Copano Field Services/South Texas S3ASR Automatic shelf registration

As filed with the Securities and Exchange Commission on November 2, 2009

Registration No. 333-

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form S-3

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

COPANO ENERGY, L.L.C.*

COPANO ENERGY FINANCE CORPORATION

(Exact name of registrant as specified in its charter)


Delaware Delaware (State or other jurisdiction of incorporation or organization)		51-0411678 20-3151590 (I.R.S. Employer Identification Number)

2727 Allen Parkway, Suite 1200

Houston, Texas 77019

(713) 621-9547

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

Douglas L. Lawing

Executive Vice President, General Counsel and Secretary

2727 Allen Parkway, Suite 1200

Houston, Texas 77019

(713) 621-9547

(Name, address, including zip code, and telephone number, including area code, of agent for service)

Copy to:

Jeffery K. Malonson

Vinson & Elkins L.L.P.

1001 Fannin Street, Suite 2500

Houston, Texas 77002

(713) 758-2222

Approximate date of commencement of proposed sale to the public: From time to time after the effective date of this registration statement.

If the only securities being registered on this Form are being offered pursuant to dividend or interest reinvestment plans, please check the following box: o

If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, other than securities offered only in connection with dividend or interest reinvestment plans, check the following box: þ

If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this Form is a registration statement pursuant to General Instruction I.D. or a post-effective amendment thereto that shall become effective upon filing with the Commission pursuant to Rule 462(e) under the Securities Act, check the following box. þ

If this Form is a post-effective amendment to a registration statement filed pursuant to General Instruction I.D. filed to register additional securities or additional classes of securities pursuant to Rule 413(b) under the Securities Act, check the following box. o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” inRule 12b-2 of the Exchange Act.


Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o
		(Do not check if a smaller reporting company)

CALCULATION OF REGISTRATION FEE


	Amount to be Registered(1)
	Proposed Maximum Offering Price	Amount of
Title of Each Class of	Per Unit(1) Proposed Maximum	Registration
Securities to be Registered	Aggregate Offering Price(1)	Fee(1)
Common Units
Debt Securities(2)
Guarantees of Debt Securities(2)
Total


(1)		An indeterminate aggregate offering price or number of securities of each identified class is being registered as may be offered from time to time at indeterminate prices. Separate consideration may or may not be received for securities that are being registered that are issued in exchange for, or upon conversion or exercise of, the securities being registered hereunder. In accordance with Rules 456(b) and 457(r), the registrant is deferring payment of all of the registration fee.

(2)		If a series of debt securities is guaranteed, such series will be guaranteed by all of Copano Energy, L.L.C.’s wholly owned subsidiaries other than “minor” subsidiaries (except Copano Energy Finance Corporation) as such term is interpreted in securities regulations governing financial reporting for guarantors. Pursuant to Rule 457(n), no separate fee is payable with respect to the guarantees of the debt securities being registered.

*		Includes certain subsidiaries of Copano Energy, L.L.C. identified on the following pages that may guarantee the debt securities.

The following are co-registrants that may guarantee the debt securities:

Cantera Gas Company LLC

(Exact name of registrant as specified in its charter)


Delaware		38-3432972
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CHC LP Holdings, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1837842
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Cimmarron Gathering, LP

(Exact name of registrant as specified in its charter)


Texas		20-2901110
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CMW Energy Services, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1146666
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy/Mid-Continent, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-3009666
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy/Rocky Mountains, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1172414
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy Services GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1862371
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy Services (Texas) GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1862441
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy Services/Texas Gulf Coast, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0650321
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Energy Services/Upper Gulf Coast, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0528374
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1862487
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Agua Dulce, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0500639
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Central Gulf Coast, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0647522
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Central Gulf Coast GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863263
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Copano Bay, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0503487
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Karnes, L.P.

(Exact name of registrant as specified in its charter)


Texas		20-0959499
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Live Oak, L.P.

(Exact name of registrant as specified in its charter)


Texas		42-1532273
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/South Texas, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0503485
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Upper Gulf Coast, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0528373
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/North Texas, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1586828
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Services/Rocky Mountains, LLC

(Exact name of registrant as specified in its charter)


Delaware		26-2503299
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Field Facilities/Rocky Mountains, LLC

(Exact name of registrant as specified in its charter)


Delaware		26-4771131
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano General Partners, Inc.

(Exact name of registrant as specified in its charter)


Delaware		51-0411719
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Houston Central, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		51-0409466
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Natural Gas/Rocky Mountains, LLC

(Exact name of registrant as specified in its charter)


Delaware		11-3693993
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano NGL Services, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0647525
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano NGL Services GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863192
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano NGL Services (Markham), L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		27-0904927
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1862978
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines Group, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		51-0411715
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines (Texas) GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863012
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/Hebbronville, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0665939
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/Rocky Mountains, LLC

(Exact name of registrant as specified in its charter)


Delaware		20-0659235
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/South Texas, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0576084
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/TGC, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0650304
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/Upper Gulf Coast, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0528375
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/North Texas, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		27-1125058
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/Texas Gulf Coast, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-3154210
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Pipelines/Victoria, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-4316438
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Processing, L.P.

(Exact name of registrant as specified in its charter)


Texas		76-0647499
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Processing GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863221
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Processing/Louisiana, LLC

(Exact name of registrant as specified in its charter)


Oklahoma		73-1493880
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano Risk Management, L.P.

(Exact name of registrant as specified in its charter)


Texas		20-3183275
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano/Red River Gathering GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-8921790
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano/Red River Gathering LP Holdings, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-8921744
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano/Webb-Duval Pipeline, L.P.

(Exact name of registrant as specified in its charter)


Delaware		20-1686633
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Copano/Webb-Duval Pipeline GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1686528
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CPG LP Holdings, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863129
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CPNO Services, L.P.

(Exact name of registrant as specified in its charter)


Texas		20-2071486
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CPNO Services GP, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-2071403
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CPNO Services LP Holdings, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-2071326
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

CWDPL LP Holdings, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		20-1863161
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Greenwood Gathering, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1146730
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Estes Cove Facilities, L.L.C.

(Exact name of registrant as specified in its charter)


Texas		76-0593059
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Nueces Gathering, L.L.C.

(Exact name of registrant as specified in its charter)


Texas		81-0560211
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

ScissorTail Energy, LLC

(Exact name of registrant as specified in its charter)


Delaware		74-2964091
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

ACP Texas, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-2565296
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

Alamo Creek Properties, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1586906
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

River View Pipelines, L.L.C.

(Exact name of registrant as specified in its charter)


Delaware		26-1586872
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

PROSPECTUS

COPANO ENERGY, L.L.C.

COPANO ENERGY FINANCE CORPORATION

Common Units

Debt Securities

We may offer, from time to time, the following securities in one or more transactions, classes or series and in amounts, at prices and on terms to be determined by market conditions at the time of our offerings:


	•	common units representing limited liability company interests in Copano Energy, L.L.C.; and

	•	debt securities, which may be secured or unsecured senior debt securities or secured or unsecured subordinated debt securities.

Copano Energy Finance Corporation may act as co-issuer of the debt securities. If a series of debt securities is guaranteed, such series will be guaranteed by all of Copano Energy, L.L.C.’s wholly owned subsidiaries other than “minor” subsidiaries (except Copano Energy Finance Corporation) as such term is interpreted in securities regulations governing financial reporting for guarantors.

We may offer and sell these securities to or through one or more underwriters, dealers and agents, or directly to purchasers, on a continuous or delayed basis. This prospectus describes the general terms of these securities and the general manner in which we will offer the securities. Each time we sell securities, we will provide a prospectus supplement that will contain specific information about the terms of that offering. The prospectus supplement may also add, update or change information contained in this prospectus. This prospectus may not be used to consummate sales of securities unless accompanied by a prospectus supplement.

You should carefully read this prospectus and any prospectus supplement before you invest. You should also read the documents we have referred you to in the “Where You Can Find More Information” section of this prospectus for information on us and our financial statements.

Our common units are listed on the Nasdaq Global Select Market under the symbol “CPNO.” We will provide information in the prospectus supplement for the trading market, if any, for any debt securities we may offer.

Investing in our securities involves risks. In addition to risks related to our business, limited liability companies are inherently different from corporations. You should carefully consider the risk factors described under “Risk Factors” beginning on page 4 of this prospectus and in the applicable prospectus supplement before you make an investment in our securities.

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.

The date of this prospectus is November 2, 2009.

TABLE OF CONTENTS

This prospectus is part of a registration statement we filed with the Securities and Exchange Commission, or the “SEC” or “Commission.” In making your investment decision, you should rely only on the information contained in or incorporated by reference in this prospectus and any prospectus supplement. We have not authorized anyone to provide you with any other information. If you receive any unauthorized information, you must not rely on it. We are not making an offer to sell these securities in any jurisdiction where the offer is not permitted.

You should not assume that the information contained in this prospectus or any prospectus supplement, as well as the information that we have previously filed with the SEC that is incorporated by reference into this prospectus or any prospectus supplement, is accurate as of any date other than the date of such document. Our business, financial condition, results of operations and prospects may have changed since those dates.

ABOUT THIS PROSPECTUS

This prospectus is part of a registration statement onForm S-3 that we and Copano Energy Finance Corporation have filed with the SEC using a “shelf” registration process. Under this shelf registration process, we may from time to time offer and sell the securities described in this prospectus in one or more offerings. This prospectus describes the general terms of these securities and the general manner in which we will offer the securities. Each time we offer securities, we will provide you with this prospectus and a prospectus supplement that will describe, among other things, the specific amounts and prices of the securities being offered and the terms of the offering.

The prospectus supplement may include additional risk factors or other special considerations applicable to those securities and may also add, update or change information contained in this prospectus. If there is any inconsistency between the information in this prospectus and any prospectus supplement, you should rely on the information in that prospectus supplement.

Additional information, including our financial statements and the notes thereto, is incorporated in this prospectus by reference to our reports filed with the SEC. Please read “Where You Can Find More Information.” You are urged to carefully read this prospectus, including the “Risk Factors,” and any attached prospectus supplement relating to the securities offered to you, together with the additional information described under “Where You Can Find More Information,” before investing in our common units or debt securities.

Throughout this prospectus, when we use the terms “we,” “us,” “our,” or like terms, we are referring either to Copano Energy, L.L.C. or to Copano Energy, L.L.C. and its consolidated subsidiaries collectively, unless the context requires otherwise.

WHERE YOU CAN FIND MORE INFORMATION

We file annual, quarterly and current reports, proxy statements and other information with the SEC. You may read and copy any materials that we file with the SEC at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549. You may obtain information on the operation of the Public Reference Room by calling the SEC at1-800-SEC-0330. The SEC maintains an Internet site (http://www.sec.gov) that contains reports, proxy and information statements and other information that we file electronically with the SEC.

We also make available free of charge on our website, athttp://www.copanoenergy.com, all materials that we file electronically with the SEC, including our annual report onForm 10-K, quarterly reports onForm 10-Q, current reports onForm 8-K, Section 16 reports and amendments to these reports, as soon as reasonably practicable after such materials are electronically filed with, or furnished to, the SEC. Information on our website is not incorporated by reference into this prospectus.

We “incorporate by reference” information into this prospectus, which means that we disclose important information to you by referring you to another document filed separately with the SEC. The information incorporated by reference is deemed to be part of this prospectus, except to the extent it is updated and superseded by information contained in this prospectus. The information we file later with the SEC will automatically update and supersede information in this prospectus. You should not assume that the information in this prospectus is current as of any date other than the date on the front page of this prospectus.

We incorporate by reference the documents listed below (excluding any information furnished pursuant to Item 2.02, 7.01 or 9.01 on any Current Report onForm 8-K):


	•	Our Annual Report onForm 10-K for the year ended December 31, 2008, including information specifically incorporated by reference into ourForm 10-K from our Proxy Statement prepared in connection with the 2009 Annual Meeting of Unitholders held on March 14, 2009;

	•	Our Quarterly Report onForm 10-Q for the quarterly period ended June 30, 2009;

	•	Our Quarterly Report onForm 10-Q for the quarterly period ended March 31, 2009;

	•	Our Current Report onForm 8-K filed on October 15, 2009;


	•	Our Current Report onForm 8-K/A filed on September 15, 2009;

	•	Our Current Report onForm 8-K filed on August 27, 2009;

	•	Our Current Report onForm 8-K filed on August 21, 2009;

	•	Our Current Report onForm 8-K filed on August 17, 2009;

	•	Our Current Report onForm 8-K filed on July 16, 2009;

	•	Our Current Report onForm 8-K filed on May 18, 2009;

	•	Our Current Report onForm 8-K filed on April 16, 2009;

	•	Our Current Report onForm 8-K filed on February 24, 2009;

	•	Our Current Report onForm 8-K filed on January 15, 2009; and

	•	The description of our common units contained in our Registration Statement onForm 8-A (FileNo. 000-51009) filed with the SEC on November 1, 2004 and any subsequent amendments or reports filed for the purpose of updating such description.

All documents that we file pursuant to Sections 13(a), 13(c), 14 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”), and that are deemed “filed,” prior to the termination of all offerings under this shelf registration statement are incorporated by reference into this prospectus.

You may obtain any of the documents incorporated by reference in this prospectus from the SEC through the SEC’s web site at the address provided above. We will provide you a copy of any or all of the information that has been incorporated by reference in this prospectus (including exhibits to those documents specifically incorporated by reference in this document), at no cost, upon your written or oral request to us at the following address or telephone number:

Copano Energy, L.L.C.
Investor Relations
2727 Allen Parkway, Suite 1200
Houston, Texas 77019
(713) 621-9547

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

Certain matters discussed in this prospectus and the documents we incorporate by reference include “forward-looking” statements. Statements that are not historical facts and instead address activities, events or developments that we expect or anticipate will or may occur in the future, including things such as references to future goals or intentions, are forward-looking statements. These statements can be identified by the use of forward-looking terms such as “may,” “believe,” “expect,” “anticipate,” “estimate” or “continue,” or similar words, and include statements related to plans for growth of the business, future capital expenditures and competitive strengths and goals. We make these statements based on our past experience and our perceptions of historical trends, current conditions and expected future developments, as well as other considerations we believe are appropriate under the circumstances. Whether actual results and developments in the future will conform to our expectations is subject to numerous risks and uncertainties, many of which are beyond our control. Therefore, actual outcomes and results could differ materially from what is expressed, implied or forecast in forward-looking statements. Any differences could result from a number of factors, including:


	•	our ability to successfully integrate any acquired assets or operations;

	•	the volatility of prices and market demand for natural gas and natural gas liquids (“NGLs”);

	•	our ability to continue to obtain new sources of natural gas supply;

	•	our ability to access NGL fractionation capacity;


	•	the ability of key producers to continue to drill and successfully complete and attach new natural gas supplies;

	•	our ability to retain key customers;

	•	the availability of local, intrastate and interstate transportation systems and other facilities for natural gas and NGLs;

	•	our ability to access our revolving credit facility and to obtain additional financing on acceptable terms;

	•	the effectiveness of our hedging program;

	•	general economic conditions;

	•	the effects of government regulations and policies; and

	•	other financial, operational and legal risks and uncertainties detailed from time to time in our filings with the SEC.

This prospectus and the documents incorporated by reference include cautionary statements identifying important factors that could cause our actual results to differ materially from our expectations, including in conjunction with forward-looking statements described above. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this prospectus, any accompanying prospectus supplement and the documents we incorporate by reference. All forward-looking statements included in those documents and all subsequent written or oral forward-looking statements attributable to us are expressly qualified in their entirety by these cautionary statements. Such forward-looking statements speak only as of the date made, and we undertake no obligation to publicly update or revise any forward-looking statements, other than as required by law.

COPANO ENERGY, L.L.C.

We are an energy company engaged in the business of providing midstream services to natural gas producers, including natural gas gathering, compression, dehydration, treating, marketing, transportation, processing, conditioning and fractionation services. Our assets are located in Oklahoma, Texas, Wyoming and Louisiana and include approximately 6,200 miles of active natural gas gathering and transmission pipelines and seven natural gas processing plants, with over one billion cubic feet per day of combined processing capacity. In addition to our natural gas pipelines, we operate 200 miles of NGL pipelines.

Our operations are conducted through, and our operating assets are owned by, our subsidiaries. Copano Energy Finance Corporation, our wholly owned subsidiary, has no material assets or any liabilities other than as a co-issuer of our debt securities. Its activities are limited to co-issuing our debt securities and activities incidental to its role as a co-issuer.

Our principal executive offices are located at 2727 Allen Parkway, Suite 1200, Houston, Texas 77019. Our telephone number at our principal executive offices is(713) 621-9547.

For additional information about our business, properties and financial condition, please read “Where You Can Find More Information.”

THE SUBSIDIARY GUARANTORS

Certain of our subsidiaries, which we refer to as the “subsidiary guarantors” in this prospectus, may fully and unconditionally guarantee our payment obligations under any series of debt securities offered using this prospectus. Financial information concerning our subsidiary guarantors and any non-guarantor subsidiaries will, to the extent required by SEC rules and regulations, be included in our consolidated financial statements filed as part of our periodic reports pursuant to the Exchange Act.

RISK FACTORS

You should carefully consider the following risk factors together with all of the other information included in this prospectus, any prospectus supplement and the information that we have incorporated herein by reference in evaluating an investment in Copano Energy, L.L.C. If any of the following risks were actually to occur, our business, financial condition or results of operations could be materially adversely affected. When we offer and sell any securities pursuant to a prospectus supplement, we may include additional risk factors relevant to such securities in the prospectus supplement.

Risks Related to Our Business

We may not have sufficient cash after establishment of cash reserves to pay cash distributions at the current level.

We may not have sufficient available cash each quarter to pay distributions at the current level. Under the terms of our limited liability company agreement, we must set aside any cash reserve amounts before making a distribution to our unitholders. The amount of cash we can distribute principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:


	•	the amount of natural gas gathered and transported on our pipelines;

	•	the amount and NGL content of the natural gas we process;

	•	the fees we charge and the margins we realize for our services;

	•	the prices of natural gas, NGLs and crude oil;

	•	the relationship between natural gas and NGL prices;

	•	the level of our operating costs and the impact of inflation on those costs; and

	•	the weather in our operating areas.

