | prevent us or our general partner, or its directors, officers, agents or trustees, from being subject to the provisions of the Investment Advisers Act of 1940 or “plan asset” regulations adopted under the Employee Retirement Income Security Act of 1974; |
| • | authorize additional limited or general partner interests; |
| • | reflect changes required by a merger agreement that has been approved under the terms of our partnership agreement; |
| • | permit us to form or invest in any entity, other than the operating partnership, permitted by our partnership agreement; |
| • | change our fiscal year or taxable year; and |
| • | make other changes substantially similar to any of the matters described above. |
In addition, our general partner may amend our partnership agreement, without the approval of the unitholders, if those amendments:
| • | do not adversely affect the limited partners in any material respect; |
| • | are necessary to satisfy any requirements or guidelines contained in any opinion, directive, order, ruling or regulation of any federal or state agency or judicial authority or contained in any federal or state statute; |
| • | are necessary to facilitate the trading of limited partner interests or to comply with any rule or guideline of any securities exchange or interdealer quotation system on which the limited partner interests are or will be listed for trading; |
| • | are necessary for any action taken by our general partner relating to splits or combinations of units; or |
| • | are required to effect the intent of the provisions of our partnership agreement or are otherwise contemplated by our partnership agreement. |
Opinion of Counsel and Unitholder Approval. Except in the case of the amendments described above under “—No Unitholder Approval,” amendments to our partnership agreement will not become effective without the approval of holders of at least 90% of the units unless we obtain an opinion of counsel to the effect that the amendment will not affect the limited liability under applicable law of any limited partner or cause us or our operating partnership to be taxable as a corporation or otherwise to be taxed as an entity for federal income tax purposes (to the extent not previously taxed as such). Subject to obtaining the opinion of counsel, any amendment that would have a material adverse effect on the rights or preferences of any type or class of outstanding units in relation to other classes of units will require the approval of at least a majority of the type or class of units so affected.
Merger, Sale or Other Disposition of Our Assets
Our general partner may not, without the prior approval of holders of a majority of the outstanding units, cause us to sell, exchange or otherwise dispose of all of substantially all of our assets, including by way of merger, consolidation or other combination, or approve on our behalf the sale, exchange or other disposition of all or substantially all of the assets of our operating partnership. However, our general partner may mortgage or otherwise grant a security interest in
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all or substantially all of our assets or sell all or substantially all of our assets under a foreclosure without that approval. Furthermore, provided that conditions specified in our partnership agreement are satisfied, our general partner may merge us or any of our subsidiaries into, or convey some or all of our and their assets to, a newly formed entity if the sole purpose of that merger or conveyance changes our legal form into another limited liability entity.
The unitholders are not entitled to dissenters’ rights of appraisal in the event of a merger, consolidation, sale of substantially all of our assets or any other transaction or event.
Termination and Dissolution
We will continue until December 31, 2098, unless terminated sooner upon:
| • | the election of our general partner to dissolve us, if approved by the holders of a majority of the outstanding units; |
| • | the sale, exchange or other disposition of all or substantially all of our assets and those of our operating partnership; |
| • | the entry of a decree of judicial dissolution of us; or |
| • | the withdrawal or removal of our general partner or any other event that results in its ceasing to be our general partner other than the transfer of its general partner interest in accordance with our partnership agreement or withdrawal or removal following approval and admission of a successor. |
Upon a dissolution under the last item above, the holders of a majority of the units may also elect, within specific time limitations, to reconstitute us by forming a new limited partnership on terms identical to those in our partnership agreement and having as general partner an entity approved by the holders of a majority of the units subject to our receipt of an opinion of counsel to the effect that:
| • | the action would not result in the loss of limited liability of any limited partner; and |
| • | we, the reconstituted limited partnership, and the operating partnership would not be taxed as a corporation or otherwise be taxed as an entity for federal income tax purposes upon the exercise of that right to continue. |
Liquidation and Distribution of Proceeds
Unless we are reconstituted and continue as a new limited partnership, upon our liquidation a liquidator will be selected to liquidate our assets and apply the proceeds of the liquidation as described in “—Cash Distribution Policy—Distributions of Cash Upon Liquidation.” The liquidator may defer liquidation or distribution of our assets for a reasonable period of time or distribute assets to partners in kind if it determines that a sale would be impractical or would cause undue loss to the partners.
Withdrawal or Removal of Our General Partner
Our general partner may withdraw as our general partner without first obtaining approval from the unitholders by giving 90 days’ written notice. Our general partner may also sell or otherwise transfer all of its general partner interests in us without the approval of the unitholders
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as described below under “–Transfer of General Partner Interest and Incentive Distribution Rights.” Upon withdrawal, we must reimburse our general partner for all expenses incurred by it on our behalf or allocable to us in connection with operating our business.
If our general partner withdraws, other than as a result of a transfer of all or a part of its general partner interests in us, the holders of a majority of the units may elect a successor to the withdrawing general partner. If a successor is not elected, or is elected but an opinion of counsel regarding limited liability and tax matters cannot be obtained, we will be dissolved and liquidated, unless within 180 days after that withdrawal the holders of a majority of the units agree in writing to continue our business and to appoint a successor general partner. See “—Termination and Dissolution.”
Our general partner may not be removed except by the vote of the holders of at least 66 2/3% of the outstanding common units, excluding common units held by our general partner and its affiliates, and we receive an opinion of counsel regarding limited liability and tax matters. Any removal is also subject to the approval of a successor general partner by the vote of the holders of a majority of the common units, excluding common units held by our general partner and its affiliates. If our general partner is removed under circumstances where cause does not exist and does not consent to that removal:
| • | the omnibus agreement with Atlas America, in which it agrees to connect wells to our gathering systems will terminate as to any future wells drilled by Atlas America; |
| • | the master natural gas gathering agreement with Atlas America will not apply to any future wells drilled by Atlas America although it will continue as to wells connected to the gathering system at the time of removal; |
| • | the obligations of Atlas America to provide assistance for the extension of our gathering systems and in the identification and acquisition of gathering systems from third parties will terminate; and |
| • | our general partner will have the right to convert its general partner interests and incentive distribution rights into common units or to receive cash in exchange for those interests from the successor general partner. |
Our partnership agreement defines “cause” as existing where a court has rendered a final, non-appealable judgment that our general partner has committed fraud, gross negligence or willful or wanton misconduct in its capacity as general partner.
Withdrawal or removal of our general partner as our general partner also constitutes its withdrawal or removal as the general partner of our operating partnership.
In the event of removal of our general partner under circumstances where cause exists or a withdrawal of our general partner that violates our partnership agreement, a successor general partner will have the option to purchase the general partner interests and incentive distribution rights of the departing general partner for a cash payment equal to the fair market value of those interests. Under all other circumstances where our general partner withdraws or is removed, the departing general partner will have the option to require the successor general partner to purchase those interests for their fair market value. In each case, fair market value will be determined by agreement between the departing general partner and the successor general partner. If they cannot reach an agreement, an independent expert selected by the departing general partner and the successor general partner will determine the fair market value. If the departing general partner
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and the successor general partner cannot agree on an expert, then an expert chosen by agreement of the experts selected by each of them will determine the fair market value. If the purchase option is not exercised by either the departing general partner or the successor general partner, the general partner interests and incentive distribution rights will automatically convert into common units equal to the fair market value of those interests. The successor general partner must indemnify the departing general partner (or its transferee) from all of our debt and liability arising on or after the date on which the departing general partner becomes a common unitholder as a result of the conversion. Except for this limited indemnity right and the right of the departing general partner to receive distributions on its common units, no other payments will be made to our general partner after withdrawal.
Transfer of General Partner Interest and Incentive Distribution Rights
Our general partner may transfer all or any part of its general partner interest without obtaining the consent of the unitholders. As a condition to the transfer of a general partner interest, the transferee must assume the rights and duties of the general partner to whose interest it has succeeded, furnish an opinion of counsel regarding limited liability and tax matters, agree to acquire all of the general partner’s interest in our operating partnership and agree to be bound by the provisions of the partnership agreement of our operating partnership.
The members of our general partner may sell or transfer all or part of their interest in our general partner to an affiliate without the approval of the unitholders. Atlas America and its affiliates have agreed that they will not divest their interest in our general partner without also divesting to the same acquiror their ownership interest in subsidiaries which act as the general partner of oil and gas investment partnerships sponsored by them.
Our general partner or a later holder may transfer its incentive distribution rights to an affiliate or another person as part of its merger or consolidation with or into, or sale of all or substantially all of its assets to, that person without the prior approval of the unitholders. However, the transferee must agree to be bound by the provisions of our partnership agreement.