In addition, the actual amount of cash we will have available for distribution will depend on other factors, some of which are beyond our control, including:


	•	the level of capital expenditures we make and the profitability of those projects;

	•	our ability to access capital markets and borrow money;

	•	the cost of acquisitions, if any;

	•	the effectiveness of our hedging program and the creditworthiness of our hedging counterparties;

	•	our debt service requirements;

	•	fluctuations in our working capital needs;

	•	restrictions on distributions imposed by our revolving credit facility and the indentures governing our senior unsecured notes;

	•	any restrictions on distributions by entities in which we own interests;

	•	the amount of cash reserves established by our Board of Directors for the proper conduct of our business; and

	•	prevailing economic conditions.

If we decrease distributions, the market price for our units may be adversely affected.

A decrease in our cash flow will reduce the amount of cash we have available for distribution to our unitholders.

The amount of cash we have available for distribution depends primarily upon our cash flow, including cash flow from financial reserves, and is not solely a function of profitability, which will be affected by non-cash items.

As a result, we may make cash distributions during periods when we record losses and may not make cash distributions during periods when we record net income.

To the extent that we make acquisitions in the future and our acquisitions do not perform as expected, our future financial performance may be negatively impacted.

Our business strategy includes making acquisitions that we anticipate would increase the cash available for distribution to our unitholders. As a result, from time to time, we evaluate and pursue assets and businesses that we believe complement our existing operations or expand our operations into new regions where our growth strategy can be applied. We cannot assure you that we will be able to complete acquisitions in the future or achieve the desired results from any acquisitions we do complete. In addition, failure to successfully assimilate our acquisitions could adversely affect our financial condition and results of operations.

Our acquisitions potentially involve numerous risks, including:


	•	operating a significantly larger combined organization and adding operations;

	•	difficulties in the assimilation of the assets and operations of the acquired businesses, especially if the assets acquired are in a new business segment or geographic area;

	•	the risk that natural gas reserves expected to support the acquired assets may not be of the anticipated magnitude or may not be developed as anticipated;

	•	the loss of significant producers or markets or key employees from the acquired businesses;

	•	the diversion of management’s attention from other business concerns;

	•	the failure to realize expected profitability or growth;

	•	the failure to realize any expected synergies and cost savings;

	•	coordinating geographically disparate organizations, systems and facilities;

	•	coordinating or consolidating corporate, information technology and administrative functions; and

	•	a decrease in liquidity and increased leverage as a result of using significant amounts of available cash or debt to finance an acquisition.

Further, unexpected costs and challenges may arise whenever businesses with different operations or management are combined, and we may experience unanticipated delays in realizing the benefits of an acquisition. Because of these risks and challenges, even when we make acquisitions that we believe will increase our ability to distribute cash, those acquisitions may nevertheless reduce our cash from operations on a per unit basis. This could result in lower distributions to our common unitholders and could impair our ability to comply with financial covenants under our debt agreements. Our capitalization and results of operations may change significantly following an acquisition, and you may not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in evaluating future acquisitions.

Our acquisitions could expose us to potential significant liabilities.

We generally assume the liabilities of entities that we acquire and may assume certain liabilities relating to assets that we acquire, including unknown and contingent liabilities. We perform due diligence in connection with our acquisitions and attempt to verify the representations of the sellers, but there may be pending, threatened, contemplated or contingent claims related to environmental, title, regulatory, litigation or other matters of which we are unaware. We may have indemnification claims against sellers for certain of these liabilities, as well as for disclosed liabilities, but our indemnification rights generally will be limited in amount and duration. Our right to indemnification also will be limited, as a practical matter, to the creditworthiness of the indemnifying party. If our right to indemnification is inadequate to cover the obligations of an acquired entity or relating to acquired assets, or if our indemnifying seller is unable to meet its obligations to us, our liability for such obligations could materially adversely affect our cash flow, operations and financial condition.

We may not be able to fully execute our business strategy if we encounter illiquid capital markets.

Our business strategy contemplates pursuing acquisitions and capital projects, both in our existing areas of operations and in new regions where we believe growth opportunities are attractive and our business strategies could be applied. We regularly consider and enter into discussions regarding strategic transactions or projects that we believe will present opportunities to pursue our growth strategy.

We will require substantial new capital to finance strategic acquisitions or to complete significant organic expansion or greenfield projects. Any limitations on our access to capital will impair our ability to execute our growth strategy. If the cost of capital becomes too expensive, our ability to develop or acquire accretive assets will be limited. We may not be able to raise the necessary funds on satisfactory terms, if at all. The primary factors that influence our cost of capital include market conditions and offering or borrowing costs such as interest rates or underwriting discounts.

Illiquid capital markets could also limit investment and development by third parties, such as producers and end-users, which could indirectly affect our ability to fully execute our business strategy.

Our substantial indebtedness could limit our operating flexibility and impair our ability to fulfill our debt obligations.

We have substantial indebtedness. As of June 30, 2009 and in addition to liabilities we incurred related to our risk management activities, we had total indebtedness of $852 million, including our senior unsecured notes and our revolving credit facility.

At June 30, 2009, available borrowing capacity under our revolving credit facility was approximately $280 million. Subject to the restrictions governing our existing indebtedness and other financial obligations, we may incur significant additional indebtedness and other financial obligations in the future. Our substantial indebtedness and other financial obligations could have important consequences to you. For example, it could:


	•	make it more difficult for us to satisfy our obligations with respect to our indebtedness;

	•	impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, general company purposes or other purposes;

	•	result in higher interest expense in the event of increases in interest rates to the extent that any of our debt is subject to variable rates of interest;

	•	have a material adverse effect on us if we fail to comply with financial and restrictive covenants in our debt agreements and an event of default occurs as a result of that failure that is not cured or waived;

	•	require us to dedicate a substantial portion of our cash flow to payments on our indebtedness and other financial obligations, thereby reducing the availability of our cash flow to fund working capital, capital expenditures and other general company requirements;

	•	limit our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate; and

	•	place us at a disadvantage relative to any competitors that have proportionately less debt.

If we are unable to meet our debt service obligations and other financial obligations, we could be forced to restructure or refinance our indebtedness, in which case our lenders could require us to suspend cash distributions, or seek additional equity capital or sell assets. We may be unable to obtain such refinancing or equity capital, or to sell assets on satisfactory terms, if at all.

Restrictive covenants in the agreements governing our indebtedness may reduce our operating flexibility.

The indenture governing our outstanding senior unsecured notes contains various covenants that limit our ability and the ability of specified subsidiaries to, among other things:


	•	sell assets;


	•	pay distributions on, redeem or repurchase our equity interests or redeem or repurchase our subordinated debt, if any;

	•	make investments;

	•	incur or guarantee additional indebtedness or issue preferred units;

	•	create or incur certain liens;

	•	enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us;

	•	consolidate, merge or transfer all or substantially all of our assets;

	•	engage in transactions with affiliates;

	•	create unrestricted subsidiaries; and

	•	enter into sale and leaseback transactions.

Our revolving credit facility contains similar covenants, as well as covenants that require us to maintain specified financial ratios and satisfy other financial conditions. The restrictive covenants in our indentures and our revolving credit facility could limit our ability and the ability of our subsidiaries to obtain future financings, make needed capital expenditures, withstand a future downturn in our business or the economy in general or conduct operations.

If we are unable to comply with our debt covenants, it could result in defaults under the terms of our indentures or our revolving credit facility and acceleration of our debt and other financial obligations. If we were unable to repay those obligations, our lenders could initiate a bankruptcy proceeding or liquidation proceeding or proceed against any collateral.

In addition, Fort Union Gas Gathering, L.L.C. (“Fort Union”), in which we own a 37.04% interest, has debt outstanding under an agreement that includes, among other customary covenants and events of default, a limitation on its ability to make cash distributions. Fort Union can distribute cash to its members only if its ratio of net operating cash flow to debt service is not less than 1.25 to 1.00. If Fort Union fails to comply with this covenant, it would be prohibited from distributing cash to us, which would adversely affect our cash flow.

Our ability to obtain funding under our revolving credit facility could be impaired by conditions in the financial markets.

We operate in a capital-intensive industry and rely on our revolving credit facility to finance a significant portion of our capital expenditures. Our ability to borrow under our revolving credit facility is subject to conditions in the financial markets, including the solvency of institutional lenders. Specifically, we would be unable to obtain adequate funding under our revolving credit facility if:


	•	one or more of our lenders failed to meet its funding obligations;

	•	at the time we draw on our revolving credit facility, any of the representations or warranties or certain covenants included in the agreement is false in any material respect and the lenders elected to refuse to provide funding; and

	•	any lender refuses to fund its commitment for any reason, whether or not valid, and the other lenders elect not to provide additional funding to make up for the unfunded portion.

If we are unable to access funds under our revolving credit facility, we would need to meet our capital requirements using other sources. Depending on economic conditions, alternative sources of liquidity may not be available on acceptable terms. If the cash generated from our operations or the funds we are able to obtain under our revolving credit facility or other sources of liquidity are not sufficient to meet our capital requirements, then we may need to delay or abandon capital projects or other business opportunities, which could have a material adverse effect on our results of operations and financial condition.

Our ability to obtain financing from sources other than our revolving credit facility is subject to conditions in the credit and capital markets.

If we need to raise capital from a source other than our revolving credit facility, we cannot be certain that additional capital will be available to the extent required and on acceptable terms. Global market and economic conditions have been volatile, and the timing of an economic recovery remains uncertain. The availability and cost of debt and equity capital are subject to general economic conditions and prevailing perceptions about the stability of financial markets and the solvency of counterparties. Adverse changes in these factors are likely to result in higher interest rates and deterioration in the availability and cost of debt and equity financing.

If capital on acceptable terms is unavailable to us, we may be unable to fully execute our growth strategy, otherwise take advantage of business opportunities, or respond to competitive pressures, any of which could have a material adverse effect on our results of operations and financial condition.

We are exposed to the credit risk of our customers and other counterparties, and a general increase in the nonpayment and nonperformance by counterparties could adversely affect our cash flows, results of operations and financial condition.

Risks of nonpayment and nonperformance by our counterparties are a major concern in our business. We are subject to risks of loss resulting from nonpayment or nonperformance by our customers and other counterparties, such as our lenders and hedging counterparties. Many of our customers finance their activities through cash flow from operations, the incurrence of debt or the issuance of equity, all of which are subject to adverse changes in commodity prices and economic and market conditions. Since the most recent economic downturn, some of our customers have experienced a combination of lower cash flow due to commodity prices, reduced borrowing bases under reserve-based credit facilities and reduced availability of debt or equity financing. These factors may result in a significant reduction in our customers’ liquidity and ability to pay or otherwise perform on their obligations to us. Furthermore, some of our customers may be highly leveraged and subject to their own credit, operating and regulatory risks, which increases the risk that they may default on their obligations to us.

Any increase in nonpayment and nonperformance by our counterparties, either as a result of financial and economic conditions or otherwise, could have an adverse impact on our operating results and could adversely affect our liquidity.

Our cash flow and profitability depend upon prices and market demand for natural gas and NGLs, which are beyond our control and have been volatile.

Our cash flow and profitability are affected by prevailing NGL and natural gas prices, and we are subject to significant risks due to fluctuations in commodity prices. In the past, the prices of natural gas and NGLs have been extremely volatile, and we expect this volatility to continue. For example, during the nine months ended September 30, 2009, the Houston Ship Channel natural gas index price ranged from a high of $5.26 per MMBtu to a low of $2.69 per MMBtu. Based on average monthly Mt. Belvieu prices and our weighted-average product production mix in Texas during this period, NGL prices ranged from a high of approximately $36.72 per barrel to a low of approximately $25.46 per barrel.

We derive a majority of our gross margin from contracts with terms that are commodity price sensitive. As a result, our cash flow and profitability depend to a significant extent on the prices at which we buy and sell natural gas and at which we sell NGLs and condensate. The markets and prices for natural gas and NGLs depend upon many factors beyond our control. These factors include supply and demand for oil, natural gas, liquefied natural gas (“LNG”), nuclear energy, coal and NGLs, which fluctuate with changes in market and economic conditions and other factors, including:


	•	the impact of weather on the demand for oil and natural gas;

	•	the level of domestic oil and natural gas production;

	•	storage levels for oil, natural gas, LNG and NGLs;

	•	the availability of imported oil, natural gas, LNG and NGLs;


	•	international demand for LNG, oil and NGLs;

	•	actions taken by foreign oil and gas producing nations;

	•	the availability of local, intrastate and interstate transportation systems for natural gas and NGLs;

	•	the availability of downstream NGL fractionation facilities;

	•	the availability and marketing of competitive fuels;

	•	the impact of energy conservation efforts; and

	•	the extent of governmental regulation and taxation.

Changes in commodity prices may also indirectly impact our profitability by influencing drilling activity and well operations, and thus the volume of natural gas we gather and process. This volatility may cause our gross margin and cash flows to vary widely from period to period. Our hedging strategies cannot offset volume risk and may not be sufficient to offset price volatility risk. In any event, our commodity derivatives do not cover all of our throughput volumes. Moreover, commodity derivatives are subject to inherent risks, which we describe below under “— Our hedging activities do not eliminate our exposure to fluctuations in commodity prices and interest rates and may reduce our cash flow and subject our earnings to increased volatility.”

Our hedging activities do not eliminate our exposure to fluctuations in commodity prices and interest rates and may reduce our cash flow and subject our earnings to increased volatility.

Our operations expose us to fluctuations in commodity prices, and our revolving credit facility exposes us to fluctuations in interest rates. We use derivative financial instruments to reduce our sensitivity to commodity prices and interest rates, and the degree of our exposure is related largely to the effectiveness and scope of our hedging activities. We have hedged only portions of our variable-rate debt and expected natural gas and condensate supply, NGL production and natural gas requirements. We continue to have direct interest rate and commodity price risk with respect to the unhedged portions.

Our ability to enter into new derivative instruments is subject to general economic and market conditions. The markets for instruments we use to hedge our commodity price and interest rate exposure generally reflect conditions in the underlying commodity and debt markets, and to the extent conditions in underlying markets are unfavorable, our ability to enter into new derivative instruments on acceptable terms will be limited. In addition, to the extent we hedge our commodity price and interest rate risks using swap instruments, we will forego the benefits of favorable changes in commodity prices or interest rates.

Even though monitored by management, our hedging activities may fail to protect us and could reduce our cash flow and profitability. Our hedging activity may be ineffective or adversely affect cash flow and earnings because, among other factors:


	•	hedging can be expensive, particularly during periods of volatile prices;

	•	our counterparty in the hedging transaction may default on its obligation to pay; and

	•	available hedges may not correspond directly with the risks against which we seek protection. For example:


	•	the duration of a hedge may not match the duration of the risk against which we seek protection;

	•	variations in the index we use to price a commodity hedge may not adequately correlate with variations in the index we use to sell the physical commodity (known as basis risk); and

	•	we may not produce or process sufficient volumes to cover swap arrangements we enter into for a given period. If our actual volumes are lower than the volumes we estimated when entering into a swap for the period, we might be forced to satisfy all or a portion of our derivative obligation without the benefit of cash flow from our sale or purchase of the underlying physical commodity, which could adversely affect our liquidity.

Our financial statements may reflect gains or losses arising from exposure to commodity prices or interest rates for which we are unable to enter into fully economically effective hedges. In addition, the standards for cash flow hedge accounting are rigorous. Even when we engage in hedging transactions that are effective economically, these transactions may not be considered effective cash flow hedges for accounting purposes. Our earnings could be subject to increased volatility to the extent our derivatives do not continue to qualify as cash flow hedges, and, if we assume derivatives as part of an acquisition, to the extent we cannot obtain or choose not to seek cash flow hedge accounting for the derivatives we assume.

The adoption of derivatives legislation by Congress could have an adverse impact on our ability to hedge risks associated with our business.

Congress is currently considering legislation to impose restrictions on certain transactions involving derivatives, which could affect the use of derivatives in hedging transactions. ACESA (defined below) contains provisions that would prohibit private energy commodity derivative and hedging transactions. ACESA would expand the power of the Commodity Futures Trading Commission, or “CFTC,” to regulate derivative transactions related to energy commodities, including oil and natural gas, and to mandate clearance of such derivative contracts through registered derivative clearing organizations. Under ACESA, the CFTC’s expanded authority over energy derivatives would terminate upon the adoption of general legislation covering derivative regulatory reform. The Chairman of the CFTC urged Congress to set limits on trading and positions in commodities with finite supply, particularly energy commodities, such as crude oil, natural gas and other energy products, and to bring the entire over-the-counter (“OTC”) derivatives marketplace under CFTC regulation. The CFTC also is evaluating whether position limits should be applied consistently across all markets and participants. In addition, the Treasury Department has proposed legislation to subject all OTC derivative dealers and all other major OTC derivative market participants to substantial supervision and regulation, including by imposing conservative capital and margin requirements and strong business conduct standards. Derivative contracts that are not cleared through central clearinghouses and exchanges may be subject to substantially higher capital and margin requirements. A recent house bill would give the CFTC power to set position limits and to regulate commodity swaps. Although it is not possible at this time to predict whether or when Congress may act on this or other derivatives legislation or how any climate change bill approved by the U.S. Senate would be reconciled with ACESA, any laws or regulations that may be adopted that subject us to additional capital or margin requirements relating to, or to additional restrictions on, our trading and commodity positions could have an adverse effect on our flexibility in hedging risks associated with our business or on the cost of our hedging activity.

Because of the natural decline in production from existing wells in our operating regions, our future success depends on our ability to continually obtain new sources of natural gas supply, which depends in part on certain factors beyond our control. Any decrease in supplies of natural gas could adversely affect our revenues and operating income.