Change of Management Provisions
Our partnership agreement contains specific provisions that are intended to discourage a person or group from attempting to remove Atlas Pipeline Partners GP, LLC as our general partner or otherwise change management. If any person or group other than our general partner and its affiliates acquires beneficial ownership of 20% or more of any class of units, that person or group will lose voting rights on all of its units and the units will not be considered outstanding for the purposes of noticing meetings, determining the presence of a quorum, calculating required votes and other similar matters. In addition, the removal of our general partner under circumstances where cause does not exist and our general partner does not consent to that removal has the adverse consequences described under “—Withdrawal or Removal of Our General Partner.”
Limited Call Right
If at any time not more than 20% of the outstanding limited partner interests of any class are held by persons other than our general partner and its affiliates, our general partner will have the right, which it may assign in whole or in part to any of its affiliates or to us, to acquire all, but not less than all, of the remaining limited partner interests of the class held by unaffiliated persons as of a record date selected by our general partner on at least 10 but not more than 60 days’ notice.
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The purchase price is the greater of:
| • | the highest cash price paid by our general partner or any of its affiliates for any limited partner interests of the class purchased within the 90 days preceding the date on which our general partner first mails notice of its election to purchase those limited partner interests and |
| • | the current market price as of the date three days before the date the notice is mailed. |
As a result of our general partner’s right to purchase outstanding limited partner interests, a holder of limited partner interests may have his limited partner interests purchased at an undesirable time or price. The tax consequences to a unitholder of the exercise of this call right are the same as a sale by that unitholder of his common units in the market.
Meetings; Voting
Except as described above under “–Change of Management Provisions,” unitholders or assignees who are record holders of units on a record date will be entitled to notice of, and to vote at, meetings of our limited partners and to act upon matters for which approvals may be solicited. Common units that are owned by an assignee who is a record holder, but who has not yet been admitted as a substituted limited partner, will be voted by our general partner at the written direction of the record holder. Absent direction of this kind, the common units will not be voted, except that, in the case of common units held by our general partner on behalf of non-citizen assignees, our general partner shall distribute the votes on those common units in the same ratios as the votes of limited partners on other units are cast.
Any action to be taken by the unitholders may be taken either at a meeting of the unitholders or without a meeting if consents in writing describing the action so taken are signed by holders of the same number of units as would be necessary to take the action. Meetings of the unitholders may be called by our general partner or by unitholders owning at least 20% of the outstanding units of the class for which a meeting is proposed. Unitholders may vote either in person or by proxy at meetings. The holders of a majority of the outstanding units of the class or classes for which a meeting has been called, represented in person or by proxy, will constitute a quorum unless any action by the unitholders requires approval by holders of a greater percentage of the units, in which case the quorum will be the greater percentage.
Except as described above under “—Change of Management Provisions,” each record holder will have a vote in accordance with his percentage interest, although additional limited partner interests having different voting rights could be issued. See “—Issuance of Additional Securities.” Units held in nominee or street name account will be voted by the broker or other nominee in accordance with the instruction of the beneficial owner.
We or the transfer agent will deliver any notice, report or proxy material required or permitted to be given or made to record holders of common units under our partnership agreement to the record holder.
Status as Limited Partner or Assignee
An assignee of a common unit, after executing and delivering a transfer application, but pending its admission as a substituted limited partner, is entitled to an interest equivalent to that of a limited partner sharing in allocations and distributions, including liquidating distributions.
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Our general partner will vote and exercise other powers attributable to common units owned by an assignee who has not become a substituted limited partner at the written direction of the assignee. See “—Meetings; Voting.” We will not treat transferees who do not execute and deliver a transfer application as assignees or as record holders of common units, and they will not receive cash distributions, federal income tax allocations or reports furnished to record holders. See “–Transfer of Common Units.”
Non-Citizen Assignees; Redemption
If we are or become subject to federal, state or local laws or regulations that, in the reasonable determination of our general partner, create a substantial risk of cancellation or forfeiture of any property in which we have an interest because of the nationality, citizenship or related status of any limited partner or assignee, we may redeem the units held by the limited partner or assignee at their current market price. In order to avoid any cancellation or forfeiture, our general partner may require each limited partner or assignee to furnish information about his nationality, citizenship or related status. If a limited partner or assignee fails to furnish this information within 30 days after a request for it, or our general partner determines after receipt of the information that the limited partner or assignee is not an eligible citizen, then the limited partner or assignee may be treated as a non-citizen assignee. In addition to other limitations on the rights of an assignee who is not a substituted limited partner, a non-citizen assignee does not have the right to direct the voting of his units and may not receive distributions in kind upon our liquidation.
Indemnification
Under the partnership agreement, we will indemnify the following persons, by reason of their status as such, to the fullest extent permitted by law, from and against all losses, claims or damages arising out of or incurred in connection with our business:
| • | our general partner; |
| • | any departing general partner; |
| • | any person who is or was an affiliate of our general partner or any departing general partner; |
| • | any person who is or was a member, partner, officer, director, employee, agent or trustee of our general partner, any departing general partner or the operating partnership or any affiliate of a general partner, any departing general partner or the operating partnership; or |
| • | any person who is or was serving at the request of a general partner or any departing general partner or any affiliate of a general partner or any departing general partner as an officer, director, employee, member, partner, agent, fiduciary or trustee of another person. |
Our indemnification obligation arises only if the indemnified person acted in good faith and in a manner the person reasonably believed to be in, and not opposed to, our best interests. With respect to criminal proceedings, the indemnified person must not have had reasonable cause to believe that the conduct was unlawful.
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Any indemnification under these provisions will be only out of our assets. Our general partner will not be personally liable for the indemnification obligations and will not have any obligation to contribute or loan funds to us in connection with it. The partnership agreement permits us to purchase insurance against liabilities asserted against and expenses incurred by persons for our activities, regardless of whether we would have the power to indemnify the person against liabilities under the partnership agreement.
Books and Reports
Our general partner keeps appropriate books on our business at our principal offices. The books are maintained for both tax and financial reporting purposes on an accrual basis. For tax and financial reporting purposes, our fiscal year is the calendar year.
We furnish or make available to record holders of common units, within 120 days after the close of each fiscal year, an annual report containing audited financial statements and a report on those financial statements by our independent public accountants. Except for our fourth quarter, we also furnish or make available summary financial information within 90 days after the close of each quarter.
We furnish each record holder information reasonably required for tax reporting purposes within 90 days after the close of each calendar year. We expect to furnish information in summary form so that some complex calculations normally required of partners can be avoided. Our ability to furnish this summary information to unitholders depends on the cooperation of unitholders in supplying us with specific information. We will furnish every unitholder with information to assist him in determining his federal and state tax liability and filing his federal and state income tax returns, regardless of whether he supplies us with information.
Right to Inspect Our Books and Records
Our partnership agreement provides that a limited partner can, for a purpose reasonably related to his interest as a limited partner, upon reasonable demand and at his own expense, have furnished to him:
| • | a current list of the name and last known address of each partner; |
| • | a copy of our tax returns; |
| • | information as to the amount of cash, and a description and statement of the agreed value of any other property or services, contributed or to be contributed by each partner and the date on which each became a partner; |
| • | copies of our partnership agreement, the certificate of limited partnership and related amendments and powers of attorney under which they have been executed; |
| • | information regarding the status of our business and financial condition; and |
| • | other information regarding our affairs that is just and reasonable. |
Our general partner intends to keep confidential from the limited partners trade secrets or other information the disclosure of which our general partner believes in good faith is not in our best interests or which we are required by law or by agreements with third parties to keep confidential.
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Registration Rights
Under the partnership agreement, we have agreed to register for resale under the Securities Act and applicable state securities laws any common units or other partnership securities proposed to be sold by our general partner or any of its affiliates if an exemption from the registration requirements is not otherwise available. We are obligated to pay all expenses incidental to the registration, excluding underwriting discounts and commissions.
In addition, on July 27, 2007, we entered into a registration rights agreement with some of the selling unitholders named in this prospectus. This agreement requires us to file by November 26, 2007 a shelf registration statement with the SEC providing for the resale from time to time of the common units held by those selling unitholders.
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This section is a discussion of the material tax considerations that may be relevant to prospective unitholders who are individual citizens or residents of the United States and, unless otherwise noted in the following discussion, is the opinion of Ledgewood, P.C., tax counsel to our general partner and us, insofar as it relates to matters of United States federal income tax law and legal conclusions with respect to those matters. This section is based upon current provisions of the Internal Revenue Code, existing and proposed regulations and current administrative rulings and court decisions, all of which are subject to change. Later changes in these authorities may cause the tax consequences to vary substantially from the consequences described below.
The following discussion does not address on all federal income tax matters affecting us or the unitholders. Moreover, the discussion focuses on unitholders who are individual citizens or residents of the United States and has only limited application to corporations, estates, trusts, nonresident aliens or other unitholders subject to specialized tax treatment, such as tax-exempt institutions, foreign persons, individual retirement accounts (IRAs), real estate investment trusts (REITs) or mutual funds. Accordingly, we urge you to consult, and depend on, your own tax advisor in analyzing the federal, state, local and foreign tax consequences particular to you of the ownership or disposition of common units.