Our gathering and transmission pipeline systems are connected to natural gas fields and wells, from which the production will naturally decline over time, which means that our cash flows associated with these wells will also decline over time. To maintain or increase throughput volumes on our pipeline systems and at our processing plants, we must continually connect new supplies of natural gas and attract new customers to our gathering and transmission lines. The primary factors affecting our ability to do so include the level of successful drilling activity near our gathering systems and our ability to compete for the attachment of such additional volumes to our systems.

Fluctuations in energy prices can greatly affect drilling and production rates and investments by third parties in the development of new natural gas reserves. Drilling activity generally decreases as natural gas prices decrease. We have no control over the level of drilling activity in the areas of our operations, the amount of reserves underlying the wells or the rate at which production from a well will decline. In addition, we have no control over producers or their drilling and production decisions, which are affected by, among other things, prevailing and projected energy prices, drilling costs, rig availability, demand for hydrocarbons, the level of reserves, geological considerations, governmental regulations and the availability and cost of capital.

The current pricing environment, particularly in combination with the constrained capital and credit markets and overall economic downturn, has resulted in a decline in drilling activity by some producers in each of our segments. Lower drilling levels over a sustained period would have a negative effect on the volumes of natural gas we gather and process. We cannot use hedging to offset the potential effects of declining volumes.

We face strong competition in acquiring new natural gas supplies. Competitors to our pipeline operations include major interstate and intrastate pipelines, and other natural gas gatherers. Competition for natural gas supplies is primarily based on the location of pipeline facilities, pricing arrangements, reputation, efficiency, flexibility and reliability. Our major competitors for natural gas supplies and markets in our Texas segment include Enterprise Products Partners, Lobo Pipeline Company, Kinder Morgan Texas Pipeline, or KMTP, DCP Midstream, Crosstex Energy, ExxonMobil, Houston Pipeline Company, Targa Resources, Atlas Pipeline and Devon Energy. The primary competitors in our Oklahoma segment include CenterPoint Field Services, DCP Midstream, ONEOK Field Services, Enogex, Enerfin, Hiland Partners and MarkWest. The primary competitors in our Rocky Mountains segment include Thunder Creek Gas Gathering, Bitter Creek Pipeline Company, Bear Paw Energy and Western Gas Resources. A number of our competitors are larger organizations than we are.

If we are unable to maintain or increase the throughput on our pipeline systems because of decreased drilling activity, decreased production from the wells connected to our systems or inability to connect new supplies of gas and attract new customers to our gathering and transmission lines, then our business, financial results and our ability to achieve our growth strategy could be materially adversely affected.

We rely on third-party pipelines and other facilities in providing service to our customers. If one or more of these pipelines or facilities were to become capacity- constrained or unavailable, our cash flows, results of operations and financial condition could be adversely affected.

Our ability to contract for natural gas supplies in the Texas region will often depend on our ability to deliver gas to our Houston Central plant and downstream markets, and we rely on KMTP’s Laredo-to-Katy pipeline to transport natural gas from our South Texas systems to the Houston Central plant. For the six months ended June 30, 2009, approximately 46% of the total natural gas delivered by our Texas segment was delivered to KMTP, and approximately 80% of the natural gas volumes processed or conditioned at our Houston Central plant was delivered to the plant through the KMTP Laredo-to-Katy pipeline.

If KMTP’s pipeline were to become unavailable for any reason, the volumes transported to our Houston Central plant would be reduced substantially, and our revenues and operating income from our Texas processing business would be adversely affected. In addition, much of the natural gas we gather in South Texas contains NGLs that must be removed in order to meet downstream market quality specifications. If we were unable to ship such natural gas to our Houston Central plant, we would need to arrange for an alternate means of removing NGLs and transport through other pipelines. Alternatively, we might be required to lease smaller treating and processing facilities so that we could treat and condition or process natural gas as needed to meet pipeline quality specifications.

We rely on ONEOK Hydrocarbon to take delivery of NGLs from several of our processing plants. We believe that fractionation facilities to which ONEOK Hydrocarbon delivers NGLs, as well as other fractionation facilities on which we depend, are subject to increasing capacity constraints due to higher NGL production in the Rocky Mountains and Mid-Continent regions. If ONEOK Hydrocarbon or the related downstream fractionation facilities were to become unavailable, we would have to run the affected plants in a reduced operating mode and make arrangements to re-route a portion of the natural gas we receive for processing to third-party plants, as well as make arrangements to transport NGLs to market by truck.

We also depend on other third-party processing plants, pipelines and other facilities to provide our customers with processing, delivery or transportation options. Like us, third-party service providers are subject to risks inherent in the midstream business, including capacity constraints, and natural disasters and operational, mechanical or other hazards. Because we do not own or operate KMTP’s, ONEOK Hydrocarbon’s, or any of these other pipelines and facilities, their continuing operation is not within our control.

If any of these pipelines and other facilities becomes unavailable or limited in its ability to provide services on which we depend, our revenues and cash flow could be adversely affected. We would likely incur higher fees or other costs in arranging for alternatives, and a prolonged interruption or reduction of service on KMTP or ONEOK could hinder our ability to contract for additional gas supplies.

We generally do not obtain reservoir engineering reports evaluating reserves dedicated to our pipeline systems; therefore, volumes of natural gas transported on our pipeline systems in the future could be less than we anticipate, which may cause our revenues and operating income to be less than we expect.

We generally do not obtain reservoir engineering reports evaluating natural gas reserves connected to our pipeline systems due to the unwillingness of producers to provide reserve information as well as the cost of such evaluations. Accordingly, we do not have estimates of total reserves dedicated to our systems or the anticipated life of such reserves. If the total reserves or estimated life of the reserves connected to our pipeline systems is less than we anticipate and we are unable to secure additional sources of natural gas, then the volumes of natural gas transported on our pipelines in the future could be less than we anticipate. A decline in the volumes of natural gas transported on our pipeline systems may cause our revenues to be less than we expect, which could have a material adverse effect on our business, financial condition and our ability to make cash distributions to you.

Federal, state or local regulatory measures could adversely affect our business.

Our pipeline transportation and gathering systems are subject to federal, state and local regulation. Most of our natural gas pipelines are gathering systems that are considered non-utilities in the states in which they are located. The Natural Gas Act (“NGA”) leaves any economic regulation of natural gas gathering to the states. Texas, Oklahoma and Wyoming, the states in which our pipeline facilities are located, do not currently regulate non-utility gathering fees.

Our gathering fees and our terms and conditions of service may nonetheless be constrained through state anti-discrimination laws. The states in which we operate have adopted complaint-based regulation of natural gas gathering activities. Natural gas producers, shippers and other affected parties may file complaints with state regulators in an effort to resolve grievances relating to natural gas gathering access and discrimination with regard to rates and terms of service. A successful complaint, or new laws or regulatory rulings related to gathering, could increase our costs or require us to alter our gathering charges, and our business, and therefore, results of operations and financial condition could be adversely affected. Other state laws and regulations may not directly regulate our business, but may nonetheless affect the availability of natural gas for gathering, purchase, processing and sale, including state regulation of production rates and maximum daily production allowables from gas wells.

Our intrastate natural gas transmission pipeline and several of our gathering systems in Texas are subject to regulation as gas utilities by the Texas Railroad Commission (“TRRC”). The TRRC’s jurisdiction over these pipelines extends to both rates and pipeline safety. The rates we charge for transportation services in Texas generally are deemed just and reasonable under Texas law unless challenged in a complaint. A successful complaint, or new state laws or regulatory rulings related to natural gas utilities, could increase our costs or require us to alter our service charges.

To the extent that our intrastate transmission pipeline in Texas transports natural gas in interstate commerce, the rates, terms and conditions of that transportation service are subject to regulation by the Federal Energy Regulatory Commission (“FERC”) pursuant to Section 311 of the Natural Gas Policy Act of 1978. Section 311 requires, among other things, that rates for such interstate service, which may be established by FERC or the applicable state agency, be “fair and equitable,” and permits the FERC to approve terms and conditions of service. If our Section 311 rates are successfully challenged, if we are unable to include all of our costs in the cost of service approved in a future rate case, if FERC changes its regulations or policies, or establishes more onerous terms and conditions applicable to Section 311 service, our margins relating to this activity would be adversely affected.

We also have transportation contracts with interstate pipelines that are subject to FERC regulation. As a shipper on an interstate pipeline, we are subject to FERC requirements related to use of the interstate capacity. Any failure on our part to comply with the FERC’s regulations or an interstate pipeline’s tariff could result in the imposition of administrative civil and criminal penalties.

We have interests in three NGL pipelines, all of which are located in Texas. We believe that these pipelines do not provide interstate service and that they are thus not subject to FERC jurisdiction under the Interstate Commerce Act (“ICA”) and the Energy Policy Act of 1992. Under the ICA, tariffs must be just and reasonable and not unduly discriminatory or confer any undue preference. We cannot guarantee that the jurisdictional status of our NGL facilities will remain unchanged, however. Should they be found jurisdictional, the FERC’s rate-making methodologies may limit our ability to set rates based on our actual costs, may delay the use of rates that reflect increased costs and may subject us to potentially burdensome and expensive operational, reporting and other requirements. Any of the foregoing could adversely affect our business, revenues and cash flow. The price at which we buy and sell natural gas and NGLs is currently not subject to federal regulation and, for the most part, is not subject to state regulation. However, with regard to our physical purchases and sales of these energy commodities, our gathering or transportation of these energy commodities, and any related hedging activities that we undertake, we are required to observe anti-market manipulation laws and related regulations enforced by the FERCand/or the CFTC. The FERC and the CFTC hold substantial enforcement authority under the anti-market manipulation laws and regulations, including the ability to assess civil penalties of up to $1 million per day per violation, to order disgorgement of profits and to recommend criminal penalties. Should we violate the anti-market manipulation laws and regulations, we could also be subject to related third party damage claims by, among others, sellers, royalty owners and taxing authorities.

The FERC has also promulgated additional market-monitoring and reporting regulations intended to increase the transparency of wholesale energy markets, protect the integrity of such markets and improve the FERC’s ability to assess market forces and detect market manipulation. One such set of regulations, FERC Order No. 720, requires certain major non-interstate pipelines to post daily information on each such pipeline’s internet web site concerning capacity and scheduled flow information. Order No. 720 is currently pending rehearing before FERC. FERC has requested supplemental comments on a number of issues and has proposed revisions to its Order No. 720 regulations. The FERC has also issued a Notice of Proposed Rulemaking proposing to increase the frequency, level of detail and mode of contract reporting by intrastate Section 311 natural gas pipelines. We cannot predict the ultimate outcome of these proceedings. Additionally, the FERC has imposed new rules requiring certain wholesale purchasers and sellers of physical natural gas to report aggregated annual volume and other information beginning in 2009. These and other transparency rules may subject certain of our operations to additional reporting requirements, which could subject us to further costs and administrative burdens.

These and other new laws and regulations or any administrative or judicial re-interpretations of existing laws, regulations or agreements could require us to incur increased costs and administrative burdens, and our business, results of operations and financial condition could be adversely affected. For instance, on February 19, 2008, the U.S. Supreme Court agreed to hear arguments in a lawsuit,Montana v. Wyoming, filed by the State of Montana against Wyoming over water rights in two rivers that flow through both states. Montana is asserting that Wyoming is using too much water from the Tongue and Powder Rivers pursuant to the Yellowstone River Compact, an agreement that both states entered into in 1950 addressing how the states may share water from the Yellowstone River and its tributaries, including the Tongue and Powder Rivers. A critical element of Montana’s argument is that the Compact applies to groundwater and, among other things, that Wyoming’s permitting of coal bed methane production, which involves the pumping of large quantities of groundwater, is depleting the waters of the two rivers to the detriment of Montana and its water users and in violation of the Compact. Wyoming’s position is that the Compact does not address groundwater. Among other things, Montana asks the High Court to declare the rights of Montana to water from these two rivers pursuant to the Compact and to issue a decree commanding Wyoming in the future to deliver the waters of these two rivers to Montana in accord with the Compact. This lawsuit has only recently been accepted for review by the U.S. Supreme Court and no substantive determination has yet been made regarding the use of waters from these two rivers, including the associated groundwater. Any decision made by the U.S. Supreme Court as a result of this case that effectively limits the amount of groundwater pumped in connection with coal bed methane production in Wyoming may have significant adverse impacts on the volume of production by coal bed methane producers in affected areas of Wyoming and, correspondingly, on gathering services that Bighorn Gas Gathering, L.L.C. (“Bighorn”) and Fort Union provide.

We must on occasion rely upon rulings by FERC or other governmental authorities to carry out certain of our business plans. For example, in order to carry out our acquisition of the McMullen Lateral pipeline,

Transcontinental Gas Pipeline Corp. (“Transco”), a subsidiary of The Williams Companies, Inc., must obtain a FERC order allowing abandonment of the facilities by Transco, as well as various other related FERC authorizations. The abandonment application is subject to protests filed by third parties and there is no guarantee that FERC will grant the application and the authorizations requested therein. Moreover, there is no guarantee that, if granted, such authorizations will be timely or will be free from potentially burdensome conditions.

Climate change legislation, regulatory initiatives and litigation could result in increased operating costs and reduced demand for the natural gas and NGL services we provide.

On June 26, 2009, the U.S. House of Representatives approved the adoption of the “American Clean Energy and Security Act of 2009,” also known as the “Waxman-Markeycap-and-trade legislation” or “ACESA.” The purpose of ACESA is to control and reduce emissions of “greenhouse gases,” or “GHGs,” in the United States. GHGs are certain gases, including carbon dioxide and methane, that may be contributing to warming of the Earth’s atmosphere and other climatic changes. ACESA would establish an economy-wide cap on emissions of GHGs in the United States and would require an overall reduction in GHG emissions of 17% (from 2005 levels) by 2020, and by over 80% (from 2005 levels) by 2050. Regulated entities under ACESA would include producers of petroleum based fuels, including refiners of oil, fractionators of NGLs and natural gas distribution companies. Under ACESA, most regulated sources of GHG emissions would be required to obtain GHG emission “allowances” corresponding to their annual emissions of GHGs. The number of emission allowances authorized each year would decline as necessary to meet ACESA’s overall emission reduction goals. As the number of GHG emission allowances declines each year, the cost or value of allowances is expected to escalate significantly. The net effect of ACESA will be to impose increasing costs on the combustion of carbon-based fuels such as oil, refined petroleum products and natural gas. The Senate is considering climate change legislation during the fall of 2009.

In addition, on April 17, 2009, the U.S. Environmental Protection Agency, or “EPA,” issued a notice of its proposed finding and determination that emissions of carbon dioxide, methane and other GHGs presented an endangerment to human health and the environment because emissions of such gases are, according to EPA, contributing to warming of the Earth’s atmosphere. Once finalized, EPA’s finding and determination would allow it to begin regulating emissions of GHGs under existing provisions of the federal Clean Air Act. In addition, on September 22, 2009, the EPA issued a final rule requiring the reporting of greenhouse gas emissions from specified large greenhouse gas emission sources in the United States, including natural gas liquids fractionators and local natural gas distribution companies, beginning in 2011 for emissions occurring in 2010. Although it may take EPA several years to adopt and impose regulations limiting emissions of GHGs, any limitation on emissions of GHGs from our equipment and operations could require us to incur costs to reduce emissions of GHGs associated with our operations. Also, two appellate courts recently took actions that allowed two lawsuits to resume to decide on the merits whether certain business entities could be held liable under common law actions with respect to those entities’ emission of greenhouse gases. With regard to one of the proceedings, on September 21, 2009, the U.S. Court of Appeals for the Second Circuit reinstated a lawsuit filed by several state attorneys general and others against five of the largest U.S. electric utility companies alleging that those companies have created a public nuisance due to their emissions of carbon dioxides. In the other proceeding, on October 16, 2009, the U.S. Court of Appeals for the Fifth Circuit allowed a lawsuit to resume wherein a putative class of property owners along the Mississippi Gulf Coast have alleged that an array of electric utilities and fossil fuel and chemical companies were negligent or had created trespass or nuisance conditions through their emissions of greenhouse gases that added to the ferocity of Hurricane Katrina in 2005.

Although it is not possible at this time to predict if and when the Senate may act on climate change legislation or how any bill passed by the Senate would be reconciled with ACESA or what effect, if any, the recent decisions permitting the common law negligence, trespassand/or nuisance lawsuit to proceed against certain utilities and fossil fuel and chemical companies may have on the oil and gas industry, any future federal or state laws or implementing regulations that may be adopted to address greenhouse gas emissions, as well as future climate change litigation against us or our customers for GHG emissions, could result in increased compliance costs or additional operating restrictions, and could have an adverse effect on demand for the natural gas and NGL services we provide.

A change in the characterization of some of our assets by federal, state or local regulatory agencies could adversely affect our business.

Section 1(b) of the NGA provides that the FERC’s jurisdiction does not extend to facilities used for the production or gathering of natural gas. “Gathering” is not specifically defined by the NGA or its implementing regulations, and there is no bright-line test for determining the jurisdictional status of pipeline facilities. Although some guidance is provided by case law, the process of determining whether facilities constitute gathering facilities for purposes of regulation under the NGA is fact-specific and subject to regulatory change. Additionally, our construction, expansion, extension or alteration of pipeline facilities may involve regulatory, environmental, political and legal uncertainties, including the possibility that physical changes to our pipeline systems may be deemed to affect their jurisdictional status.

The distinction between FERC-regulated interstate natural gas transmission services and federally unregulated gathering services has been the subject of litigation, as has been the line between intrastate and interstate transportation services. Thus, the classification and regulation of some of our natural gas gathering facilities and our intrastate transportation pipeline may be subject to change based on future determinations by the FERCand/or the courts. Should any of our natural gas gathering or intrastate facilities be deemed to be jurisdictional under the NGA, we could be required to comply with numerous federal requirements for interstate service, including laws and regulations governing the rates charged for interstate transportation services, the terms and conditions of service, certification and construction of new facilities, the extension or abandonment of services and facilities, the maintenance of accounts and records, the initiation and discontinuation of services, the monitoring and posting of real-time system information and many other requirements. Failure to comply with all applicable FERC-administered statutes, rules, regulations and orders could result in substantial penalties and fines. It is also possible that our gathering facilities could be deemed by a relevant state commission or court, or by a change in law or regulation, to constitute intrastate pipelines subject to general state law and regulation of rates and terms and conditions of service. A change in jurisdictional status through litigation or legislation could require significant changes to the rates, terms and conditions of service on the affected pipeline, could increase the expense of providing service and adversely affect our business.