All statements as to matters of law and legal conclusions, but not as to factual matters, contained in this section, unless otherwise noted, are the opinion of Ledgewood and are based on the accuracy of the representations made by us.
We have not received, and will not request, a ruling from the IRS regarding any matter affecting us or prospective unitholders. Instead, we will rely on opinions of Ledgewood. Unlike a ruling, an opinion of counsel represents only that counsel’s best legal judgment and does not bind the IRS or the courts. Accordingly, the opinions and statements made here may not be sustained by a court if contested by the IRS. Any contest of this sort with the IRS may materially and adversely impact the market for the common units and the prices at which common units trade. In addition, the costs of any contest with the IRS, principally legal, accounting and related fees, will result in a reduction in cash available for distribution to our unitholders and our general partner and thus will be borne indirectly by our unitholders and our general partner. Furthermore, the tax treatment of us, or of an investment in us, may be significantly modified by future legislative or administrative changes or court decisions. Any modifications may or may not be retroactively applied.
For the reasons described below, Ledgewood has not rendered an opinion with respect to the following specific federal income tax issues:
| • | the treatment of a unitholder whose common units are loaned to a short seller to cover a short sale of common units (please read “—Tax Consequences of Unit Ownership—Treatment of Short Sales”); |
| • | whether our monthly convention for allocating taxable income and losses is permitted by existing Treasury Regulations (please read “—Disposition of Common Units—Allocations Between Transferors and Transferees”); and |
| • | whether our method for depreciating Section 743 adjustments is sustainable in certain cases (please read “—Disposition of Common Units — Section 754 Election”). |
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Partnership Status
A partnership is not a taxable entity and incurs no federal income tax liability. Instead, each partner of a partnership is required to take into account its share of items of income, gain, loss and deduction of the partnership in computing its federal income tax liability, regardless of whether cash distributions are made to it by the partnership. Distributions by a partnership to a partner are generally not taxable unless the amount of cash distributed is in excess of the partner’s adjusted basis in its partnership interest.
Section 7704 of the Internal Revenue Code provides that publicly traded partnerships will, as a general rule, be taxed as corporations. However, an exception, referred to as the “qualifying income exception,” exists with respect to publicly traded partnerships of which 90% or more of the gross income for every taxable year consists of “qualifying income.” Qualifying income includes income and gains derived from the transportation, storage, processing and marketing of crude oil, natural gas and products thereof. Other types of qualifying income include interest (other than from a financial business), dividends, gains from the sale of real property and gains from the sale or other disposition of capital assets held for the production of income that otherwise constitutes qualifying income. We estimate that less than 1% of our current income is not qualifying income; however, this estimate could change from time to time. Based upon and subject to this estimate, the factual representations made by us and our general partner and a review of the applicable legal authorities, Ledgewood is of the opinion that at least 90% of our current gross income constitutes qualifying income.
We have not received, and will not seek, a ruling from the IRS and the IRS has made no determination as to our status for federal income tax purposes or whether our operations generate “qualifying income” under Section 7704 of the Internal Revenue Code. Instead, we will rely on the opinion of Ledgewood that, based upon the Internal Revenue Code, its regulations, published revenue rulings and court decisions and the representations described below, we will be classified as a partnership for federal income tax purposes.
In rendering its opinion, Ledgewood has relied on factual representations made by us and our general partner. The representations made by us and our general partner upon which Ledgewood has relied are:
| • | Neither we nor our operating partnership or any operating subsidiary has elected or will elect to be treated as a corporation; and |
| • | For each taxable year, more than 90% of our gross income will be income that Ledgewood has opined or will opine is “qualifying income” within the meaning of Section 7704(d) of the Internal Revenue Code. |
If we fail to meet the qualifying income exception, other than a failure that is determined by the IRS to be inadvertent and that is cured within a reasonable time after discovery, we will be treated as if we had transferred all of our assets, subject to liabilities, to a newly formed corporation, on the first day of the year in which we fail to meet the qualifying income exception, in return for stock in that corporation, and then distributed that stock to the unitholders in liquidation of their interests in us. This contribution and liquidation should be tax-free to unitholders and us so long as we, at that time, do not have liabilities in excess of the tax basis of our assets. Thereafter, we would be treated as a corporation for federal income tax purposes.
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If we were taxable as a corporation in any taxable year, either as a result of a failure to meet the qualifying income exception or otherwise, our items of income, gain, loss and deduction would be reflected only on our tax return rather than being passed through to the unitholders, and our net income would be taxed to us at corporate rates. In addition, any distribution made to a unitholder would be treated as either taxable dividend income, to the extent of our current or accumulated earnings and profits, or, in the absence of earnings and profits, a nontaxable return of capital, to the extent of the unitholder’s tax basis in his common units, or taxable capital gain, after the unitholder’s tax basis in his common units is reduced to zero. Accordingly, taxation of us as a corporation would result in a material reduction in a unitholder’s cash flow and after-tax return and thus would likely result in a substantial reduction of the value of the units.
The discussion below is based on Ledgewood’s opinion that we will be classified as a partnership for federal income tax purposes.
Limited Partner Status
Unitholders who have become our limited partners will be treated as our partners for federal income tax purposes. Counsel is also of the opinion, based upon and in reliance upon those same representations set forth under “—Partnership Status,” that
| • | assignees who have executed and delivered transfer applications and are awaiting admission as limited partners, and |
| • | unitholders whose common units are held in street name or by a nominee and who have the right to direct the nominee in the exercise of all substantive rights attendant to the ownership of their common units, |
will be treated as our partners for federal income tax purposes. As there is no direct authority addressing assignees of common units who are entitled to execute and deliver transfer applications and thereby become entitled to direct the exercise of attendant rights, but who fail to execute and deliver transfer applications, Counsel’s opinion does not extend to these persons. Furthermore, a purchaser or other transferee of common units who does not execute and deliver a transfer application may not receive some federal income tax information or reports furnished to record holders of common units unless the common units are held in a nominee or street name account and the nominee or broker has executed and delivered a transfer application for those common units.
A beneficial owner of common units whose units have been transferred to a short seller to complete a short sale would appear to lose his or her status as a partner with respect to such units for federal income tax purposes. See “—Tax Consequences of Unit Ownership—Treatment of Short Sales.”
Income, gain, deductions or losses would not appear to be reportable by a unitholder who is not a partner for federal income tax purposes, and any cash distributions received by a unitholder who is not a partner for federal income tax purposes would therefore be fully taxable as ordinary income. These holders should consult their own tax advisors with respect to their status as our partners for federal income tax purposes.
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Tax Consequences of Unit Ownership
Flow-through of Taxable Income. We do not pay any federal income tax. Instead, each unitholder is required to report on his or her income tax return his or her allocable share of our income, gains, losses and deductions without regard to whether we make cash distributions to that unitholder. Consequently, we may allocate income to our unitholders although we have made no cash distribution to them. Each unitholder will be required to include in income his or her allocable share of our income, gain, loss and deduction for our taxable year ending with or within his or her taxable year.
Treatment of Distributions. Our distributions generally will not be taxable for federal income tax purposes to the extent of a unitholder’s tax basis in his or her common units immediately before the distribution. Our cash distributions in excess of that tax basis generally will be considered to be gain from the sale or exchange of the common units, taxable in accordance with the rules described under “—Disposition of Common Units” below. Any reduction in a unitholder’s share of our liabilities for which no partner, including our general partner, bears the economic risk of loss, known as “nonrecourse liabilities,” will be treated as a distribution of cash to that unitholder. To the extent our distributions cause a unitholder’s “at risk” amount to be less than zero at the end of any taxable year, the unitholder must recapture any losses deducted in previous years. See “—Limitations on Deductibility of Our Losses.”
A decrease in a unitholder’s percentage interest in us because of our issuance of additional common units will decrease his or her share of our nonrecourse liabilities, and thus will result in a corresponding deemed distribution of cash. A non-pro rata distribution of money or property may result in ordinary income to a unitholder, regardless of his or her tax basis in our common units, if the distribution reduces his or her share of our “unrealized receivables,” including depreciation recapture, or substantially appreciated “inventory items,” both as defined in Section 751 of the Internal Revenue Code, known collectively as “Section 751 assets.” To that extent, a unitholder will be treated as having been distributed his or her proportionate share of the Section 751 assets and having exchanged those assets with us in return for the non-pro rata portion of the actual distribution made to him or her. This latter deemed exchange will generally result in the unitholder’s realization of ordinary income under Section 751(b) of the Internal Revenue Code. That income will equal the excess of:
| • | the non-pro rata portion of that distribution over |
| • | his or her tax basis for the share of Section 751 assets deemed relinquished in the exchange. |
Ratio of Taxable Income to Distributions. In prior taxable years, unitholders received cash distributions that exceeded the amount of taxable income allocated to the unitholders. This excess was partially the result of depreciation deductions, but was primarily the result of special allocations to our general partner of taxable income earned by our operating subsidiary which caused a corresponding reduction in the amount of taxable income allocable to us. Since these special allocations increased our general partner’s capital account, the distribution it would receive upon our liquidation will be increased and distributions to unitholders would be correspondingly reduced. It is possible that upon liquidation common unitholders will recognize taxable income in excess of liquidation distributions.
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Tax Rates. In general the highest effective United States federal income tax rate for individuals is currently 35% and the maximum United States federal income tax rate for net capital gains of an individual is currently 15% if the asset disposed of was held for more than 12 months at the time of disposition.
Alternative Minimum Tax. Although we do not expect to generate significant tax preference items or adjustments, each unitholder will be required to take into account his distributive share of any items of our income, gain, deduction or loss for purposes of the alternative minimum tax.
Basis of Common Units. A unitholder’s initial tax basis for his or her common units will be the amount he or she paid for the common units plus his or her share of our nonrecourse liabilities. That basis will be increased by his or her share of our income and by any increases in his or her share of our nonrecourse liabilities. That basis will be decreased, but not below zero, by our distributions to him or her, by his or her share of our losses, by any decreases in his or her share of our nonrecourse liabilities and by his or her share of our expenditures that are not deductible in computing taxable income and are not required to be capitalized.
Limitations on Deductibility of Our Losses. The deduction by a unitholder of his or her share of our losses will be limited to the tax basis in his or her units and, in the case of an individual unitholder or a corporate unitholder that is subject to the “at risk” rules (for example, if more than 50% of the value of its stock is owned directly or indirectly by five or fewer individuals or some tax-exempt organizations), to the amount for which the unitholder is considered to be “at risk” with respect to our activities, if that is less than its tax basis. A unitholder must recapture losses deducted in previous years to the extent that distributions cause his at risk amount to be less than zero at the end of any taxable year. Losses disallowed to a unitholder or recaptured as a result of these limitations will carry forward and will be allowable to the extent that his tax basis or at risk amount, whichever is the limiting factor, is subsequently increased. Upon the taxable disposition of a unit, any gain recognized by a unitholder can be offset by losses that were previously suspended by the at risk limitation but may not be offset by losses suspended by the basis limitation. Any excess loss above that gain previously suspended by the at risk or basis limitations is no longer utilizable.
In general, a unitholder will be at risk to the extent of the tax basis of his or her units, excluding any portion of that basis attributable to his or her share of our nonrecourse liabilities, reduced by any amount of money he or she borrows to acquire or hold the units, if the lender of those borrowed funds owns an interest in us, is related to the unitholder or can look only to the units for repayment. A unitholder’s at risk amount will increase or decrease as the tax basis of the unitholder’s units increases or decreases, other than tax basis increases or decreases attributable to increases or decreases in his or her share of our nonrecourse liabilities.
The passive loss limitations generally provide that individuals, estates, trusts and some closely-held corporations and personal service corporations can deduct losses from passive activities, which are generally activities in which the taxpayer does not materially participate, only to the extent of the taxpayer’s income from those passive activities. The passive loss limitations are applied separately with respect to each publicly-traded partnership. Consequently, any passive losses we generate will only be available to offset our passive income generated in the future and will not be available to offset income from other passive activities or investments, including our investments or your investments in other publicly-traded partnerships, or salary or active business income. Passive losses that are not deductible because they exceed a unitholder’s share of our income may be deducted in full when the unitholder disposes of his or her entire investment in us in a fully taxable transaction with an unrelated party. The passive activity loss rules are applied after other applicable limitations on deductions, including the at risk rules and the basis limitation.
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A unitholder’s share of our net income may be offset by any of our suspended passive losses, but it may not be offset by any other current or carryover losses from other passive activities, including those attributable to other publicly-traded partnerships.
Limitations on Interest Deductions. The deductibility of a non-corporate taxpayer’s “investment interest expense” is generally limited to the amount of that taxpayer’s “net investment income.” As noted, a unitholder’s share of our net passive income will be treated as investment income for this purpose. In addition, a unitholder’s share of our portfolio income will be treated as investment income. Investment interest expense includes:
| • | interest on indebtedness properly allocable to property held for investment; |
| • | our interest expense attributed to portfolio income; and |
| • | the portion of interest expense incurred to purchase or carry an interest in a passive activity to the extent attributable to portfolio income. |
The computation of a unitholder’s investment interest expense will take into account interest on any margin account borrowing or other loan incurred to purchase or carry a unit. Net investment income includes gross income from property held for investment and amounts treated as portfolio income under the passive loss rules, less deductible expenses, other than interest, directly connected with the production of investment income, but generally does not include gains attributable to the disposition of property held for investment.
Allocation of Income, Gain, Loss and Deductions. In general, if we have a net profit, our items of income, gain, loss and deduction will be allocated among our general partner and the unitholders in accordance with their percentage interests in us. At any time that incentive distributions are made to our general partner, gross income will be allocated to it to the extent of these distributions. In addition, for 2006 there may be a special allocation of taxable income to our general partner. See “ —Ratio of Taxable Income to Distributions.” If we have a net loss for the entire year, the amount of that loss will generally be allocated first to our general partner and the unitholders in accordance with their particular percentage interests in us to the extent of their positive capital accounts and, second, to our general partner.
As required by the Internal Revenue Code some items of our income, deduction, gain and loss will be allocated to account for the difference between the tax basis and fair market value of property contributed to us by our general partner referred to in this discussion as “contributed property,” and to account for the difference between the fair market value of our assets and their carrying value on our books at the time of this offering. The effect of these allocations to a unitholder purchasing common units will be essentially the same as if the tax basis of our assets were equal to their fair market value as of the date of this prospectus. In addition, specified items of recapture income will be allocated to the extent possible to the partner who was allocated the deduction giving rise to the treatment of that gain as recapture income in order to minimize the recognition of ordinary income by some unitholders.
Finally, although we do not expect that our operations will result in the creation of negative capital accounts, if negative capital accounts nevertheless result, items of our income and gain will be allocated in an amount and manner sufficient to eliminate the negative balance as quickly as possible.
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Ledgewood is of the opinion that, with the exception of the issues described in “—Disposition of Common Units—Section 754 Election” and “—Disposition of Common Units—Allocations Between Transferors and Transferees,” allocations under our partnership agreement will be recognized for federal income tax purposes in determining a partner’s share of an item of our income, gain, loss or deduction.
Entity-Level Collections. If we are required or elect under applicable law to pay any federal, state or local income tax on behalf of any unitholder or our general partner or any former unitholder, we are authorized to pay those taxes from our funds. That payment, if made, will be treated as a distribution of cash to the person on whose behalf the payment was made. If the payment is made on behalf of a person whose identity cannot be determined, we are authorized to treat the payment as a distribution to all current unitholders and our general partner. We are authorized to amend the partnership agreement in the manner necessary to maintain uniformity of intrinsic tax characteristics of units and to adjust later distributions, so that after giving effect to these distributions, the priority and characterization of distributions otherwise applicable under the partnership agreement is maintained as nearly as is practicable. Payments by us as described above could give rise to an overpayment of tax on behalf of a unitholder in which event he could file a claim for credit or refund.
Treatment of Short Sales. A unitholder whose units are loaned to a “short seller” to cover a short sale of units may be considered as having disposed of ownership of those units. If so, the unitholder would no longer own units for federal income tax purposes during the period of the loan and may recognize gain or loss from the disposition. As a result, during this period:
| • | any of our income, gain, deduction or loss with respect to those units would not be reportable by the unitholder; |
| • | any cash distributions we make to that unitholder with respect to those units would be fully taxable; and |
| • | all of those distributions would appear to be treated as ordinary income. |
Unitholders desiring to assure ownership of their units for tax purposes and avoid these consequences should modify any applicable brokerage account agreements to prohibit their brokers from borrowing their units. The IRS has announced that it is actively studying issues relating to the tax treatment of short sales of partnership interests. See also “—Disposition of Common Units—Recognition of Gain or Loss.” Because the IRS has not announced the results of its study and there is no authority addressing the treatment of short sales of partnership interests, Ledgewood is unable to opine on the treatment of such short sales.
Tax Treatment of Operations
Accounting Method and Taxable Year. We use the accrual method of accounting and the tax year ending December 31 for federal income tax purposes. Each unitholder must include in income his or her share of our income, gain, loss and deduction for our taxable year(s) ending within or with his or her taxable year. In addition, a unitholder who has a taxable year ending on a date other than December 31, and who disposes of all of his or her units following the close of our taxable year but before the close of his or her taxable year, must include his or her share of our income, gain, loss and deduction in income for his or her taxable year, with the result that he or she will be required to report income for his or her taxable year for his or her share of more than one year of our income, gain, loss and deduction.