The distinction between FERC-regulated common carriage of NGLs, and the non-jurisdictional intrastate transportation of NGLs, has also been the subject of litigation. The FERC, under the ICA, the Energy Policy Act of 1992 and the rules and orders promulgated thereunder, regulates the tariff rates for interstate NGL transportation and these rates must be filed with the FERC. Under the ICA, tariffs must be just and reasonable and not unduly discriminatory or confer any undue preference. To the extent any of our NGL assets are subject to the jurisdiction of the FERC, the FERC’s rate-making methodologies could limit our ability to set rates that we might otherwise be able to charge, could delay the use of rates that reflect increased costs and could subject us to potentially burdensome and expensive operational, reporting and other requirements. Any of the foregoing could adversely affect our business, revenues and cash flow.

We may incur significant costs and liabilities resulting from pipeline integrity programs and related repairs.

We are subject to regulation by the U.S. Department of Transportation (“DOT”) under the Natural Gas Pipeline Safety Act of 1968, as amended, with respect to our natural gas lines and the Hazardous Liquids Pipeline Safety Act of 1979, as amended, with respect to our NGL lines, pursuant to which the DOT has established requirements relating to the design, installation, testing, construction, operation, replacement and management of pipeline facilities. In addition, we are subject to regulation by the DOT under the Pipeline Safety Improvement Act of 2002, which was amended by the Pipeline Inspection, Protection, Enforcement and Safety Act of 2006 (“PIPES”), and pursuant to which the DOT has implemented regulations establishing mandatory inspections for all United States oil (including NGL) and natural gas transportation pipelines and gathering lines meeting certain operational risk and location requirements. Moreover, the DOT has developed PIPES regulations that require operators of certain rural onshore hazardous liquid gathering lines and low-stress pipelines located in specified unusually sensitive areas to comply with additional safety requirements addressing primarily corrosion and third-party damage concerns applicable to such pipelines.

Although many of our natural gas facilities fall within a class that is not subject to these requirements, we may incur significant costs and liabilities associated with repair, remediation, preventative or mitigation measures associated with non-exempt pipelines. Such costs and liabilities might relate to repair, remediation, preventative or mitigating actions that may be determined to be necessary as a result of the testing program, as well as lost cash flows resulting from shutting down our pipelines during the pendency of such repairs. Additionally, we may be affected by the testing, maintenance and repair of pipeline facilities downstream from our own facilities. Our NGL pipelines are also subject to integrity management and other safety regulations imposed by the TRRC.

Any regulatory expansion of the existing pipeline safety requirements or the adoption of new pipeline safety requirements could also increase our cost of operation and impair our ability to provide service during the period in which assessments and repairs take place, adversely affecting our business.

Because we handle natural gas, NGLs and other hydrocarbons in our pipeline and processing businesses, we may incur significant costs and liabilities in the future resulting from a failure to comply with new or existing environmental regulations or an accidental release of waste substances into the environment.

The operation of our gathering systems, plants and other facilities is 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 wastes and other regulated 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 and, under certain circumstances, 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 environmental costs and liabilities in our business due to our handling of natural gas, NGLs and other hydrocarbons, 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, it is possible 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.

Expanding our business by constructing new assets will subject us to risks that projects may not be completed on schedule, the costs associated with the projects may exceed our expectations and additional natural gas supplies may not be available following completion of the projects, which could cause our revenues to be less than anticipated. Our operating cash flows from our capital projects may not be immediate.

One of the ways we may grow our business is through the construction of additions to our existing gathering and transportation systems (including additional compression) and modifications to, or construction of, natural gas processing plants. The construction of additions or modifications to our existing gathering and transportation systems and processing and treating facilities, and the construction of new gathering and processing facilities, involve numerous regulatory, environmental, political, legal and operational uncertainties beyond our control and require the expenditure of significant amounts of capital. These projects also involve numerous economic uncertainties, including the impact of inflation on project costs and the availability of required resources. If we undertake these projects, they may not be completed on schedule or at all or at the budgeted cost. Moreover, we may not receive any material increase in operating cash flow from a project for some time. If we experience unanticipated or extended delays in generating operating cash flow from these projects, then we may need to reduce or reprioritize our capital budget in order to meet our capital requirements. We often rely on estimates of

future production in deciding to construct additions to our gathering and transportation systems. These estimates may prove to be inaccurate because of the numerous technological, economic and other 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, and that in turn, could adversely affect our cash flows and results of operations.

If the cost of renewing existing rights-of-way increases, it may have an adverse impact on our profitability. In addition, if we are unable to obtain new rights-of-way, then we may be unable to fully execute our growth strategy.

The construction of additions to our existing gathering and transportation assets may require us to obtain new rights-of-way prior to constructing new pipelines. We may be unable to obtain such 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 renewing existing rights-of-way increases, then our results of operations could be adversely affected. In addition, increased rights-of-way costs could impair our ability to grow.

Our business involves many hazards and operational risks, some of which may not be fully covered by insurance. If a significant accident or event occurs that is not fully insured, our operations could be temporarily or permanently impaired, and our liabilities and expenses could be significant.

Our operations are subject to the many hazards inherent in the gathering, compression, treating, processing, transportation and fractionation of natural gas and NGLs, including:


	•	damage to pipelines, pipeline blockages and damage to related equipment and surrounding properties caused by hurricanes, tornadoes, floods, fires, extreme weather conditions and other natural disasters and acts of terrorism;

	•	inadvertent damage from motor vehicles, construction or farm equipment;

	•	leaks of natural gas, NGLs and other hydrocarbons;

	•	operator error; and

	•	fires and explosions.

These risks could result in substantial losses due to personal injuryand/or loss of life, severe damage to and destruction of property and equipment and pollution or other environmental damage and may result in curtailment or suspension of our related operations. In addition, mechanical malfunctions, undetected leaks in pipelines, faulty measurement or other errors may result in significant costs or lost revenues. Our operations are primarily concentrated in the Texas Gulf Coast and north Texas regions, in central and east Oklahoma and in Wyoming, and a natural disaster or other hazard affecting any of these areas could have a material adverse effect on our operations, even if our own facilities are not directly affected. For example, although we did not suffer significant damage due to Hurricane Ike in September 2008, the storm damaged gathering systems and processing and NGL fractionation facilities along the Gulf Coast, including facilities owned by third-party service providers on whom we depend in providing services to our customers. Some companies were required to curtail or suspend operations, which adversely affected various energy companies with assets in the region, including us.

There can be no assurance that insurance will cover all damages and losses resulting from these types of natural disasters. We are not fully insured against all risks incident to our business. In accordance with typical industry practice, we generally do not have any property insurance on any of our underground pipeline systems that would cover damage to the pipelines. We are not insured against all environmental accidents that might occur, other than those considered to be sudden and accidental. Our business interruption insurance covers only certain lost revenues arising from physical damage to our processing plants and certain pipeline facilities. If a significant accident or event occurs that is not fully insured, our operations could be temporarily or permanently impaired, and our liabilities and expenses could be significant.

Due to our limited asset diversification, adverse developments in our gathering, transportation, processing and related businesses would have a significant impact on our results of operations.

Substantially all of our revenues are generated from our gathering, dehydration, treating, conditioning, processing, fractionation and transportation business, and as a result, our financial condition depends upon prices of, and continued demand for, natural gas and NGLs. Furthermore, substantially all of our assets are located in Texas, Oklahoma and Wyoming. Due to our limited diversification in asset type and location, an adverse development in one of these businesses or in these areas would have a significantly greater impact on our cash flows, results of operations and financial condition than if we maintained more diverse assets.

If we fail to maintain an effective system of internal control over financial reporting, we may not be able to accurately report our financial results or prevent fraud. As a result, we may experience materially higher compliance costs.

In 2005, we began a process to annually document and evaluate our internal control over financial reporting to satisfy the requirements of Section 404 of the Sarbanes-Oxley Act of 2002, which requires that the effectiveness of our internal control over financial reporting be subjected to annual assessment by management and annual audit by our independent registered public accounting firm. In this regard, management has dedicated internal resources, engaged outside consultants and adopted a detailed work plan to (i) assess and document the adequacy of our internal control over financial reporting, (ii) take steps to improve control processes, where appropriate, (iii) validate through testing that controls are functioning as documented and (iv) implement a continuous review and reporting process for internal control over financial reporting. We cannot be certain that these measures will ensure that we maintain adequate controls over our financial processes and reporting in the future. Any failure to implement required new controls, or difficulties encountered in their implementation, could harm our operating results or cause us to fail to meet our reporting obligations. If our compliance with policies or procedures deteriorates and we fail to correct any associated issues in the design or operating effectiveness of our internal control over financial reporting or fail to prevent fraud, current and potential holders of our securities could lose confidence in our financial reporting, which could harm our business.

We own interests in limited liability companies and a general partnership in which third parties also own interests, which may limit our ability to influence significant business decisions affecting these entities.

In addition to our wholly owned subsidiaries, we own interests in a number of entities in which third parties also own an interest. These interests include our:


	•	62.5% interest in Webb/Duval Gatherers;

	•	majority interest in Southern Dome, LLC;

	•	51% interest in Bighorn; and

	•	37.04% interest in Fort Union

Although we serve as operator of Webb/Duval Gatherers, managing member and operator of Southern Dome, managing member and field operator of Bighorn and managing member of Fort Union, certain substantive business decisions with respect to these entities require the majority or unanimous approval of the owners or, in the case of Bighorn, of a management committee to which we have the right to appoint 50% of the members. Examples of some of these substantive business decisions include significant expenditures or contractual commitments, the construction or acquisition of assets, borrowing money or otherwise raising capital and transactions not in the ordinary course of business, among others. Differences in views among the respective owners of these entities could result in delayed decisions or in failures to agree on significant matters, potentially adversely affecting their respective businesses and results of operations or prospects and, in turn, the amounts and timing of cash from operations distributed to their respective members or partners, including us.

In addition, we do not control the day-to-day operations of Fort Union. Our lack of control over Fort Union’s day-to-day operations and the associated costs of operations could result in our receiving lower cash distributions than we anticipate, which could reduce our cash flow available for distribution to our unitholders.

Risks Related to Our Structure

Our limited liability company agreement prohibits a unitholder who acquires 15% or more of our common units without the approval of our Board of Directors from engaging in a business combination with us for three years. This provision could discourage a change of control that our unitholders may favor, which could negatively affect the price of our common units.

Our limited liability company agreement effectively adopts Section 203 of the Delaware General Corporation Law (the “DGCL”). Section 203 of the DGCL as it applies to us prevents an interested unitholder, defined as a person who owns 15% or more of our outstanding units, from engaging in business combinations with us for three years following the time such person becomes an interested unitholder, except in limited circumstances. Section 203 broadly defines “business combination” to encompass a wide variety of transactions with or caused by an interested unitholder, including mergers, asset sales and other transactions in which the interested unitholder receives a benefit on other than a pro rata basis with other unitholders. This provision of our limited liability company agreement could have an anti-takeover effect with respect to transactions not approved in advance by our Board of Directors, including discouraging takeover attempts that might result in a premium over the market price for our common units.

We may issue additional common units without your approval, which would dilute your existing ownership interests.

Our limited liability company agreement does not limit the number of additional limited liability company interests that we may issue at any time without the approval of our unitholders, including common units and other equity securities that rank senior to common units. The issuance of additional common units or other equity securities of equal or senior rank will have the following effects:


	•	your proportionate ownership interest in us will decrease;

	•	the amount of cash available for distribution on each unit may decrease;

	•	the relative voting strength of each previously outstanding unit will be diminished; and

	•	the market price of the common units may decline.

Our limited liability company agreement provides for a limited call right that may require you to sell your common units at an undesirable time or price.

If, at any time, any person owns more than 90% of the common units then outstanding, such person has the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the remaining common units then outstanding at a price not less than the then-current market price of the common units. As a result, you may be required to sell your common units at an undesirable time or price and may therefore not receive any return on your investment. You may also incur tax liability upon a sale of your units.

Certain of our investors may sell units in the public market, which could reduce the market price of our outstanding common units.

Pursuant to agreements with our pre-IPO investors and investors in private placements we effected in 2005, 2006 and 2007, we have filed or agreed to file registration statements onForm S-3 registering sales by selling unitholders of an aggregate of 39,354,334 of our common units, including 3,245,817 common units to be issued upon conversion of our outstanding Class D units. If investors holding these units were to dispose of a substantial portion of these units in the public market, whether in a single transaction or series of transactions, it could adversely affect the market price for our common units. In addition, these sales, or the possibility that these sales may occur, could make it more difficult for us to sell our common units in the future.

Increases in interest rates could adversely affect our unit price.

Interest rates on future credit facilities and debt offerings could be higher than current levels, causing our financing costs to increase accordingly. An increase in interest rates could also cause a corresponding decline in

demand for equity investments, in general, and in particular for yield-based equity investments such as our common units. Lower demand for our common units for any reason, including competition from other more attractive investment opportunities, would likely cause the trading price of our common units to decline. If we issue additional equity at a significantly lower price, material dilution to our existing unitholders could result.

Risks Related to Our Debt Securities

We have a holding company structure in which our subsidiaries conduct our operations and own our operating assets.

We are a holding company, and our subsidiaries conduct all of our operations and own all of our operating assets. We have no significant assets other than the limited liability company interests and other equity interests in our subsidiaries. As a result, our ability to make required payments on our outstanding senior notes or any future issuances of debt securities will depend on the performance of our subsidiaries and the other entities in which we own interests, and their ability to distribute funds to us. The ability of our subsidiaries to make distributions to us may be restricted by, among other things, state and other laws and regulations or, in the case of other entities in which we own an interest, debt that they may incur, which could be governed by agreements restricting their ability to distribute cash to us. If we are unable to obtain the funds necessary to pay the principal amount at maturity of our outstanding senior notes or any future issuance of debt securities, or to repurchase our outstanding senior notes upon the occurrence of a change of control, we may be required to adopt one or more alternatives, such as a refinancing of our outstanding senior notes or any future issuance of debt securities. We cannot assure you that we would be able to refinance our outstanding senior notes or any future issuance of debt securities.

We require a significant amount of cash to service our indebtedness. Our ability to generate cash depends on many factors beyond our control.

Our ability to make payments on and to refinance our indebtedness, including our outstanding senior notes and any future issuance of debt securities, and to fund planned capital expenditures depends on our ability to generate cash in the future. This, to a certain extent, is subject to general economic, financial, competitive, legislative, regulatory and other factors that are beyond our control.

We cannot assure you that we will generate sufficient cash flow from operations or that future borrowings will be available to us under our revolving credit facility or otherwise in an amount sufficient to enable us to pay our indebtedness, including our outstanding senior notes and any future issuance of debt securities, or to fund our other liquidity needs. We may need to refinance all or a portion of our indebtedness, including our outstanding senior notes and any future issuance of debt securities, on or before maturity. We cannot assure you that we would be able to refinance any of our indebtedness, including our outstanding senior notes and any future issuances of debt securities, on commercially reasonable terms or at all.

We do not have the same flexibility as other types of organizations to accumulate cash, which may limit cash available to service our outstanding senior notes or any future issuances of debt securities or to repay them at maturity.

Subject to the limitations on restricted payments contained in the indentures governing our outstanding senior notes and in our revolving credit facility and any other indebtedness, we distribute all of our “available cash” each quarter to our unitholders. “Available cash” is defined in our limited liability company agreement, and it generally means, for each fiscal quarter:


	•	all cash on hand at the end of the quarter;

	•	plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. Our credit facility does not provide for the type of working capital borrowing that would be eligible, pursuant to our limited liability company agreement, to be considered available cash.


	•	less the amount of cash that our Board of Directors determines in its reasonable discretion is necessary or appropriate to:


	•	provide for the proper conduct of our business (including reserves for future capital expenditures and for our future credit needs);

	•	comply with applicable law, any of our debt instruments, or other agreements or obligations; or

	•	provide funds for distributions to our unitholders for any one or more of the next four quarters.

As a result, we may not accumulate significant amounts of cash. If our Board of Directors fails to establish sufficient reserves, these distributions could significantly reduce the cash available to us in subsequent periods to make payments on our outstanding indebtedness.

The guarantees by certain of our subsidiaries of our outstanding senior notes and any future issuances of debt securities could be deemed fraudulent conveyances under certain circumstances, and a court may try to subordinate or void these subsidiary guarantees.

Under U.S. bankruptcy law and comparable provisions of state fraudulent transfer laws, a guarantee can be voided, or claims under a guarantee may be subordinated to all other debts of that guarantor if, among other things, the guarantor, at the time it incurred the indebtedness evidenced by its guarantee:


	•	intended to hinder, delay or defraud any present or future creditor or received less than reasonably equivalent value or fair consideration for the incurrence of the guarantee;

	•	was insolvent or rendered insolvent by reason of such incurrence;

	•	was engaged in a business or transaction for which the guarantor’s remaining assets constituted unreasonably small capital; or

	•	intended to incur, or believed that it would incur, debts beyond its ability to pay those debts as they mature.

In addition, any payment by that guarantor under a guarantee could be voided and required to be returned to the guarantor or to a fund for the benefit of the creditors of the guarantor. The measures of insolvency for purposes of these fraudulent transfer laws will vary depending upon the law applied in any proceeding to determine whether a fraudulent transfer has occurred. Generally, however, a subsidiary guarantor would be considered insolvent if:


	•	the sum of its debts, including contingent liabilities, was greater than the fair saleable value of all of its assets;

	•	the present saleable value of its assets was less than the amount that would be required to pay its probable liability, including contingent liabilities, on its existing debts as they become absolute and mature; or

	•	it could not pay its debts as they became due.

Tax Risks to Common Unitholders

You should read “Material Tax Consequences” for a more complete discussion of the expected material federal income tax consequences of owning and disposing of common units.

Our tax treatment depends on our status as a partnership for federal income tax purposes, as well as our not being subject to a material amount of entity-level taxation by individual states. If the IRS were to treat us as a corporation for tax purposes or we were to become subject to a material amount of entity-level taxation, it would substantially reduce the amount of cash available for distribution to our unitholders.

The anticipated after-tax economic benefit of an investment in our 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 with respect to this or any other tax matter.

Despite the fact that we are a limited liability company under Delaware law, it is possible in certain circumstances for a limited liability company such as ours to be treated as a corporation for federal income tax purposes. Although we do not believe based upon our current operations that we should be so treated, a change in our business (or a change in current law) could cause us to be treated as a corporation for federal income tax purposes or otherwise subject us to taxation as an entity.

If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rates, currently at a maximum rate of 35%, and would likely pay state income tax at varying rates. Distributions to you would generally be taxed again as corporate distributions, and no income, gain, loss or deduction would flow through to you. Because a tax would be imposed on us as a corporation, our cash available for distribution to our unitholders would be substantially reduced. Therefore, treatment of us as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to our unitholders and would likely result in a substantial reduction in the value of our common units.

In addition, because of widespread state budget deficits and other reasons, several states are evaluating ways to subject limited liability companies to entity-level taxation through the imposition of state income, franchise or other forms of taxation. For example, we are required to pay Texas franchise tax at a maximum effective rate of 0.7% of our federal gross income apportioned to Texas in the prior year. Imposition of such a tax on us by any other state will further reduce the cash available for distribution to our unitholders. Moreover, at the federal level, legislation has been considered that would have eliminated pass-through tax treatment for certain publicly traded limited liability companies. Although such legislation would not have applied to us as considered, it could be reintroduced in a manner that does apply to us. We are unable to predict whether any of these changes or other proposals will be reintroduced or will ultimately be enacted. Additionally, any modification to the federal income tax laws and interpretations thereof may or may not be applied retroactively. Any such changes could negatively impact the value of an investment in our common units.

If the IRS contests the federal income tax positions we take, the market for our common units may be adversely impacted, and the costs of any IRS contest will reduce cash available for distribution to our unitholders.

We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes or any other matter affecting us. The IRS may adopt positions that differ from the positions we take. It may be necessary to resort to administrative or court proceedings to sustain some or all of the positions we take. A court may disagree with some or all of the positions we take. Any contest with the IRS may materially and adversely impact the market for our common units and the price at which they trade. In addition, our costs of any contest with the IRS will be borne indirectly by our unitholders because the costs will reduce our cash available for distribution.

You will be required to pay taxes on the share of our income allocated to you even if you do not receive any cash distributions from us.

Because our unitholders are treated as partners to whom we allocate taxable income, you will be required to pay any federal income taxes and, in some cases, state and local income taxes on your share of our taxable income, regardless of the amount of any distributions from us. You may not receive cash distributions from us equal to your share of our taxable income or even equal to the actual tax liability that results from that income.

Tax gain or loss on disposition of our common units could be more or less than expected.

If you sell your common units, you will recognize a gain or loss equal to the difference between the amount realized and your tax basis in those common units. Because distributions in excess of your allocable share of our net taxable income decrease your tax basis in your common units, the amount, if any, of such prior excess distributions with respect to the units you sell, will, in effect, become taxable income to you if you sell such units at a price greater than your tax basis, even if the price you receive is less than your original cost. Furthermore, a substantial portion of the amount realized, whether or not representing gain, may be taxed as ordinary income due to potential recapture items, including depreciation recapture. In addition, because the amount realized includes a unitholder’s share of

our nonrecourse liabilities, if you sell your units, you may incur a tax liability in excess of the amount of cash you receive from the sale.

Tax-exempt entities andnon-U.S. persons face unique tax issues from owning common units that may result in adverse tax consequences to them.

Investment in common units by tax-exempt entities, including employee benefit plans and individual retirement accounts (known as IRAs), andnon-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations exempt from federal income tax, including individual retirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to such a unitholder. Distributions tonon-U.S. persons will be reduced by withholding taxes at the highest applicable tax rate, andnon-U.S. persons will be required to file United States federal tax returns and pay tax on their share of our taxable income. If you are a tax-exempt entity or anon-U.S. person, you should consult your tax advisor before investing in our units.

We treat each purchaser of our common units as having the same tax benefits without regard to the actual common units purchased. The IRS may challenge this treatment, which could adversely affect the value of the common units.

Because we cannot match transferors and transferees of common units and for certain other reasons, we have adopted depreciation and amortization positions that may not conform with all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to our unitholders. It also could affect the timing of these tax benefits or the amount of gain on the sale of common units and could have a negative impact on the value of our common units or result in audits of and adjustments to our unitholders’ tax returns.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our unitholders.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The use of this proration method may not be permitted under existing Treasury Regulations. If the IRS were to challenge this method or new Treasury Regulations were issued, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders.

A unitholder whose units are loaned to a “short seller” to cover a short sale of units may be considered as having disposed of those units. If so, he would no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and may recognize gain or loss from the disposition.

Because a unitholder whose units are loaned to a “short seller” to cover a short sale of units may be considered as having disposed of the loaned units, he may no longer be treated for tax purposes as a partner with respect to those units during the period of the loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of our income, gain, loss or deduction with respect to those units may not be reportable by the unitholder and any cash distributions received by the unitholder as to those units could be fully taxable as ordinary income. Unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to modify any applicable brokerage account agreements to prohibit their brokers from borrowing and loaning their units.

The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the technical termination of our partnership for federal income tax purposes.

We will be considered to have technically 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 twelve-month period. For purposes

of determining whether the 50% threshold has been met, multiple sales of the same interest will be counted only once. While we would continue our existence as a Delaware limited liability company, our technical termination would, among other things result in the closing of our taxable year for all unitholders, which would result in us filing two tax returns (and our unitholders could receive two Schedules K-1) for one fiscal year and could result in a deferral of depreciation deductions allowable in computing our taxable income. 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 may also result in more than twelve months of our taxable income or loss being includable in his taxable income for the year of termination. A technical termination would not affect our classification as a partnership for federal income tax purposes, but instead, we would be treated as a new partnership for tax purposes. If treated as a new partnership, we would be required to make new tax elections and could be subject to penalties if we were unable to determine that a termination occurred.

As a result of investing in our common units, you may be subject to state and local taxes and return filing requirements in states where you do not live.

In addition to federal income taxes, unitholders will likely be subject to other taxes, including state and local taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we do business or own property now or in the future, even if our unitholders do not reside in any of those jurisdictions. Our unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these jurisdictions. Further, unitholders may be subject to penalties for failure to comply with those requirements. We currently do business and own assets in Texas, Oklahoma, Wyoming, Colorado and Louisiana. Although Texas and Wyoming do not currently impose a personal income tax, Oklahoma, Colorado and Louisiana do and as we make acquisitions or expand our business, we may do business or own assets in other jurisdictions that impose a personal income tax. It is the responsibility of each unitholder to file all United States federal, state and local tax returns that may be required of such unitholder.

USE OF PROCEEDS

Unless we specify otherwise in any prospectus supplement, we will use the net proceeds we receive from the sale of securities covered by this prospectus for general corporate purposes, which may include, among other things:


	•	paying or refinancing all or a portion of our indebtedness outstanding at the time; and

	•	funding working capital, capital expenditures or acquisitions.

The application of proceeds from any particular offering of securities using this prospectus will be described in the prospectus supplement relating to such offering. The precise amount and timing of the application of these proceeds will depend on our funding requirements and the availability and cost of other funds.

RATIOS OF EARNINGS TO FIXED CHARGES

Year Ended December 31,

Six Months Ended

2004

2005

2006

2007

2008

June 30, 2009

Ratio of earnings to fixed charges

—

(a)

2.4

2.9

3.1

2.1

1.7x


(a)		Earnings were inadequate to cover fixed charges for the year ended December 31, 2004 by $1.3 million.

For purposes of calculating the ratio of consolidated earnings to fixed charges:


	•	“earnings” means the aggregate of the following items: pre-tax income from continuing operations before adjustment for income or loss from equity investees; plus fixed charges; plus amortization of capitalized interest; plus distributed income of equity investees; plus our share of pre-tax losses of equity investees for which charges arising from guarantees are included in fixed charges; less interest capitalized; less preference security dividend requirements of consolidated subsidiaries; and less the noncontrolling interest in pre-tax income of subsidiaries that have not incurred fixed charges;


	•	“fixed charges” means the sum of the following: (a) interest expensed and capitalized, (b) amortized premiums, discounts and capitalized expenses related to indebtedness, (c) an estimate of the interest within rental expense and (d) preference security dividend requirements of consolidated subsidiaries; and

	•	“preference security dividend” means the amount of pre-tax earnings that is required to pay the dividends on outstanding preference securities.

DESCRIPTION OF OUR COMMON UNITS

Our common units represent limited liability company interests in us. The holders of our common units are entitled to participate in distributions and exercise the rights or privileges available to members under our limited liability company agreement. As of September 30, 2009, we had 54,601,458 common units outstanding. We also had 3,245,817 Class D units outstanding, all of which will convert into common units in February 2010, upon payment of our cash distribution for the fourth quarter of 2009.

Our Limited Liability Company Agreement

Our limited liability company agreement governs the rights and obligations of our common unitholders. A copy of our limited liability company agreement is included in our other SEC filings and is incorporated by reference in this prospectus.

Our Cash Distribution Policy

Please read “Cash Distribution Policy” for a detailed description of the right to receive cash distributions with respect to our common units.

Timing of Distributions

We pay distributions approximately 45 days after March 31, June 30, September 30 and December 31 to unitholders of record on the applicable record date.

Issuance of Additional Units

In general, we may issue additional equity securities, and options, rights, warrants and appreciation rights relating to our equity securities, for any company purpose at any time and from time to time, to such persons for such consideration and on such terms and conditions as our Board of Directors shall determine, all without the approval of any unitholders. Each additional equity security authorized to be issued by us pursuant to our limited liability company agreement may be issued in one or more classes, or one or more series of any such classes, with such designations, preferences, rights, powers and duties (which may be senior to existing classes and series of our equity securities), as our Board of Directors shall determine, all without the approval of any unitholders.

We may choose to finance acquisitions by issuing additional common units or other equity securities. Holders of any additional common units we issue will be entitled to participate in our distributions of available cash. In addition, the issuance of additional common units or other equity securities may dilute the value of the existing common unitholders’ interests in our net assets.

In accordance with Delaware law and the provisions of our limited liability company agreement, we may also issue additional securities that, as determined by our Board of Directors, may have special voting rights to which the common units are not entitled.

The holders of common units do not have preemptive rights to acquire additional common units or other securities.

Voting Rights

In general, common unitholders have the right to vote with respect to the election of our Board of Directors, certain amendments to our limited liability company agreement, the merger of our company or the sale of all or substantially all of our assets and the dissolution of our company.

Limited Call Right

If, at any time, any person owns more than 90% of the issued and outstanding membership interests of any class, such person will have the right, which it may transfer in whole or in part to any of its affiliates or to us, to acquire all, but not less than all, of the remaining membership interests of the class held by unaffiliated persons as of a record date to be selected by our Board of Directors, on at least 10 but not more than 60 days’ notice. Our unitholders are not entitled to dissenters’ rights of appraisal under our limited liability company agreement or applicable Delaware law if this limited call right is exercised. The purchase price in the event of the exercise of this right is the greater of:


	•	the current market price as of the date three days prior to the date that the notice is mailed; and

	•	the highest price paid by such person or any of its affiliates for any such interest of such class purchased during the90-day period preceding the date that the notice is mailed.

As a result of this limited call right, a holder of membership interests in our company may have its membership interests purchased at an undesirable time or price. Please read “Risk Factors — Risks Related to Our Structure.” The tax consequences to a unitholder of the exercise of this call right are the same as a sale by that unitholder of its common units in the market. Please read “Material Tax Consequences — Disposition of Common Units.”

Exchange Listing

Our common units are listed on the Nasdaq Global Select Market under the symbol “CPNO.”

Transfer Agent and Registrar

Duties

American Stock Transfer & Trust Company, LLC serves as registrar and transfer agent for our common units. We pay all fees charged by the transfer agent for transfers of common units, except the following fees that will 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 will be no charge to unitholders for disbursements of our cash distributions. We will indemnify the transfer agent, its agents and each of their shareholders, directors, officers and employees against all claims and losses that may arise out of acts performed or omitted for its activities as transfer agent, except for any liability due to any gross negligence or intentional misconduct of the indemnified person or entity.

Resignation or Removal

The transfer agent may at any time resign, by notice to us, or be removed by us. The resignation or removal of the transfer agent will become effective upon our appointment of a successor transfer agent and registrar and its acceptance of the appointment. If no successor has been appointed and accepted the appointment within 30 days after notice of the resignation or removal, we are authorized to act as the transfer agent and registrar until a successor is appointed.

Transfer of Common Units

By transfer of common units in accordance with our limited liability company agreement, each transferee of common units shall be admitted as a unitholder with respect to the common units transferred when such transfer and admission is reflected in our books and records. Additionally, each transferee of common units:


	•	automatically agrees to be bound by the terms and conditions of, and is deemed to have executed, our limited liability company agreement;

	•	becomes the record holder of the common units;

	•	represents that the transferee has the capacity, power and authority to enter into our limited liability company agreement;

	•	grants powers of attorney to our officers and any liquidator of our company as specified in the limited liability company agreement; and

	•	makes the consents and waivers contained in the limited liability company agreement.

An assignee will become a unitholder of our company for the transferred common units upon the recording of the name of the assignee on our books and records.

Until a common unit has been transferred on our books, we and the transfer agent, notwithstanding any notice to the contrary, 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.

DESCRIPTION OF OUR DEBT SECURITIES

General

Copano Energy, L.L.C. may issue debt securities in one or more series, and Copano Energy Finance Corporation may be a co-issuer of one or more series of debt securities. Copano Energy Finance Corporation was incorporated under the laws of the State of Delaware in 2005, is wholly owned by Copano Energy, L.L.C. and has no material assets or any liabilities other than as a co-issuer of debt securities. Its activities are limited to co-issuing debt securities and engaging in other activities incidental thereto. When used in this section “Description of Our Debt Securities,” the terms “we,” “us,” “our” and “issuers” refer jointly to Copano Energy, L.L.C. and Copano Energy Finance Corporation, and the terms “Copano Energy” and “Copano Finance” refer strictly to Copano Energy, L.L.C. and Copano Energy Finance Corporation, respectively.

If we offer senior debt securities, we will issue them under a senior indenture. If we issue subordinated debt securities, we will issue them under a subordinated indenture. A form of each indenture is filed as an exhibit to the registration statement of which this prospectus is a part. We have not restated either indenture in its entirety in this description. You should read the relevant indenture because it, and not this description, controls your rights as holders of the debt securities. Capitalized terms used in this summary have the meanings specified in the indentures.

The debt securities will be:


	•	our direct general obligations;

	•	either senior debt securities or subordinated debt securities; and

	•	issued under separate indentures among us, any subsidiary guarantors and a trustee.

Specific Terms of Each Series of Debt Securities in the Prospectus Supplement

A prospectus supplement and a supplemental indenture or authorizing resolutions relating to any series of debt securities being offered will include specific terms relating to the offering. These terms will include some or all of the following:


	•	whether Copano Finance will be a co-issuer of the debt securities;


	•	the guarantors of the debt securities, if any;

	•	whether the debt securities are senior or subordinated debt securities;

	•	the title of the debt securities;

	•	the total principal amount of the debt securities;

	•	the assets, if any, that are pledged as security for the payment of the debt securities;

	•	whether we will issue the debt securities in individual certificates to each holder in registered form, or in the form of temporary or permanent global securities held by a depositary on behalf of holders;

	•	the prices at which we will issue the debt securities;

	•	the portion of the principal amount that will be payable if the maturity of the debt securities is accelerated;

	•	the currency or currency unit in which the debt securities will be payable, if not U.S. dollars;

	•	the dates on which the principal of the debt securities will be payable;

	•	the interest rate that the debt securities will bear and the interest payment dates for the debt securities;

	•	any conversion or exchange provisions;

	•	any optional redemption provisions;

	•	any sinking fund or other provisions that would obligate us to repurchase or otherwise redeem the debt securities;

	•	any changes to or additional events of default or covenants; and

	•	any other terms of the debt securities.

We may offer and sell debt securities, including original issue discount debt securities, at a substantial discount below their principal amount. The prospectus supplement will describe special U.S. federal income tax and any other considerations applicable to those securities. In addition, the prospectus supplement may describe certain special U.S. federal income tax or other considerations applicable to any debt securities that are denominated in a currency other than U.S. dollars.

Guarantees

If specified in the prospectus supplement respecting a series of debt securities, the subsidiaries of Copano Energy specified in the prospectus supplement will fully and unconditionally guarantee to each holder and the trustee, on a joint and several basis, the full and prompt payment of principal of, premium, if any, and interest on the debt securities of that series when and as the same become due and payable, whether at stated maturity, upon redemption or repurchase, by declaration of acceleration or otherwise. If a series of debt securities is guaranteed, such series will be guaranteed by all of Copano Energy’s wholly owned subsidiaries other than “minor” subsidiaries (except Copano Finance) as such term is interpreted in securities regulations governing financial reporting for guarantors. The prospectus supplement will describe any limitation on the maximum amount of any particular guarantee and the conditions under which guarantees may be released.

The guarantees will be general obligations of the guarantors. Guarantees of subordinated debt securities will be subordinated to the Senior Indebtedness of the guarantors on the same basis as the subordinated debt securities are subordinated to the Senior Indebtedness of Copano Energy.