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Tax Basis, Depreciation and Amortization. The tax basis of our assets will be used for purposes of computing depreciation and cost recovery deductions and, ultimately, gain or loss on the disposition of these assets. The federal income tax burden associated with the difference between the fair market value of property contributed and the tax basis established for that property will be borne by our general partner and the unitholders. See “—Tax Treatment of Unitholders—Allocation of Income, Gain, Loss and Deduction.”
To the extent allowable, we may elect to use the depreciation and cost recovery methods that will result in the largest deductions being taken in the early years after assets are placed in service. We are not entitled to any amortization deductions with respect to any goodwill conveyed to us on formation. Property we acquire or construct is depreciated using accelerated methods permitted by the Internal Revenue Code.
If we dispose of depreciable property by sale, foreclosure, or otherwise, all or a portion of any gain, determined by reference to the amount of depreciation previously deducted and the nature of the property, may be subject to the recapture rules and taxed as ordinary income rather than capital gain. Similarly, a unitholder who has taken cost recovery or depreciation deductions with respect to our property may be required to recapture those deductions as ordinary income upon a sale of his units. See “—Tax Consequences of Unit Ownership—Allocation of Income, Gain, Loss and Deduction” and “—Disposition of Common Units—Recognition of Gain or Loss.”
Uniformity of Units. We must maintain economic and tax uniformity of the units to all holders. A lack of tax uniformity can result from a literal application of Treasury Regulation Sections 1.167(c)-1(a)(6) and 1.197-2(g)(3). Any resulting non-uniformity could have a negative impact on the value of the common units by reducing the tax deductions available to a purchaser of units. See “—Disposition of Common Units—Section 754 Election.”
We intend to continue to depreciate or amortize the Section 743(b) adjustment attributable to unrealized appreciation in the value of contributed property in a way that will avoid non-uniformity of tax treatment among unitholders. See “—Disposition of Common Units—Section 754 Election.” If we determine that this position cannot reasonably be taken, we may adopt a different position in an effort to maintain uniformity. This could result in lower annual depreciation and amortization deductions than would otherwise be allowable to some unitholders and risk the loss of depreciation and amortization deductions not taken in the year that these deductions are otherwise allowable. The IRS may challenge any method of depreciating the Section 743(b) adjustment we adopt. If such a challenge were made and sustained, the uniformity of units might be affected, and the gain from the sale of units might be increased without the benefit of additional deductions. See “—Disposition of Common Units—Recognition of Gain or Loss.”
Valuation of Our Properties. The federal income tax consequences of the ownership and disposition of units depends in part on our estimates of the relative fair market values of our assets. Although we may from time to time consult with professional appraisers regarding valuation matters, we make many of the relative fair market value estimates ourselves. These estimates are subject to challenge and will not be binding on the IRS or the courts. If the estimates of fair market value are later found to be incorrect, the character and amount of items of income, gain, loss or deductions previously reported by unitholders might change, and unitholders might be required to adjust their tax liability for prior years and incur interest and penalties with respect to such adjustments.
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Disposition of Common Units
Recognition of Gain or Loss. Gain or loss will be recognized on a sale of units equal to the difference between the amount realized and the unitholder’s tax basis in the units sold. A unitholder’s amount realized will be measured by the sum of the cash or the fair market value of other property received plus his or her share of our nonrecourse liabilities. Because the amount realized includes a unitholder’s share of our nonrecourse liabilities, the gain recognized on the sale of units could result in a tax liability in excess of any cash received from the sale.
Prior distributions from us in excess of cumulative net taxable income for a common unit that decreased a unitholder’s tax basis in that common unit will, in effect, become taxable income if the common unit is sold at a price greater than the unitholder’s tax basis in that common unit, even if the price is less than his original cost.
Should the IRS successfully contest our method of depreciating or amortizing the Section 743(b) adjustment, described under “—Disposition of Common Units—Section 754 Election,” attributable to contributed property, a unitholder could realize additional gain from the sale of units than had our method been respected. In that case, the unitholder may have been entitled to additional deductions against income in prior years but may be unable to claim them, with the result to him of greater overall taxable income than appropriate. Due to the lack of final regulations, Ledgewood is unable to opine as to the validity of the convention but believes a contest by the IRS is unlikely because a successful contest could result in substantial additional deductions to other unitholders.
Except as noted below, gain or loss recognized by a unitholder, other than a “dealer” in units, on the sale or exchange of a unit held for more than one year will generally be taxable as capital gain or loss. Capital gain recognized by an individual on the sale of units held more than 12 months will generally be taxed at a maximum rate of 15%. However, a portion of this gain or loss, which will likely be substantial, will be separately computed and taxed as ordinary income under Section 751 of the Internal Revenue Code to the extent attributable to assets giving rise to depreciation recapture or other “unrealized receivables” or to “inventory items” we own. Ordinary income attributable to unrealized receivables, inventory items and depreciation recapture may exceed net taxable gain realized upon the sale of a unit and may be recognized even if there is a net taxable loss realized on that sale. Thus, a unitholder may recognize both ordinary income and a capital loss upon a disposition of units. Net capital loss may offset no more than $3,000 of ordinary income in the case of individuals and may only be used to offset capital gain in the case of corporations.
The IRS has ruled that a partner who acquires interests in a partnership in separate transactions must combine those interests and maintain a single adjusted tax basis. Upon a sale or other disposition of less than all of those interests, a portion of that tax basis must be allocated to the interests sold using an “equitable apportionment” method. Although the ruling is unclear as to how the holding period of these interests is determined once they are combined, Treasury regulations allow a selling unitholder, who can identify units transferred with an ascertainable holding period, to use the actual holding period of the units transferred. Thus, according to the ruling, a unitholder will not be able to select high or low basis common units to sell, as would be the case with corporate stock, but may designate specific common units sold for purposes of determining the holding period of units transferred. A unitholder electing to use the actual
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holding period of units transferred must consistently use that identification method for all subsequent sales or exchanges of units. A unitholder considering the purchase of additional common units or a sale of common units purchased in separate transactions should consult his tax advisor as to the possible consequences of this ruling and application of the Treasury regulations.
Specific provisions of the Internal Revenue Code affect the taxation of some financial products and securities, including partnership interests, by treating a taxpayer as having sold an “appreciated” partnership interest, one in which gain would be recognized if it were sold, assigned or terminated at its fair market value, if the taxpayer or related persons enter into:
| • | a short sale; |
| • | an offsetting notional principal contract; or |
| • | a futures or forward contract with respect to the partnership interest or substantially identical property. |
Moreover, if a taxpayer has previously entered into a short sale, an offsetting notional principal contract or a futures or forward contract with respect to the partnership interest, the taxpayer will be treated as having sold that position if the taxpayer or a related person then acquires the partnership interest or substantially identical property. The Secretary of Treasury is also authorized to issue regulations that treat a taxpayer that enters into transactions or positions that have substantially the same effect as the preceding transactions as having constructively sold the financial position.
Allocations Between Transferors and Transferees. Our taxable income and losses are determined annually, prorated on a monthly basis and apportioned among the unitholders in proportion to the number of units owned by each of them as of the opening of the New York Stock Exchange on the first business day of the month. However, gain or loss realized on a sale or other disposition of our assets other than in the ordinary course of business is allocated among the unitholders as of the opening of the New York Stock Exchange on the first business day of the month in which that gain or loss is recognized. As a result, a unitholder transferring units may be allocated income, gain, loss and deduction accrued after the date of transfer.
The use of this method may not be permitted under existing Treasury regulations. Accordingly, Ledgewood is unable to opine on the validity of this method of allocating income and deductions between transferors and transferees of units. If this method is not allowed under the Treasury Regulations, or only applies to transfers of less than all of the unitholder’s interest, our taxable income or losses might be reallocated among the unitholders. Under our partnership agreement, we are authorized to revise our method of allocation between transferors and transferees, as well as among partners whose interests otherwise vary during a taxable period, to conform to a method permitted under future Treasury regulations.
A unitholder who owns units at any time during a quarter and who disposes of them before the record date set for a cash distribution for that quarter will be allocated a share of our income, gain, loss and deductions attributable to that quarter but will not be entitled to receive that cash distribution.