Consolidation, Merger or Asset Sale

Each indenture will, in general, allow us to consolidate or merge with or into another domestic entity. It will also allow each issuer to sell, lease, transfer or otherwise dispose of all or substantially all of its assets to another domestic entity. If this happens, the remaining or acquiring entity must assume all of the issuer’s obligations under

the indenture, including the payment of all amounts due on the debt securities and performance of the issuer’s covenants in the indenture.

However, each indenture will impose certain requirements with respect to any consolidation or merger with or into an entity, or any sale, lease, transfer or other disposition of all or substantially all of an issuer’s assets, including:


	•	the remaining or acquiring entity must be organized under the laws of the United States, any state or the District of Columbia; provided that, if Copano Finance is a co-issuer, then it may not merge or consolidate with or into another entity other than a corporation satisfying such requirement for so long as Copano Energy is not a corporation;

	•	the remaining or acquiring entity must assume the issuer’s obligations under the indenture; and

	•	immediately after giving effect to the transaction, no Default or Event of Default (as defined under “— Events of Default and Remedies” below) may exist.

The remaining or acquiring entity will be substituted for the issuer in the indenture with the same effect as if it had been an original party to the indenture, and, except in the case of a lease of all or substantially all of the assets of an issuer, the issuer will be released from any further obligations under the indenture.

No Protection in the Event of a Change of Control

Unless otherwise set forth in the prospectus supplement, the debt securities will not contain any provisions that protect the holders of the debt securities in the event of a change of control of us or in the event of a highly leveraged transaction, whether or not such transaction results in a change of control of us.

Modification of Indentures

We may supplement or amend an indenture if the holders of a majority in aggregate principal amount of the outstanding debt securities of each series issued under the indenture affected by the supplement or amendment consent to it. Further, the holders of a majority in aggregate principal amount of the outstanding debt securities of any series may waive past defaults under the indenture and compliance by us with our covenants with respect to the debt securities of that series only. Those holders may not, however, waive any default in any payment on any debt security of that series or compliance with a provision that cannot be supplemented or amended without the consent of each holder affected. Without the consent of each outstanding debt security affected, no modification of the indenture or waiver may:


	•	reduce the percentage in principal amount of debt securities whose holders must consent to an amendment, supplement or waiver;

	•	reduce the principal of or extend the fixed maturity of any debt security;

	•	reduce the premium payable upon redemption or change the time of the redemption of the debt securities;

	•	reduce the rate of or extend the time for payment of interest on any debt security;

	•	except as otherwise permitted under the indenture, release any security that may have been granted with respect to the debt securities;

	•	make any debt security payable in currency other than that stated in the debt securities;

	•	in the case of any subordinated debt security, make any change in the subordination provisions that adversely affects the rights of any holder under those provisions;

	•	impair the right of any holder to receive payment of principal, premium, if any, and interest on its debt securities on or after the respective due dates or to institute suit for the enforcement of any such payment;

	•	except as otherwise permitted in the indenture, release any guarantor from its obligations under its guarantee or the indenture or change any guarantee in any manner that would adversely affect the rights of holders; or


	•	make any change in the preceding amendment, supplement and waiver provisions (except to increase any percentage set forth therein).

We may supplement or amend an indenture without the consent of any holders of the debt securities in certain circumstances, including:


	•	to establish the form or terms of any series of debt securities;

	•	to cure any ambiguity, defect or inconsistency;

	•	to provide for uncertificated notes in addition to or in place of certificated notes;

	•	to provide for the assumption of an issuer’s obligations to holders of debt securities in the case of a merger or consolidation or disposition of all or substantially all of such issuer’s assets;

	•	in the case of any subordinated debt security, to make any change in the subordination provisions that limits or terminates the benefits applicable to any holder of Senior Indebtedness of Copano Energy;

	•	to add or release guarantors pursuant to the terms of the indenture;

	•	to make any changes that would provide any additional rights or benefits to the holders of debt securities or that do not adversely affect the rights under the indenture of any holder of debt securities;

	•	to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act of 1939 (the “Trust Indenture Act”);

	•	to evidence or provide for the acceptance of appointment under the indenture of a successor trustee;

	•	to add any additional Events of Default; or

	•	to secure the debt securitiesand/or the guarantees.

Events of Default and Remedies

Unless otherwise indicated in the prospectus supplement, “Event of Default,” when used in an indenture, will mean any of the following with respect to the debt securities of any series:


	•	failure to pay when due the principal of or any premium on any debt security of that series;

	•	failure to pay, within 30 days of the due date, interest on any debt security of that series;

	•	failure to pay when due any sinking fund payment with respect to any debt securities of that series;

	•	failure on the part of the issuers to comply with the covenant described under “— Consolidation, Merger or Asset Sale”;

	•	failure to perform any other covenant in the indenture that continues for 60 days after written notice is given to the issuers;

	•	certain events of bankruptcy, insolvency or reorganization of an issuer or any guarantor of the debt securities of that series (an “insolvency event”);

	•	if that series is guaranteed by any subsidiary of Copano Energy, the guarantee ceases to be in full force and effect (except as provided in the indenture), is declared null and void or the guarantor disaffirms its guarantee; or

	•	any other Event of Default provided under the terms of the debt securities of that series.

An Event of Default for a particular series of debt securities will not necessarily constitute an Event of Default for any other series of debt securities issued under an indenture. The trustee may withhold notice to the holders of debt securities of any default (except in the payment of principal, premium, if any, or interest) if it considers such withholding of notice to be in the best interests of the holders.

If an insolvency event occurs with respect to either issuer, the entire principal of, premium, if any, and accrued interest on, all debt securities then outstanding will be due and payable immediately, without any declaration or other act on the part of the trustee or any holders. If any other Event of Default for any series of debt securities occurs and continues, the trustee or the holders of at least 25% in aggregate principal amount of the debt securities of the series may declare the entire principal of, and accrued interest on, all the debt securities of that series to be due and payable immediately. If this happens, subject to certain conditions, the holders of a majority in the aggregate principal amount of the debt securities of that series can rescind the declaration.

Other than its duties in case of a default, a trustee is not obligated to exercise any of its rights or powers under either indenture at the request, order or direction of any holders, unless the holders offer the trustee reasonable security or indemnity. If they provide this reasonable security or indemnity, the holders of a majority in aggregate principal amount of any series of debt securities may direct the time, method and place of conducting any proceeding or any remedy available to the trustee, or exercising any power conferred upon the trustee, for that series of debt securities.

No Limit on Amount of Debt Securities

Neither indenture will limit the amount of debt securities that we may issue, unless we indicate otherwise in a prospectus supplement. Each indenture will allow us to issue debt securities of any series up to the aggregate principal amount that we authorize.

Registration of Notes

We will issue debt securities of a series only in registered form, without coupons, unless otherwise indicated in the prospectus supplement.

Minimum Denominations

Unless the prospectus supplement states otherwise, the debt securities will be issued only in principal amounts of $1,000 each or integral multiples of $1,000.

No Personal Liability

None of the past, present or future partners, incorporators, managers, members, directors, officers, employees, unitholders or stockholders of either issuer or any guarantor will have any liability for the obligations of the issuers or any guarantors under either indenture or the debt securities or for any claim based on such obligations or their creation. Each holder of debt securities by accepting a debt security waives and releases all such liability. The waiver and release are part of the consideration for the issuance of the debt securities. The waiver may not be effective under federal securities laws, however, and it is the view of the SEC that such a waiver is against public policy.

Payment and Transfer

The trustee will initially act as paying agent and registrar under each indenture. The issuers may change the paying agent or registrar without prior notice to the holders of debt securities, and the issuers or any of their subsidiaries may act as paying agent or registrar.

If a holder of debt securities has given wire transfer instructions to the issuers, the issuers will make all payments on the debt securities in accordance with those instructions. All other payments on the debt securities will be made at the corporate trust office of the trustee indicated in the applicable prospectus supplement, unless the issuers elect to make interest payments by check mailed to the holders at their addresses set forth in the debt security register.

The trustee and any paying agent will repay to us upon request any funds held by them for payments on the debt securities that remain unclaimed for two years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment as general creditors.

Exchange, Registration and Transfer

Debt securities of any series will be exchangeable for other debt securities of the same series, the same total principal amount and the same terms but in different authorized denominations in accordance with the indenture. Holders may present debt securities for exchange or registration of transfer at the office of the registrar. The registrar will effect the transfer or exchange when it is satisfied with the documents of title and identity of the person making the request. We will not charge a service charge for any registration of transfer or exchange of the debt securities. We may, however, require the payment of any tax or other governmental charge payable for that registration.

We will not be required to:


	•	issue, register the transfer of, or exchange debt securities of a series either during a period of 15 business days prior to the mailing of notice of redemption of the debt securities of that series, or between a record date and the next succeeding interest payment date; or

	•	register the transfer of or exchange any debt security selected or called for redemption, except the unredeemed portion of any debt security we are redeeming in part.

Provisions Relating only to the Senior Debt Securities

The senior debt securities will rank equally in right of payment with all of our other senior and unsubordinated debt. The senior debt securities will be effectively subordinated, however, to all of our secured debt to the extent of the value of the collateral for that debt. We will disclose the amount of our secured debt in the prospectus supplement.

Provisions Relating only to the Subordinated Debt Securities

Subordinated Debt Securities Subordinated to Senior Indebtedness

The subordinated debt securities will rank junior in right of payment to all of our Senior Indebtedness. The definitions of “Senior Indebtedness” and “Designated Senior Indebtedness” will be set forth in the prospectus supplement respecting each series of subordinated debt securities. If the subordinated debt securities are guaranteed by any of the subsidiaries of Copano Energy, then the guarantees will be subordinated on like terms.

Payment Blockages

The subordinated indenture will provide that no payment of principal, interest and any premium on the subordinated debt securities (or any related guarantee) may be made in the event:


	•	we or our property (or any guarantor or its property) is involved in any liquidation, bankruptcy or similar proceeding;

	•	we (or any guarantor) fail to pay the principal, interest, any premium or any other amounts on any of our (or the guarantor’s) Senior Indebtedness within any applicable grace period or the maturity of such Senior Indebtedness is accelerated following any other default, subject to certain limited exceptions set forth in the subordinated indenture; or

	•	any other default on any of our (or any guarantor’s) Designated Senior Indebtedness occurs that permits immediate acceleration of its maturity, in which case a payment blockage on the subordinated debt securities will be imposed for a maximum of 179 days at any one time.

No Limitation on Amount of Senior Debt

The subordinated indenture will not limit the amount of Senior Indebtedness that we or any guarantor may incur, unless otherwise indicated in the prospectus supplement.

Book Entry, Delivery and Form

The debt securities of a particular series may be issued in whole or in part in the form of one or more global certificates that will be deposited with the trustee as custodian for The Depository Trust Company, New York, New York (“DTC”). This means that we will not issue certificates to each holder, except in the limited circumstances described below. Instead, one or more global debt securities will be issued to DTC, who will keep a computerized record of its participants (for example, your broker) whose clients have purchased the debt securities. The participant will then keep a record of its clients who purchased the debt securities. Unless it is exchanged in whole or in part for a certificated debt security, a global debt security may not be transferred, except that DTC, its nominees and their successors may transfer a global debt security as a whole to one another.

Beneficial interests in global debt securities will be shown on, and transfers of global debt securities will be made only through, records maintained by DTC and its participants.

DTC has provided us the following information: DTC is a limited-purpose trust company organized under the New York Banking Law, a “banking organization” within the meaning of the New York Banking Law, a member of the Federal Reserve System, a “clearing corporation” within the meaning of the New York Uniform Commercial Code and a “clearing agency” registered pursuant to the provisions of Section 17A of the Exchange Act. DTC holds and provides asset servicing for U.S. andnon-U.S. equity issues, corporate and municipal debt issues, and money market instruments that DTC’s participants (“Direct Participants”) deposit with DTC. DTC also facilitates the post-trade settlement among Direct Participants of sales and other securities transactions in deposited securities, through electronic computerized book-entry transfers and pledges between Direct Participants’ accounts. This eliminates the need for physical movement of securities certificates. Direct Participants include both U.S. andnon-U.S. securities brokers and dealers, banks, trust companies, clearing corporations and certain other organizations. DTC is a wholly owned subsidiary of The Depository Trust & Clearing Corporation (“DTCC”). DTCC is owned by the users of its regulated subsidiaries. Access to the DTC system is also available to others such as both U.S. andnon-U.S. securities brokers and dealers, banks, trust companies and clearing corporations that clear through or maintain a custodial relationship with a Direct Participant, either directly or indirectly (“Indirect Participants”). The DTC Rules applicable to its participants are on file with the SEC.

We will wire all payments on the global debt securities to DTC’s nominee. We and the trustee will treat DTC’s nominee as the owner of the global debt securities for all purposes. Accordingly, we, the trustee and any paying agent will have no direct responsibility or liability to pay amounts due on the global debt securities to owners of beneficial interests in the global debt securities.

It is DTC’s current practice, upon receipt of any payment on the global debt securities, to credit Direct Participants’ accounts on the payment date according to their respective holdings of beneficial interests in the global debt securities as shown on DTC’s records. In addition, it is DTC’s current practice to assign any consenting or voting rights to Direct Participants whose accounts are credited with debt securities on a record date, by using an omnibus proxy. Payments by participants to owners of beneficial interests in the global debt securities, and voting by participants, will be governed by the customary practices between the participants and owners of beneficial interests, as is the case with debt securities held for the account of customers registered in “street name.” However, payments will be the responsibility of the participants and not of DTC, the trustee or us.

Debt securities represented by a global debt security will be exchangeable for certificated debt securities with the same terms in authorized denominations only if:


	•	DTC notifies us that it is unwilling or unable to continue as depositary or if DTC ceases to be a clearing agency registered under applicable law and in either event a successor depositary is not appointed by us within 90 days;

	•	an Event of Default occurs and DTC notifies the trustee of its decision to require the debt securities of a series to no longer be represented by a global debt security; or

	•	as otherwise specified by us in the prospectus supplement pertaining to such debt securities.

Satisfaction and Discharge; Defeasance

Each indenture will be discharged and will cease to be of further effect as to all outstanding debt securities of any series issued thereunder, when:

(a) either:

(1) all outstanding debt securities of that series that have been authenticated (except lost, stolen or destroyed debt securities that have been replaced or paid and debt securities for whose payment money has theretofore been deposited in trust and thereafter repaid to us) have been delivered to the trustee for cancellation; or

(2) all outstanding debt securities of that series that have not been delivered to the trustee for cancellation have become due and payable by reason of the giving of a notice of redemption or otherwise or will become due and payable at their stated maturity within one year or are to be called for redemption within one year under arrangements satisfactory to the trustee and in any case we have irrevocably deposited or caused to be irrevocably deposited with the trustee as trust funds cash sufficient to pay and discharge the entire indebtedness of such debt securities not delivered to the trustee for cancellation, for principal, premium, if any, and accrued interest to the date of such deposit (in the case of debt securities that have been due and payable) or the stated maturity or redemption date;

(b) we have paid or caused to be paid all other sums payable by us under the indenture with respect to the debt securities of that series; and

(c) we have delivered an officers’ certificate and an opinion of counsel to the trustee stating that all conditions precedent to satisfaction and discharge have been satisfied.

The debt securities of a particular series will be subject to legal or covenant defeasance to the extent, and upon the terms and conditions, set forth in the prospectus supplement.

Governing Law

Each indenture and all of the debt securities will be governed by the laws of the State of New York.

The Trustee

We will enter into the indentures with a trustee that is qualified to act under the Trust Indenture Act and with any other trustees chosen by us and appointed in a supplemental indenture for a particular series of debt securities. Unless we otherwise specify in the applicable prospectus supplement, the initial trustee for each series of debt securities will be U.S. Bank National Association. We may maintain a banking relationship in the ordinary course of business with U.S. Bank National Association and one or more of its affiliates.

Resignation or Removal of Trustee

If the trustee has or acquires a conflicting interest within the meaning of the Trust Indenture Act, the trustee must either eliminate its conflicting interest or resign, to the extent and in the manner provided by, and subject to the provisions of, the Trust Indenture Act and the applicable indenture. Any resignation will require the appointment of a successor trustee under the applicable indenture in accordance with the terms and conditions of such indenture.

The trustee may resign or be removed by us with respect to one or more series of debt securities and a successor trustee may be appointed to act with respect to any such series. The holders of a majority in aggregate principal amount of the debt securities of any series may remove the trustee with respect to the debt securities of such series.

Limitations on Trustee if It Is Our Creditor

Each indenture will contain certain limitations on the right of the trustee, in the event that it becomes a creditor of an issuer or a guarantor, to obtain payment of claims in certain cases, or to realize on certain property received in respect of any such claim as security or otherwise.

Annual Trustee Report to Holders of Debt Securities

The trustee is required to submit an annual report to the holders of the debt securities regarding, among other things, the trustee’s eligibility to serve as such, the priority of the trustee’s claims regarding certain advances made by it and any action taken by the trustee materially affecting the debt securities.

Certificates and Opinions to Be Furnished to Trustee

Each indenture will provide that, in addition to other certificates or opinions that may be specifically required by other provisions of such indenture, every application by us for action by the trustee must be accompanied by a certificate of certain of our officers and an opinion of counsel (who may be our counsel) stating that, in the opinion of the signers, all conditions precedent to such action have been complied with by us.

CASH DISTRIBUTION POLICY

Quarterly Distributions of Available Cash

General. We intend to pay quarterly distributions to our common unitholders of record on the applicable record date within 45 days after the end of each quarter (in February, May, August and November of each year) to the extent we have sufficient available cash, as defined in our limited liability company agreement. We will make distributions of available cash to common unitholders in accordance with their respective percentage interests.

Definition of Available Cash. Available cash generally means, with respect to any quarter:


	•	the sum of (1) all cash and cash equivalents on hand at the end of such quarter and (2) all additional cash and cash equivalents on hand with respect to such quarter resulting from working capital borrowings made subsequent to the end of such quarter,less

	•	the amount of any cash reserves established by our Board of Directors to (1) provide for the proper conduct of our business (including reserves for future capital expenditures and for anticipated future credit needs) subsequent to such quarter, (2) comply with applicable law or any loan agreement, security agreement, mortgage, debt instrument or other agreement or obligation to which we or any of our subsidiaries are a party or by which we are bound or our assets are subject or (3) provide funds for distributions in respect of any one or more of the next four quarters.

Contractual Restrictions on Our Ability to Distribute Available Cash. If we are not in compliance with covenants contained in our revolving credit facility or the indentures governing our senior unsecured notes, we will be unable to make distributions of available cash. In addition, if we issue debt securities in the future, then the indenture governing the debt securities will likely contain covenants that limit our ability to make distributions to our unitholders if we fail to comply with such covenants.

Adjustment of Distribution

If we combine our units into fewer units or subdivide our units into a greater number of units, we will proportionately adjust:


	•	the quarterly distribution; and

	•	other amounts calculated on a per unit basis.

For example, if a two-for-one split of the common units should occur, the quarterly distribution would be reduced to 50% of its initial level. We will not make any adjustment by reason of the issuance of additional common units for cash or property.

In addition, if legislation is enacted or if existing law is modified or interpreted in a manner that causes us to become taxable as a corporation or otherwise subject to taxation as an entity for federal, state or local income tax purposes, we will reduce the quarterly distribution level for each quarter by multiplying the quarterly distribution by a fraction, the numerator of which is available cash for that quarter and the denominator of which is the sum of

available cash for that quarter plus our Board of Directors’ estimate of our aggregate liability for the income taxes payable by reason of that legislation or interpretation. To the extent that the actual tax liability differs from the estimated tax liability for any quarter, the difference will be accounted for in subsequent quarters.

Distributions of Cash Upon Liquidation

If we dissolve in accordance with our limited liability company agreement, we will sell or otherwise dispose of our assets in a process called liquidation. We will first apply the proceeds of liquidation to the payment of our creditors. We will distribute any remaining proceeds to our unitholders in accordance with their respective capital account balances, as adjusted to reflect any taxable gain or loss upon the sale or other disposition of our assets in liquidation.

The allocations of taxable gain upon liquidation are intended, to the extent possible, to allow common unitholders to receive proceeds equal to their unrecovered capital plus the quarterly distribution for the quarter during which liquidation occurs. There may not be sufficient taxable gain upon our liquidation to enable common unitholders to fully recover all of these amounts.

MATERIAL TAX CONSEQUENCES

This section is a summary of the material tax consequences 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 Vinson & Elkins L.L.P., counsel to us, insofar as it relates to United States federal income tax law. This section is based upon current provisions of the Internal Revenue Code of 1986, as amended (the “Internal Revenue Code”), existing and proposed Treasury regulations promulgated thereunder (the “Treasury 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. Unless the context otherwise requires, references in this section to “us” or “we” are references to Copano Energy, L.L.C. and its operating subsidiaries.

This section does not address all federal income tax matters that affect us or our unitholders. Furthermore, this section focuses on unitholders who are individual citizens or residents of the United States and has only limited application to corporations, estates, trusts, non-resident 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, each prospective unitholder is encouraged to consult, and depend on, his own tax advisor in analyzing the federal, state, local and foreign tax consequences particular to him of the ownership or disposition of our common units.

No ruling has been or will be requested from the IRS regarding any matter that affects us or prospective unitholders. Instead, we will rely on opinions and advice of Vinson & Elkins L.L.P. 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 herein 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 our common units and the prices at which our 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 thus will be borne directly or indirectly by the unitholders. 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.

All statements as to matters of law and legal conclusions set forth below, unless otherwise noted, are the opinion of Vinson & Elkins L.L.P. and are based on the accuracy of the representations made by us. Statements of fact do not represent opinions of Vinson & Elkins L.L.P.

For the reasons described below, Vinson & Elkins L.L.P. has not rendered an opinion with respect to the following specific federal income tax issues:

(1) 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”);

(2) 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

(3) whether our method for depreciating Section 743 adjustments is sustainable in certain cases (please read “— Tax Consequences of Unit Ownership — Section 754 Election”).

Partnership Status

A limited liability company is treated as a partnership for federal income tax purposes and, therefore, is not a taxable entity and incurs no federal income tax liability. Instead, each unitholder of a partnership is required to take into account his share of items of income, gain, loss and deduction of the partnership in computing his federal income tax liability, even if no cash distributions are made to him. Distributions by a partnership to a unitholder are generally not taxable to the unitholder unless the amount of cash distributed to him is in excess of his adjusted basis in his partnership interests.

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 herein 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 processing, transportation and marketing of natural resources, including 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 5% of our current gross income does not constitute qualifying income; however, this estimate could change from time to time. Based on and subject to this estimate, the factual representations made by us and a review of the applicable legal authorities, Vinson & Elkins L.L.P. is of the opinion that more than 90% of our current gross income constitutes qualifying income. The portion of our income that is qualifying income may change from time to time.

No ruling has been or will be sought from the IRS, and the IRS has made no determination as to our status or the status of our operating subsidiaries 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 Vinson & Elkins L.L.P. on such matters. It is the opinion of Vinson & Elkins L.L.P. that, based upon the Internal Revenue Code, the Treasury 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, Vinson & Elkins L.L.P. has relied on factual representations made by us, including:

(a) We have not elected nor will we elect to be treated as a corporation; and

(b) For each taxable year, more than 90% of our gross income has been and will be income that Vinson & Elkins L.L.P. has opined or will opine is “qualifying income” within the meaning of Section 7704(d) of the Internal Revenue Code.

We believe that these representations have been true in the past and expect that these representations will be true in the future.

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, in which case the IRS may also require us to make adjustments with respect to our unitholders or pay other amounts, 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 deemed 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.

If we were treated as an association 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 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 remainder of this section is based on Vinson & Elkins L.L.P.’s opinion that we will be classified as a partnership for federal income tax purposes.

Unitholder Status

Unitholders who become members of our company will be treated as partners of our company for federal income tax purposes. Also:

(a) assignees who have executed and delivered transfer applications, and are awaiting admission as members, and

(b) 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 partners of our company for federal income tax purposes.

As there is no direct or indirect controlling authority addressing the federal tax treatment of 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, the opinion of Vinson & Elkins L.L.P. 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 status as a partner with respect to those units for federal income tax purposes. Please read “— Tax Consequences of Unit Ownership — Treatment of Short Sales.”

Income, gain, loss, or deduction 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 appear to be fully taxable as ordinary income. These holders are urged to consult their own tax advisors with respect to the consequences of their status as partners in our company for federal income tax purposes.

Tax Consequences of Unit Ownership

Flow-Through of Taxable Income

We will not pay any federal income tax. Instead, each unitholder will be required to report on his income tax return his share of our income, gains, losses and deductions without regard to whether corresponding cash distributions are received by him. Consequently, we may allocate income to a unitholder even if he has not received a cash distribution. Each unitholder will be required to include in income his allocable share of our income, gain, loss and deduction for our taxable year ending with or within his taxable year. Our taxable year ends on December 31.

Treatment of Distributions

Distributions made by us to a unitholder generally will not be taxable to him for federal income tax purposes except to the extent the amount of any such cash distribution exceeds his tax basis in his common units immediately before the distribution. Cash distributions made by us to a unitholder in an amount in excess of his tax basis in his common units generally will be considered to be gain from the sale or exchange of those common units, taxable in accordance with the rules described under “— Disposition of Common Units” below. To the extent that cash distributions made by us cause a unitholder’s “at risk” amount to be less than zero at the end of any taxable year, he must recapture any losses deducted in previous years. Please read “— Limitations on Deductibility of Losses.”

Any reduction in a unitholder’s share of our liabilities for which no partner bears the economic risk of loss, known as “non-recourse liabilities,” will be treated as a distribution of cash to that unitholder. A decrease in a unitholder’s percentage interest in us because of our issuance of additional common units will decrease his share of our nonrecourse liabilities and thus will result in a corresponding deemed distribution of cash, which may constitute a non-pro rata distribution. A non-pro rata distribution of money or property may result in ordinary income to a unitholder, regardless of his tax basis in his common units, if the distribution reduces the unitholder’s share of our “unrealized receivables,” including depreciation recaptureand/or substantially appreciated “inventory items,” both as defined in Section 751 of the Internal Revenue Code, and collectively, “Section 751 Assets.” To that extent, he will be treated as having received his 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. This latter deemed exchange will generally result in the unitholder’s realization of ordinary income. That income will equal the excess of (1) the non-pro rata portion of that distribution over (2) the unitholder’s tax basis (generally zero) for the share of Section 751 Assets deemed relinquished in the exchange.

Basis of Common Units

A unitholder’s initial tax basis for his common units generally will be the amount he paid for the common units plus his share of our nonrecourse liabilities. That basis generally will be increased by his share of our income and by any increases in his share of our nonrecourse liabilities. That basis generally will be decreased, but not below zero, by distributions to him from us, by his share of our losses, by any decreases in his share of our nonrecourse liabilities and by his share of our expenditures that are not deductible in computing taxable income and are not required to be capitalized. A unitholder will have a share, generally based on his share of profits, of our nonrecourse liabilities. Please read “— Disposition of Common Units — Recognition of Gain or Loss.”

Limitations on Deductibility of Losses

The deduction by a unitholder of his share of our losses will be limited to the tax basis in his units and, in the case of an individual unitholder or a corporate unitholder, if more than 50% of the value of its stock is owned directly or indirectly by or for five or fewer individuals or certain 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 his 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 as a deduction in a later year to the extent that his at-risk amount is subsequently increased, provided such losses do not exceed the unitholder’s tax basis in his units. 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 his tax basis in his units, excluding any portion of that basis attributable to his share of our nonrecourse liabilities, reduced by any amount of money he borrows to acquire or hold his 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, or any portion of that basis representing amounts otherwise protected against loss because of a guarantee, stop loss agreement or other similar arrangement. 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 share of our nonrecourse liabilities.

In addition to the basis and at-risk limitations on the deductibility of losses, the passive loss limitations generally provide that individuals, estates, trusts and some closely-held corporations and personal service corporations are permitted to deduct losses from passive activities, which are generally defined as trade or business 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 investments in other publicly traded partnerships, or salary or active business income. Similarly, a unitholder’s share of our net income may not be offset by any other current or carryover losses from other passive activities, including those attributable to other publicly traded partnerships. Passive losses that are not deductible because they exceed a unitholder’s share of income we generate may be deducted in full when he disposes of his 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.

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.” Investment interest expense includes:


	•	interest on indebtedness properly allocable to property held for investment;

	•	our interest expense attributable 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 or qualified dividend income. The IRS has indicated that net passive income earned by a publicly traded partnership will be treated as investment income to its unitholders. In addition, the unitholder’s share of our portfolio income will be treated as investment income.

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 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 unitholder on whose behalf the payment was made. If the payment is made on behalf of a unitholder whose identity cannot be determined, we are authorized to treat the payment as a distribution to all current unitholders. We are authorized to amend the limited liability company 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 limited liability company 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 an individual unitholder in which event the unitholder would be required to file a claim in order to obtain a credit or refund.

Allocation of Income, Gain, Loss and Deduction

In general, if we have a net profit, our items of income, gain, loss and deduction will be allocated among the unitholders in accordance with their percentage interests in us. If we have a net loss for the entire year, that amount of loss will be allocated to the unitholders in accordance with their percentage interests in us to the extent of their positive capital accounts.

Specified items of our income, gain, loss and deduction will be allocated to account for the difference between the tax basis and fair market value of our assets at the time of an offering or certain other transactions, referred to in this discussion as “Contributed Property.” The effect of these allocations, referred to as Section 704(c) Allocations, to a unitholder acquiring common units in an offering will be essentially the same as if the tax basis of our assets were equal to their fair market value at the time of such offering. In the event we issue additional common units or engage in certain other transactions in the future, “reverse Section 704(c) Allocations,” similar to the Section 704(c) Allocations described above, will be made to all holders of partnership interests immediately prior to such other transactions to account for the difference between the “book” basis for purposes of maintaining capital accounts and the fair market value of all property held by us at the time of the future transaction. In addition, items of recapture income will be allocated to the extent possible to the unitholder 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 other 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.

An allocation of items of our income, gain, loss or deduction, other than an allocation required by the Internal Revenue Code to eliminate the difference between a partner’s “book” capital account, credited with the fair market value of Contributed Property, and “tax” capital account, credited with the tax basis of Contributed Property, referred to in this discussion as the “Book-Tax Disparity,” will generally be given effect for federal income tax purposes in determining a partner’s share of an item of income, gain, loss or deduction only if the allocation has substantial economic effect. In any other case, a partner’s share of an item will be determined on the basis of his interest in us, which will be determined by taking into account all the facts and circumstances, including:


	•	his relative contributions to us;

	•	the interests of all the partners in profits and losses;

	•	the interest of all the partners in cash flow; and

	•	the rights of all the partners to distributions of capital upon liquidation.

Vinson & Elkins L.L.P. is of the opinion that, with the exception of the issues described in “— Tax Consequences of Unit Ownership — Section 754 Election” and “— Disposition of Common Units — Allocations Between Transferors and Transferees,” allocations under our limited liability company agreement will be given effect for federal income tax purposes in determining a unitholder’s share of an item of income, gain, loss or deduction.

Treatment of Short Sales


	•	any of our income, gain, loss or deduction with respect to those units would not be reportable by the unitholder;

	•	any cash distributions received by the unitholder as to those units would be fully taxable; and

	•	all of these distributions would appear to be ordinary income.

Vinson & Elkins L.L.P. has not rendered an opinion regarding the tax treatment of a unitholder whose common units are loaned to a short seller to cover a short sale of units; therefore, unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to modify any applicable brokerage account agreements to prohibit their brokers from borrowing and loaning their units. The IRS has announced that it is studying issues relating to the tax treatment of short sales of partnership interests. Please also read “— Disposition of Common Units — Recognition of Gain or Loss.”

Alternative Minimum Tax

Each unitholder will be required to take into account his distributive share of any items of our income, gain, loss or deduction for purposes of the alternative minimum tax. The current minimum tax rate for non-corporate taxpayers is 26% on the first $175,000 of alternative minimum taxable income in excess of the exemption amount and 28% on any additional alternative minimum taxable income. Prospective unitholders are urged to consult with their tax advisors as to the impact of an investment in our units on their liability for the alternative minimum tax.

Tax Rates

Under current law, the highest marginal U.S. federal income tax rate applicable to ordinary income of individuals is 35% and the highest marginal U.S. federal income tax rate applicable to long-term capital gains (generally, capital gains on certain assets held for more than 12 months) of individuals is 15%. However, absent new legislation extending the current rates, beginning January 1, 2011, the highest marginal U.S. federal income tax rate applicable to ordinary income and long-term capital gains of individuals will increase to 39.6% and 20%, respectively. Moreover, these rates are subject to change by new legislation at any time.

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. That election will generally permit us to adjust a common unit purchaser’s tax basis in our assets (“inside basis”) under Section 743(b) of the Internal Revenue Code to reflect his purchase price. The Section 743(b) adjustment does not apply to a person who purchases common units directly from us, and it belongs only to the purchaser and not to other unitholders. Please also read, however, “— Allocation of Income, Gain, Loss and Deduction” above. For purposes of this discussion, a unitholder’s inside basis in our assets will be considered to have two components: (1) his share of our tax basis in our assets (“common basis”) and (2) his Section 743(b) adjustment to that basis.

Where the remedial allocation method is adopted (which we have adopted as to all of our properties), the Treasury Regulations under Section 743 of the Internal Revenue Code require a portion of the Section 743(b) adjustment that is attributable to recovery property subject to depreciation under Section 168 of the Internal Revenue Code whose book basis is in excess of its tax basis to be depreciated over the remaining cost recovery period for the property’s unamortized Book-Tax Disparity. Under TreasuryRegulation Section 1.167(c)-1(a)(6), a Section 743(b) 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. If we elect a method other than the remedial method, the depreciation and amortization methods and useful lives associated with the Section 743(b) adjustment, therefore, may differ from the methods and useful lives generally used to depreciate the inside basis in such properties. Under our limited liability company agreement, our Board of Directors is authorized to take a position to preserve the uniformity of units even if that position is not consistent with these and any other Treasury Regulations. Please read “— Uniformity of Units.”

Although Vinson & Elkins L.L.P. is unable to opine as to the validity of this approach because there is no direct or indirect controlling authority on this issue, we intend to depreciate the portion of a Section 743(b) adjustment attributable to unrealized appreciation in the value of Contributed Property, 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 property’s unamortized Book-Tax Disparity, or treat that portion asnon-amortizable to the extent attributable to property of which is not amortizable. This method is consistent with the methods employed by other publicly traded partnerships but is arguably inconsistent with TreasuryRegulation Section 1.167(c)-1(a)(6), which is not expected to directly apply to a material portion of our assets and TreasuryRegulation Section 1.197-2(g)(3). To the extent this Section 743(b) adjustment is attributable to appreciation in value in excess of the unamortized Book-Tax Disparity, 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 take a depreciation or amortization position under which all purchasers acquiring units in the same month would receive depreciation or amortization, whether attributable to common basis or a Section 743(b) adjustment, based upon the same applicable

rate as if they had purchased a direct interest in our assets. This kind of aggregate approach may result in lower annual depreciation or amortization deductions than would otherwise be allowable to some unitholders. Please read “— Uniformity of Units.” A unitholder’s tax basis for his common units is reduced by his share of our deductions (whether or not such deductions were claimed on an individual’s income tax return) so that any position we take that understates deductions will overstate the common unitholder’s basis in his common units, which may cause the unitholder to understate gain or overstate loss on any sale of such units. Please read “— Disposition of Common Units — Recognition of Gain or Loss.” The IRS may challenge our position with respect to depreciating or amortizing the Section 743(b) adjustment we take to preserve the uniformity of the units. If such a challenge were sustained, the gain from the sale of units might be increased without the benefit of additional deductions.