Section 754 Election. We have made the election permitted by Section 754 of the Internal Revenue Code. That election is irrevocable without the consent of the IRS. The election generally permits us to adjust a common unit purchaser’s tax basis in our assets (“inside basis”) to reflect his or her purchase price. This election does not apply to a person who purchases common
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units directly from us. The adjustment belongs to the purchaser and not to other unitholders. For purposes of this discussion, a partner’s inside basis in our assets will be considered to have two components:
| • | his or her share of our tax basis in our assets (“common basis”) and |
| • | his or her Section 743(b) adjustment to that basis. |
Treasury regulations under Section 743 of the Internal Revenue Code require, if the remedial allocation method is adopted (which we have), a portion of the adjustment attributable to recovery property to be depreciated over the remaining cost recovery period for built-in gain. Under Treasury Regulation Section 1.167(c)-1(a)(6), an adjustment attributable to property subject to depreciation under Section 167 of the Internal Revenue Code rather than cost recovery deductions under Section 168 is generally required to be depreciated using either the straight-line method or the 150% declining balance method. A literal application of these different rules result in lack of uniformity. Under our partnership agreement, our general partner is authorized to adopt a position intended to preserve the uniformity of units even if that position is not consistent with the Treasury Regulations. See “—Tax Treatment of Operations—Uniformity of Units.”
We intend to depreciate the portion of a Section 743(b) adjustment attributable to unrealized appreciation in the value of property previously contributed to us, to the extent of any unamortized book-tax disparity, using a rate of depreciation or amortization derived from the depreciation or amortization method and useful life applied to the common basis of the property. If this contributed property is not amortizable, we will treat that portion as non-amortizable. This method is consistent with the regulations under Section 743. This method, however, is arguably inconsistent with Treasury Regulation Section 1.167(c)-1(a)(6) and Treasury Regulation Section 1.197-2(g)(3), neither of which is expected to directly apply to a material portion of our assets. To the extent this Section 743(b) adjustment exceeds that amount, we will apply the rules described in the Treasury Regulations and legislative history. If we determine that this position cannot reasonably be taken, we may adopt a different position which could result in lower annual depreciation or amortization deductions than would otherwise be allowable to specified unitholders. See “—Tax Treatment of Operations—Uniformity of Units.”
The allocation of the Section 743(b) adjustment among our assets must be made in accordance with the Internal Revenue Code. The IRS could seek to allocate some or all of any Section 743(b) adjustment to goodwill not so allocated by us. Goodwill, as an intangible asset, is generally amortizable over a longer period of time or under a less accelerated method than our tangible assets.
A Section 754 election is advantageous if the transferee’s tax basis in his or her units is higher than the units’ share of the aggregate tax basis of our assets immediately before the transfer. In that case, as a result of the election, the transferee would have a higher tax basis in his or her share of our assets for purposes of calculating, among other items, his or her depreciation and depletion deductions and share of any gain or loss on a sale of our assets. Conversely, a Section 754 election is disadvantageous if the transferee’s tax basis in his or her units is lower than the units’ share of the aggregate tax basis of our assets immediately before the transfer. Thus, the fair market value of the units may be affected either favorably or adversely by the election.
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The calculations involved in the Section 754 election are complex and we will make them on the basis of assumptions as to the value of our assets and other matters. There is no assurance that the determinations we make will not be successfully challenged by the IRS and that the deductions resulting from them will not be reduced or disallowed altogether. Should the IRS require a different basis adjustment to be made, and should, in our opinion, the expense of compliance exceed the benefit of the election, we may seek permission from the IRS to revoke our Section 754 election. If permission is granted, a subsequent purchaser of units may be allocated more income than he would have been allocated had the election not been revoked.
Notification Requirements. A unitholder who sells or exchanges units is required to notify us in writing of that sale or exchange within 30 days after the sale or exchange. We are required to notify the IRS of that transaction and to furnish information to the transferor and transferee. However, these reporting requirements do not apply to a sale by an individual who is a citizen of the United States and who effects the sale or exchange through a broker. Additionally, a transferor and a transferee of a unit will be required to furnish statements to the IRS, filed with their income tax returns for the taxable year in which the sale or exchange occurred, that describe the amount of the consideration received for the unit that is allocated to our goodwill or going concern value. Failure to satisfy these reporting obligations may lead to the imposition of substantial penalties.
Dissolutions and Terminations
Upon our dissolution, our assets will be sold and any resulting gain or loss will be allocated among our general partner and the unitholders. See “—Tax Consequences of Unit Ownership—Allocation of Income, Gain Loss and Deductions.” We will distribute all cash to our general partner and unitholders in liquidation in accordance with their positive capital account balances. See “Our Partnership Agreement—Cash Distribution Policy—Distributions of Cash on Liquidation” in the accompanying prospectus.
We will be considered to have terminated for tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a 12-month period. Our termination would result in the closing of our taxable year for all unitholders. In the case of a unitholder reporting on a taxable year other than a fiscal year ending December 31, the closing of our taxable year might result in more than 12 months of our taxable income or loss being includable in his taxable income for the year of termination. See “—Tax Treatment of Operations—Accounting Method and Taxable Year.” We would be required to make new tax elections after a termination, including a new election under Section 754 of the Internal Revenue Code, and a termination could result in a deferral of our deductions for depreciation. A termination could also result in penalties if we were unable to determine that the termination had occurred. Moreover, a termination might either accelerate the application of, or subject us to, any tax legislation enacted before the termination.
Tax-Exempt Organizations and Other Investors
Ownership of units by employee benefit plans, other tax-exempt organizations, nonresident aliens, foreign corporations, other foreign persons and regulated investment companies raises issues unique to those investors and, as described below, may have substantially adverse tax consequences.
Employee benefit plans and most other organizations exempt from federal income tax, including individual retirement accounts and other retirement plans, are subject to federal income tax on unrelated business taxable income. Virtually all of our taxable income allocated to a unitholder which is a tax-exempt organization will be unrelated business taxable income and thus will be taxable to that unitholder.
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A regulated investment company or “mutual fund” is required to derive 90% or more of its gross income from interest, dividends and gains from the sale of stocks or securities or foreign currency or specified related sources. T he American Jobs Creation Act of 2004 generally treats income from the ownership of a “qualified publicly traded partnership” as qualified income to a regulated investment company. We expect that we will meet the definition of a qualified publicly traded partnership. Accordingly, we anticipate that all of our income will be treated as qualified income to a regulated investment company.
Non-resident aliens and foreign corporations, trusts or estates that own units will be considered to be engaged in business in the United States on account of ownership of our units. As a consequence they will be required to file federal tax returns reporting their share of our income, gain, loss or deduction and pay federal income tax at regular rates on any net income or gain. Generally, a partnership is required to pay a withholding tax on the portion of the partnership’s income that is effectively connected with the conduct of a United States trade or business and which is allocable to foreign partners. Under rules applicable to publicly traded partnerships, we will withhold at the highest applicable effective tax rate on cash distributions made to foreign unitholders. Each foreign unitholder must obtain a taxpayer identification number from the IRS and submit that number to our transfer agent on a Form W-8 BEN in order to obtain credit for the taxes withheld.
Because a foreign corporation that owns units will be treated as engaged in a United States trade or business, that corporation may be subject to United States branch profits tax a rate of 30%, in addition to regular federal income tax, on its share of our income and gain, as adjusted for changes in its “U.S. net equity,” which are effectively connected with the conduct of a United States trade or business. That tax may be reduced or eliminated by an income tax treaty between the United States and the country in which the foreign corporate unitholder is a “qualified resident.” In addition, this type of unitholder is subject to special information reporting requirements under Section 6038C of the Internal Revenue Code.
Under a ruling of the IRS, a foreign unitholder who sells or otherwise disposes of a unit will be subject to federal income tax on gain realized on the disposition of that unit to the extent that this gain is effectively connected with a United States trade or business of the foreign unitholder. Apart from the ruling, a foreign unitholder will not be taxed or subject to withholding upon the disposition of a unit if he has owned less than 5% in value of the units during the five-year period ending on the date of the disposition and if the units are regularly traded on an established securities market at the time of the disposition.
Administrative Matters
Information Returns and Audit Procedures. We furnish to each unitholder, within 90 days after the close of each calendar year, specific tax information, including a Schedule K-1, which describes his or her share of our income, gain, loss and deduction for our preceding taxable year. In preparing this information, which is generally not reviewed by counsel, we take various accounting and reporting positions, some of which have been mentioned earlier, to determine the unitholder’s share of income, gain, loss and deduction. We cannot assure you that those accounting and reporting positions will yield a result that conforms with the requirements of the Internal Revenue Code, regulations, or administrative interpretations of the IRS. We also cannot assure you that the IRS will not successfully contend in court that those accounting and reporting positions are impermissible. Any challenge by the IRS could negatively affect the value of the units.
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The IRS may audit our federal income tax information returns. Adjustments resulting from any such audit may require each unitholder to adjust a prior year’s tax liability, and possibly may result in an audit of that unitholder’s own return. Any audit of a unitholder’s return could result in adjustments not related to our returns as well as those related to our returns.
Partnerships generally are treated as separate entities for purposes of federal tax audits, judicial review of administrative adjustments by the IRS and tax settlement proceedings. The tax treatment of partnership items of income, gain, loss and deduction are determined in a partnership proceeding rather than in separate proceedings with the partners. The Internal Revenue Code provides for one partner to be designated as the “tax matters partner” for these purposes. The partnership agreement appoints our general partner as our tax matters partner.
The tax matters partner will make some elections on our behalf and on behalf of unitholders. In addition, the tax matters partner can extend the statute of limitations for assessment of tax deficiencies against unitholders for items in our returns. The tax matters partner may bind a unitholder with less than a 1% profits interest in us to a settlement with the IRS unless that unitholder elects, by filing a statement with the IRS, not to give that authority to the tax matters partner. The tax matters partner may seek judicial review, by which all the unitholders are bound, of a final partnership administrative adjustment and, if the tax matters partner fails to seek judicial review, judicial review may be sought by any unitholder having at least a 1% interest in profits and by unitholders having in the aggregate at least a 5% profits interest. However, only one action for judicial review will go forward, and each unitholder with an interest in the outcome may participate.
A unitholder must file a statement with the IRS identifying the treatment of any item on his federal income tax return that is not consistent with the treatment of the item on our return. Intentional or negligent disregard of the consistency requirement may subject a unitholder to substantial penalties.
Nominee Reporting. Persons who hold an interest in us as a nominee for another person are required to furnish to us:
| • | the name, address and taxpayer identification number of the beneficial owner and the nominee; |
| • | whether the beneficial owner is |
| • | a person that is not a United States person; |
| • | a foreign government, an international organization or any wholly owned agency or instrumentality of either of the foregoing; or |
| • | a tax-exempt entity; |
| • | the amount and description of units held, acquired or transferred for the beneficial owner; and |
| • | specific information including the dates of acquisitions and transfers, means of acquisitions and transfers, and acquisition cost for purchases, as well as the amount of net proceeds from sales. |
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Brokers and financial institutions are required to furnish additional information, including whether they are United States persons and specific information on units they acquire, hold or transfer for their own account. A penalty of $50 per failure, up to a maximum of $100,000 per calendar year, is imposed by the Internal Revenue Code for failure to report that information to us. The nominee is required to supply the beneficial owner of the units with the information furnished to us.
Reportable Transactions. If we were to engage in a “reportable transaction,” we (and possibly you and others) would be required to make a detailed disclosure of the transaction to the IRS. A transaction may be a reportable transaction based upon any of several factors, including the fact that it is a type of transaction publicly identified by the IRS as a “listed transaction” or that it produces certain kinds of losses in excess of $2 million. Our participation in a reportable transaction could increase the likelihood that our federal income tax information return (and possibly your tax return) is audited by the IRS. See “Information Returns and Audit Procedures.”
Moreover, if we were to participate in a reportable transaction with a significant purpose to avoid or evade tax, or in any listed transaction, you may be subject to the following provisions of the American Jobs Creation Act of 2004:
| • | accuracy-related penalties with a broader scope, significantly narrower exceptions and potentially greater amounts than described below at “Accuracy-related Penalties,” |
| • | for those persons otherwise entitled to deduct interest on federal tax deficiencies, nondeductibility of interest on any resulting tax liability, and |
| • | in the case of a listed transaction, an extended statute of limitations. |
We do not expect to engage in any “reportable transactions.”
Accuracy-related Penalties. An additional tax equal to 20% of the amount of any portion of an underpayment of tax that is attributable to one or more specified causes, including negligence or disregard of rules or regulations, substantial understatements of income tax and substantial valuation misstatements, is imposed by the Internal Revenue Code. No penalty will be imposed, however, for portion of an underpayment if it is shown that there was a reasonable cause for that portion and that the taxpayer acted in good faith regarding that portion.
A substantial understatement of income tax in any taxable year exists if the amount of the understatement exceeds the greater of 10% of the tax required to be shown on the return for the taxable year or $5,000 ($10,000 for most corporations). The amount of any understatement subject to penalty generally is reduced if any portion is attributable to a position adopted on the return:
| • | for which there is, or was, “substantial authority” or |
| • | as to which there is a reasonable basis and the pertinent facts of that position are disclosed on the return. |
If any item of income, gain, loss or deduction allocated to unitholders might result in that kind of an “understatement” of income for which no “substantial authority” exists, we must disclose the pertinent facts on our return. In addition, we will make a reasonable effort to furnish sufficient information for unitholders to make adequate disclosure on their returns to avoid liability for this penalty. More stringent rules apply to “tax shelters,” a term that in this context does not appear to include us.
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A substantial valuation misstatement exists if the value of any property, or the adjusted basis of any property, claimed on a tax return is 200% or more of the amount determined to be the correct amount of the valuation or adjusted basis. No penalty is imposed unless the portion of the underpayment attributable to a substantial valuation misstatement exceeds $5,000. If the valuation claimed on a return is 400% or more than the current valuation, the penalty imposed increases to 40%.
Registration as a Tax Shelter. We registered as a “tax shelter” under the law in effect at the time of our initial public offering and were assigned tax shelter registration number 99344000008. Issuance of a tax shelter registration number to us does not indicate that investment in us or the claimed tax benefits have been reviewed, examined or approved by the IRS. The American Jobs Creation Act of 2004 repealed the tax shelter registration rules and replaced them with a new reporting regime. However, IRS Form 8271, as revised after the American Jobs Creation Act, nevertheless requires a unitholder to continue to report our tax shelter registration number on the unitholder’s tax return for any year in which the unitholder claims any deduction, loss or other benefit, or reports any income, with respect to our common units. The IRS also appears to take the position that a unitholder who sells or transfers our common units after the American Jobs Creation Act must continue to provide our tax shelter registration number to the transferee. Unitholders are urged to consult their tax advisors regarding the application of the tax shelter registration rules.
State, Local and Other Tax Considerations
In addition to federal income taxes, you will be subject to other taxes, including state and local income taxes, unincorporated business taxes, and estate, inheritance or intangible taxes that may be imposed by the various jurisdictions in which we do business or own property. Although an analysis of those various taxes is not presented here, each prospective unitholder should consider their potential impact on his or her investment in us. We currently own property or do business in Arkansas, Kansas, Missouri, Ohio, Oklahoma, Texas, Pennsylvania and New York. Each of these states, except Texas, currently imposes a personal income tax. We may also own property or do business in other states in the future. A unitholder will be required to file state income tax returns and to pay state income taxes in some or all of these states in which we do business or own property and may be subject to penalties for failure to comply with those requirements. In some states, tax losses may not produce a tax benefit in the year incurred and also may not be available to offset income in subsequent taxable years. Some of the states may require us, or we may elect, to withhold a percentage of income from amounts to be distributed to a unitholder who is not a resident of the state. Withholding, the amount of which may be greater or less than a particular unitholder’s income tax liability to the state, generally does not relieve a nonresident unitholder from the obligation to file an income tax return. Amounts withheld may be treated as if distributed to unitholders for purposes of determining the amounts distributed by us. See “—Tax Consequences of Ownership—Entity-Level Collections.” Based on current law and our anticipated future operations, our general partner anticipates that any amounts required to be withheld will not be material.
It is the responsibility of each unitholder to investigate the legal and tax consequences, under the laws of pertinent states and localities, of his or her investment in us. Accordingly, each prospective unitholder should consult, and must depend upon, his or her own tax counsel or other
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advisor with regard to those matters. Further, it is the responsibility of each unitholder to file all state and local, as well as United States federal tax returns that may be required of him or her. Ledgewood has not rendered an opinion on the state or local tax consequences of an investment in us.
Investment by Employee Benefit Plans
An investment in us by an employee benefit plan is subject to additional considerations because the investments of these plans are subject to the fiduciary responsibility and prohibited transaction provisions of ERISA and restrictions imposed by Section 4975 of the Internal Revenue Code. For these purposes the term “employee benefit plan” includes, but is not limited to, qualified pension, profit-sharing and stock bonus plans, Keogh plans, simplified employee pension plans and tax deferred annuities or IRAs established or maintained by an employer or employee organization. Among other things, consideration should be given to:
| • | whether the investment is prudent under Section 404(a)(1)(B) of ERISA; |
| • | whether, in making the investment, the plan will satisfy the diversification requirements of Section 404(a)(1)(C) of ERISA; and |
| • | whether the investment will result in recognition of unrelated business taxable income by the plan and, if so, the potential after-tax investment return. |
The person with investment discretion with respect to the assets of an employee benefit plan, often called a fiduciary, should determine whether an investment in us is authorized by the appropriate governing instrument and is a proper investment for the plan.
Section 406 of ERISA and Section 4975 of the Internal Revenue Code prohibit employee benefit plans, and also IRAs that are not considered part of an employee benefit plan, from engaging in specified transactions involving “plan assets” with parties that are “parties in interest” under ERISA or “disqualified persons” under the Internal Revenue Code with respect to the plan.
In addition to considering whether the purchase of common units is a prohibited transaction, a fiduciary of an employee benefit plan should consider whether the plan will, by investing in us, be deemed to own an undivided interest in our assets, with the result that our general partner also would be a fiduciary of the plan and our operations would be subject to the regulatory restrictions of ERISA, including its prohibited transaction rules, as well as the prohibited transaction rules of the Internal Revenue Code.
The Department of Labor regulations provide guidance with respect to whether the assets of an entity in which employee benefit plans acquire equity interests would be deemed “plan assets” under some circumstances. Under these regulations, an entity’s assets would not be considered to be “plan assets” if, among other things,
| • | the equity interests acquired by employee benefit plans are publicly offered securities, i.e., the equity interests are widely held by 100 or more investors independent of the issuer and each other, freely transferable and registered under some provisions of the federal securities laws; |
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| • | the entity is an “operating company,” i.e., it is primarily engaged in the production or sale of a product or service other than the investment of capital either directly or through a majority-owned subsidiary or subsidiaries; or |
| • | there is no significant investment by benefit plan investors, which is defined to mean that less than 25% of the value of each class of equity interest, disregarding some interests held by our general partner, its affiliates, and some other persons, is held by the employee benefit plans referred to above, IRAs and other employee benefit plans not subject to ERISA, including governmental plans. |
Our assets should not be considered “plan assets” under these regulations because we satisfy the first requirement above.
Plan fiduciaries contemplating a purchase of common units should consult with their own counsel regarding the consequences under ERISA and the Internal Revenue Code in light of the serious penalties imposed on persons who engage in prohibited transactions or other violations.
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We are registering the resale from time to time of the common units offered by this prospectus in accordance with the terms of a registration rights agreement and employment agreements with the selling unitholders. The registration of these units, however, does not necessarily mean that any of the units will be offered or sold by the selling unitholders or their respective donees, pledgees or other transferees or successors in interest. We will not receive any proceeds from the sale of the common units offered by this prospectus.
Subject to certain restrictions on transfer that may be applicable to the selling unitholders, they may sell the common units described in this prospectus and any prospectus supplement to one or more underwriters for public offering and sale, or they may sell the common units to investors directly or through dealers or agents.
The selling unitholders may act independently of us in making decisions with respect to the timing, manner and size of each of their sales. The selling unitholders may make sales on the New York Stock Exchange or otherwise, at prices and under terms prevailing at the time of the sale, or at prices related to the then-current market price, at fixed prices, or in privately negotiated transactions. The selling unitholders may sell the common units offered by this prospectus by one or more of, or a combination of, the following methods:
| • | purchases by a broker-dealer as principal and resales by such broker-dealer for its own account pursuant to this prospectus; |
| • | ordinary brokerage transactions and transactions in which the broker solicits purchasers; |
| • | block trades in which the broker-dealer so engaged will attempt to sell the common units as agent, but may position and resell a portion of the block as principal to facilitate the transaction; or |
| • | privately negotiated transactions, which include direct sales to purchasers and sales effected through agents. |
In effecting sales, broker-dealers engaged by the selling unitholders may arrange for other broker-dealers to participate. Broker-dealers may receive compensation from the selling unitholders in the form of commissions, discounts or concessions. Broker-dealers may also receive compensation from purchasers of the common units for whom they act as agents or to whom they sell as principals or both. Compensation as to a particular broker-dealer may be in excess of customary commissions and will be in amounts to be negotiated.
The distribution of the common units also may be effected from time to time in one or more underwritten transactions. Any underwritten offering may be on a “best efforts” or a “firm commitment” basis. In connection with any underwritten offering, underwriters or agents may receive compensation in the form of discounts, concessions or commissions from the selling unitholders or from purchasers of the units. Underwriters may sell the common units to or through dealers, and dealers may receive compensation in the form of discounts, concessions or commissions from the underwriters and/or commissions from the purchasers for whom they may act as agents.
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Any underwriting compensation paid by any selling unitholder to underwriters or agents in connection with the offering of these common units, and any discounts, concessions or commissions allowed by underwriters to participating dealers, will be set forth in the applicable prospectus supplement. Underwriters, dealers and agents participating in the distribution of these common units may be deemed to be underwriters, and any discounts and commissions received by them and any profit realized by them on resale of these common units may be deemed to be underwriting discounts and commissions under the Securities Act. Any underwriter, dealer or agent involved in the offer and sale of these common units will be named in the applicable prospectus supplement.
In addition, any securities registered and offered pursuant to this prospectus which qualify for sale pursuant to Rule 144 of the Securities Act may be sold under Rule 144 rather than pursuant to this prospectus.
The selling unitholders may be required by the securities laws of some states to offer and sell the common units only through registered or licensed brokers or dealers.
We have agreed to pay all expenses incident to the offering and sale of the common units offered by this prospectus, other than commissions, discounts and fees of underwriters, broker-dealers or agents. We have agreed to indemnify the selling unitholders against certain liabilities to which they may become subject in connection with the sale of the common units registered under this prospectus, including liabilities arising under the Securities Act.
If a prospectus supplement so indicates, the selling unitholders may authorize agents, underwriters or dealers to solicit offers by institutional investors to purchase the common units to which such prospectus supplement relates, providing for payment and delivery on a future date specified in such prospectus supplement. There may be limitations on the minimum amount that may be purchased by any institutional investor or on the number of common units that may be sold pursuant to such arrangements. Institutional investors include commercial and savings banks, insurance companies, pension funds, investment companies, educational and charitable institutions and such other institutions as we may approve.
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The validity of the common units and tax matters will be passed upon for us by Ledgewood, Philadelphia, Pennsylvania.
The consolidated financial statements of Atlas Pipeline Partners, L.P. as of December 31, 2006 and 2005 and for each of the three years in the period ended December 31, 2006 and management’s assessment of the effectiveness of internal control over financial reporting, incorporated in this prospectus by reference, have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their reports with respect thereto, and are included herein in reliance upon the authority of said firm as experts in giving such reports.
The combined statements of assets acquired and liabilities assumed as of December 31, 2006 and the related statements of revenues and direct operating expenses of the Anadarko Chaney Dell System and Anadarko Midkiff/Benedum System, for each of the years in the three-year period ended December 31, 2006, have been incorporated by reference herein in reliance upon the reports of KPMG LLP, independent registered public accounting firm, incorporated by reference herein, and upon the authority of said firm as experts in accounting and auditing. These combined statements were prepared for the purpose of complying with the rules and regulations of the SEC as described in note 1 and are not intended to be complete presentations of assets, liabilities, revenues, and expenses of the Anadarko Chaney Dell System and Anadarko Midkiff/Benedum System.
WHERE YOU CAN FIND MORE INFORMATION
We have filed with the SEC a registration statement on Form S-3 with respect to this offering. This prospectus constitutes only a part of the registration statement and does not contain all of the information set forth in the registration statement, its exhibits and its schedules.
We file annual, quarterly and current reports, proxy statements and other information with the SEC. Our SEC filings are available to the public over the Internet at the SEC’s web site at http://www.sec.gov or at our website at www.atlaspipelinepartners.com. You may also read and copy any document we file at the SEC’s public reference room at 100 F. Street, N.E., Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for additional information on the public reference room.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The SEC allows us to “incorporate by reference” the information we file with it. This means that we can disclose important information to you by referring to these documents. The information incorporated by reference is an important part of this prospectus, and information that we file later with the SEC under Sections 13, 14 or 15(d) of the Securities Exchange Act of 1934 will automatically update and supersede this information.
We are incorporating by reference the following documents that we have previously filed with the SEC (other than information in such documents that is deemed not to be filed):
| • | our Annual Report on Form 10-K and Form 10-K/A for the fiscal year ended December 31, 2006; |
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| • | our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2007, June 30, 2007 and September 30, 2007; and |
| • | our Current Reports on Form 8-K or Form 8-K/A filed April 19, 2007, June 5, 2007, July 30, 2007, September 14, 2007 and October 26, 2007. |
You may request a copy of any document incorporated by reference in this prospectus without charge by writing or calling us at:
Atlas Pipeline Partners, L.P.
Westpointe Corporate Center One
1550 Coraopolis Heights Road
Moon Township, PA 15108
(412) 262-2830
Attn: Brian Begley
You should rely only on the information incorporated by reference or provided in this prospectus. We have not authorized anyone else to provide you with different information. We are not making an offer to sell these securities or soliciting an offer to buy these securities in any state where the offer or sale is not permitted. You should not assume that the information in this prospectus or the documents we have incorporated by reference is accurate as of any date other than the date on the front of those documents.
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