A Section 754 election is advantageous if the transferee’s tax basis in his units is higher than the units’ share of the aggregate tax basis of our assets immediately prior to the transfer. In that case, as a result of the election, the transferee would have, among other items, a greater amount of depreciation deductions and his share of any gain or loss on a sale of our assets would be less. Conversely, a Section 754 election is disadvantageous if the transferee’s tax basis in his units is lower than those units’ share of the aggregate tax basis of our assets immediately prior to the transfer. Thus, the fair market value of the units may be affected either favorably or unfavorably by the election. A basis adjustment is required regardless of whether a Section 754 election is made in the case of a transfer of an interest in us if we have a substantial built — in loss immediately after the transfer, or if we distribute property and have a substantial basis reduction. Generally a built — in loss or a basis reduction is substantial if it exceeds $250,000.

The calculations involved in the Section 754 election are complex and will be made on the basis of assumptions as to the value of our assets and other matters. For example, 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 reallocate some or all of any Section 743(b) adjustment we allocated to our tangible assets to goodwill instead. Goodwill, as an intangible asset, is generally nonamortizable or amortizable over a longer period of time or under a less accelerated method than our tangible assets. We cannot assure you 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.

Tax Treatment of Operations

Accounting Method and Taxable Year

We will use the year ending December 31 as our taxable year and the accrual method of accounting for federal income tax purposes. Each unitholder will be required to include in income his share of our income, gain, loss and deduction for our taxable year ending within or with his 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 units following the close of our taxable year but before the close of his taxable year must include his share of our income, gain, loss and deduction in income for his taxable year, with the result that he will be required to include in income for his taxable year his share of more than one year of our income, gain, loss and deduction. Please read “— Disposition of Common Units — Allocations Between Transferors and Transferees.”

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 our assets and their tax basis immediately prior to an offering will be borne by our unitholders as of that time. Please read “— Tax Consequences of Unit Ownership — 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 may not be entitled to any

amortization deductions with respect to certain goodwill or properties held by us at the time of any future offering. Please read “— Uniformity of Units.” Property we subsequently acquire or construct may be 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 property we own will likely be required to recapture some or all of those deductions as ordinary income upon a sale of his interest in us. Please read “— Tax Consequences of Unit Ownership — Allocation of Income, Gain, Loss and Deduction” and “— Disposition of Common Units — Recognition of Gain or Loss.”

The costs incurred in selling our units (called “syndication expenses”) must be capitalized and cannot be deducted currently, ratably or upon our termination. There are uncertainties regarding the classification of costs as organization expenses, which we may amortize, and as syndication expenses, which we may not amortize. The underwriting discounts and commissions we incur will be treated as syndication expenses.

Valuation and Tax Basis of Our Properties

The federal income tax consequences of the ownership and disposition of units will depend in part on our estimates of the relative fair market values and the initial tax bases of our assets. Although we may from time to time consult with professional appraisers regarding valuation matters, we will make many of the relative fair market value estimates ourselves. These estimates and determinations of basis are subject to challenge and will not be binding on the IRS or the courts. If the estimates of fair market value or basis are later found to be incorrect, the character and amount of items of income, gain, loss or deduction 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 those adjustments.

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 for 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 he receives plus his 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 received is less than his original cost.

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 twelve months will generally be taxed at a maximum U.S. federal income tax rate of 15% through December 31, 2010 and 20% thereafter (absent new legislation extending or adjusting the current rate). However, a portion of this gain or loss, which may be substantial, however, will be separately computed and taxed as ordinary income or loss under Section 751 of the Internal Revenue Code to the extent attributable to assets giving rise to depreciation recapture or other “unrealized receivables” or “inventory items” that we own. The term “unrealized receivables” includes potential recapture items, including depreciation recapture. Ordinary income attributable to unrealized receivables, inventory items and depreciation recapture may exceed net taxable gain realized on the sale of a unit and may be recognized even if there is a net taxable loss realized on the sale of a unit. Thus, a unitholder may recognize both ordinary income and a capital loss upon a sale of units. Net capital loss may offset capital gains and 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 for all those interests. 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, which generally means that the tax basis allocated to the interest sold equals an amount that bears the same relation to the partner’s tax basis in his entire interest in the partnership as the value of the interest sold bears to the value of the partner’s entire interest in the partnership. Treasury Regulations under Section 1223 of the Internal Revenue Code allow a selling unitholder who can identify common units transferred with an ascertainable holding period to elect to use the actual holding period of the common units transferred. Thus, according to the ruling, a common unitholder will be unable to select high or low basis common units to sell as would be the case with corporate stock, but, according to the Treasury Regulations, may designate specific common units sold for purposes of determining the holding period of units transferred. A unitholder electing to use the actual holding period of common units transferred must consistently use that identification method for all subsequent sales or exchanges of common units. A unitholder considering the purchase of additional units or a sale of common units purchased in separate transactions is urged to consult his tax advisor as to the possible consequences of this ruling and those 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(s) 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 the 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

In general, our taxable income and losses will be determined annually, will be prorated on a monthly basis and will be subsequently apportioned among the unitholders in proportion to the number of units owned by each of them as of the opening of the applicable exchange on the first business day of the month (the “Allocation Date”). However, gain or loss realized on a sale or other disposition of our assets other than in the ordinary course of business will be allocated among the unitholders on the Allocation Date in 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 realized after the date of transfer.

Although simplifying conventions are contemplated by the Internal Revenue Code and most publicly traded partnerships use similar simplifying conventions, the use of this method may not be permitted under existing Treasury Regulations. Recently, however, the Department of the Treasury and the IRS issued proposed Treasury Regulations that provide a safe harbor pursuant to which a publicly traded partnership may use a similar monthly simplifying convention to allocate tax items among transferor and transferee unitholders, although such tax items must be prorated on a daily basis. Existing publicly traded partnerships are entitled to rely on these proposed Treasury Regulations; however, they are not binding on the IRS and are subject to change until final Treasury Regulations are issued. Accordingly, Vinson & Elkins L.L.P. is unable to opine on the validity of this method of allocating income and deductions between transferee and transferor unitholders. 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. We are authorized to revise our method of allocation between

transferee and transferor unitholders, as well as among unitholders whose interests vary during a taxable year, 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 prior to the record date set for a cash distribution for that quarter will be allocated items of our income, gain, loss and deductions attributable to that quarter but will not be entitled to receive that cash distribution.

Notification Requirements

A unitholder who sells any of his units is generally required to notify us in writing of that sale within 30 days after the sale (or, if earlier, January 15 of the year following the sale). A purchaser of units who purchases units from another unitholder is also generally required to notify us in writing of that purchase within 30 days after the purchase. Upon receiving such notifications, we are required to notify the IRS of that transaction and to furnish specified information to the transferor and transferee. Failure to notify us of a purchase may, in some cases, lead to the imposition of penalties. 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 who will satisfy such requirements.

Constructive Termination

We will be considered to have been terminated for tax purposes if there are sales and exchanges that, in the aggregate, constitute 50% or more of the total interests in our capital and profits within a twelve-month period. For purposes of measuring whether the 50% threshold is reached, multiple sales of the same unit are counted only once. A constructive termination results 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 may result in more than twelve months of our taxable income or loss being includable in his taxable income for the year of termination. A constructive termination occurring on a date other than December 31 will result in our filing two tax returns (and unitholders receiving two Schedules K-1) for one fiscal year, and the cost of the preparation of these returns will be borne by all unitholders. 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 would 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. The IRS has announced recently that it plans to issue guidance regarding the treatment of constructive terminations of publicly traded partnerships such as us. Any such guidance may change the application of the rules discussed above and may affect the tax treatment of a unitholder.

Uniformity of Units

Because we cannot match transferors and transferees of units, we must maintain uniformity of the economic and tax characteristics of the units to a purchaser of these units. In the absence of uniformity, we may be unable to completely comply with a number of federal income tax requirements, both statutory and regulatory. A lack of uniformity can result from a literal application of TreasuryRegulation Section 1.167(c)-1(a)(6) and TreasuryRegulation Section 1.197-2(g)(3). Any non-uniformity could have a negative impact on the value of the units. Please read “— Tax Consequences of Unit Ownership — Section 754 Election.”

We depreciate the portion of a Section 743(b) adjustment attributable to unrealized appreciation in the value of Contributed Property, 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 property’s unamortized Book-Tax Disparity, or treat that portion as nonamortizable, to the extent attributable to property the common basis of which is not amortizable, consistent with the Treasury Regulations under Section 743 of the Internal Revenue Code, even though that position may be inconsistent with TreasuryRegulation Section 1.167(c)-1(a)(6), which is not expected to directly apply to a material portion of our assets and TreasuryRegulation Section 1.197-2(g)(3). Please read “— Tax Consequences of Unit Ownership — Section 754 Election.” To the extent that the Section 743(b) adjustment is attributable to appreciation in value in excess of the unamortized

Book-Tax Disparity, 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 depreciation and amortization position under which all purchasers acquiring units in the same month would receive depreciation and amortization deductions, whether attributable to a common basis or Section 743(b) adjustment, based upon the same applicable methods and lives as if they had purchased a direct interest in our property. If this position is adopted, it may 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. This position will not be adopted if we determine that the loss of depreciation and amortization deductions will have a material adverse effect on the unitholders. If we choose not to utilize this aggregate method, we may use any other reasonable depreciation and amortization method to preserve the uniformity of the intrinsic tax characteristics of any units that would not have a material adverse effect on the unitholders. The IRS may challenge any method of depreciating the Section 743(b) adjustment described in this paragraph. If this challenge were 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. Please read “— Disposition of Common Units — Recognition of Gain or Loss.”

Tax-Exempt Organizations and Other Investors

Ownership of units by employee benefit plans, other tax-exempt organizations, non-resident aliens, foreign corporations, and other foreign persons raises issues unique to those investors and, as described below, may have substantially adverse tax consequences to them. If you are a tax-exempt entity or a foreign person, you should consult your tax advisor before investing in our units.

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. A significant portion of our income allocated to a unitholder that is a tax-exempt organization will be unrelated business taxable income and will be taxable to them.

Non-resident aliens and foreign corporations, trusts or estates that own units will be considered to be engaged in business in the United States because of the ownership of units. As a consequence they will be required to file federal tax returns to report their share of our income, gain, loss or deduction and pay federal income tax at regular rates on their share of our net income or gain. Under rules applicable to publicly traded partnerships, cash distributions made to foreign unitholders will be subject to withholding at the highest applicable effective tax rate. Each foreign unitholder must obtain a taxpayer identification number from the IRS and submit that number to our transfer agent on aForm W-8 BEN or applicable substitute form in order to obtain credit for these withholding taxes. A change in applicable law may require us to change these procedures.

In addition, 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 the United States branch profits tax at a rate of 30%, in addition to regular federal income tax, on its share of our income and gain, as adjusted for changes in the foreign corporation’s “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.

A foreign unitholder who sells or otherwise disposes of a unit will be subject to U.S. federal income tax on gain realized from the sale or disposition of that unit to the extent the gain is effectively connected with a U.S. trade or business of the foreign unitholder. Under a ruling published by the IRS, interpreting the scope of “effectively connected income,” a foreign unitholder would be considered to be engaged in a trade or business in the U.S. by virtue of the U.S. activities of the partnership, and part or all of that unitholder’s gain would be effectively connected with that unitholder’s indirect U.S. trade or business. Moreover, under the Foreign Investment in Real Property Tax Act, a foreign common unitholder generally will be subject to U.S. federal income tax upon the sale or disposition of a common unit if (i) he owned (directly or constructively applying certain attribution rules) more than 5% of our units at any time during the five-year period ending on the date of such disposition and (ii) 50% or more of the fair market value of all of our assets consisted of U.S. real property interests at any time during the shorter of the period

during which such unitholder held the common units or the5-year period ending on the date of disposition. Currently, more than 50% of our assets consist of U.S. real property interests and we do not expect that to change in the foreseeable future. Therefore, foreign unitholders may be subject to federal income tax on gain from the sale or disposition of their units.

Administrative Matters

Information Returns and Audit Procedures

We intend to furnish to each unitholder, within 90 days after the close of each calendar year, specific tax information, including aSchedule K-1, which describes his share of our income, gain, loss and deduction for our preceding taxable year. In preparing this information, which will not be reviewed by counsel, we will take various accounting and reporting positions, some of which have been mentioned earlier, to determine each unitholder’s share of income, gain, loss and deduction.

We cannot assure you that those positions will yield a result that conforms to the requirements of the Internal Revenue Code, Treasury Regulations or administrative interpretations of the IRS. Neither we nor counsel can assure prospective unitholders that the IRS will not successfully contend in court that those positions are impermissible. Any challenge by the IRS could negatively affect the value of the units.

The IRS may audit our federal income tax information returns. Adjustments resulting from an IRS audit may require each unitholder to adjust a prior year’s tax liability and possibly may result in an audit of his 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 requires that one partner be designated as the “Tax Matters Partner” for these purposes. We have appointed Copano Partners Trust as our Tax Matters Partner, subject to redetermination by our Board of Directors from time to time.

The Tax Matters Partner has made and 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 or by any group of unitholders having in the aggregate at least a 5% interest in profits. 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 this 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:

(a) the name, address and taxpayer identification number of the beneficial owner and the nominee;

(b) whether the beneficial owner is:

(1) a person that is not a United States person,

(2) a foreign government, an international organization or any wholly owned agency or instrumentality of either of the foregoing, or

(3) a tax-exempt entity;

(d) 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.

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.

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 any 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.

For individuals 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. The amount of any understatement subject to penalty generally is reduced if any portion is attributable to a position adopted on the return:

(1) for which there is, or was, “substantial authority,” or

(2) as to which there is a reasonable basis and the relevant facts of that position are disclosed on the return.

If any item of income, gain, loss or deduction included in the distributive shares of unitholders might result in that kind of an “understatement” of income for which no “substantial authority” exists, we must disclose the relevant 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 and take other actions as may be appropriate to permit unitholders 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.

A substantial valuation misstatement exists if (a) the value of any property, or the tax basis of any property, claimed on a tax return is 150% or more of the amount determined to be the correct amount of the valuation or tax basis, (b) the price for any property or services (or for the use of property) claimed on any such return with respect to any transaction between persons described in Internal Revenue Code Section 482 is 200% or more (or 50% or less) of the amount determined under Section 482 to be the correct amount of such price, or (c) the net Internal Revenue Code Section 482 transfer price adjustment for the taxable year exceeds the lesser of $5 million or 10% of the taxpayer’s gross receipts. No penalty is imposed unless the portion of the underpayment attributable to a substantial valuation misstatement exceeds $5,000 ($10,000 for a corporation other than an S Corporation or a personal holding company). The penalty is increased to 40% in the event of a gross valuation misstatement. We do not anticipate making any valuation misstatements.

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 tax avoidance transaction publicly identified by the IRS as a “listed transaction” or that it produces certain kinds of losses for partnerships, individuals, S corporations and trusts in excess of $2 million in any single year, or $4 million in any combination of six successive tax years. Our participation in a reportable transaction could increase the likelihood that our federal income tax information return

(and possibly your tax return) would be audited by the IRS. Please read “— 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 above 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.”

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 or in which you are a resident. We currently do business and own property in Texas, Oklahoma, Wyoming, Colorado and Louisiana. Although Texas and Wyoming do not currently impose a personal income tax, Oklahoma, Colorado and Louisiana do, and as we make acquisitions or expand our business, we may do business or own assets in other jurisdictions that impose a personal income tax. Although an analysis of those various taxes is not presented here, each prospective unitholder should consider their potential impact on his investment in us. You may not be required to file a return and pay taxes in some states because your income from that state falls below the filing and payment requirement. You will be required, however, to file state income tax returns and to pay state income taxes in many of the states in which we may do business or own property, and you 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. Please read “— Tax Consequences of Unit Ownership — Entity-Level Collections.” Based on current law and our estimate of our future operations, we anticipate 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 jurisdictions, of his investment in us. Accordingly, each prospective unitholder is urged to consult, and depend upon, his tax counsel or other advisor with regard to those matters. Further, it is the responsibility of each unitholder to file all state, local and foreign, as well as United States federal tax returns, that may be required of him. Vinson & Elkins L.L.P. has not rendered an opinion on the state, local or foreign tax consequences of an investment in us.

Tax Consequences of Ownership of Debt Securities

A description of the material federal income tax consequences of the acquisition, ownership and disposition of debt securities will be set forth on the prospectus supplement relating to the offering of debt securities.

LEGAL MATTERS

In connection with particular offerings of the securities in the future, and if stated in the applicable prospectus supplement, the validity of those securities may be passed upon for us by Vinson & Elkins L.L.P. and for any underwriters or agents by counsel named in the applicable prospectus supplement.

EXPERTS

The consolidated financial statements of Copano Energy, L.L.C. incorporated in this prospectus by reference from the Company’s Annual Report onForm 10-K for the year ended December 31, 2008 and the effectiveness of Copano Energy, L.L.C.’s internal control over financial reporting have been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their reports, which are incorporated herein by reference. Such financial statements have been so incorporated in reliance upon the reports of such firm given upon their authority as experts in accounting and auditing.

The financial statements of Bighorn Gas Gathering, L.L.C. as of December 31, 2007 and for the period from October 1, 2007 through December 31, 2007, incorporated in this prospectus by reference from Copano Energy, L.L.C.’s Annual Report onForm 10-K for the year ended December 31, 2008 have been audited by Deloitte & Touche LLP, independent auditors’, as stated in their report, which is incorporated herein by reference. Such financial statements have been so incorporated in reliance upon the report of such firm given upon their authority as experts in accounting and auditing.

PART II

INFORMATION NOT REQUIRED IN PROSPECTUS


Item 14.	*Other Expenses of Issuance and Distribution.*

Set forth below are the expenses (other than underwriting discounts and commissions) expected to be incurred in connection with the issuance and distribution of the securities registered hereby. With the exception of the Securities and Exchange Commission registration fee, the amounts set forth below are estimates.


SEC registration fee	$	*
Legal fees and expenses		**
Accounting fees and expenses		**
Trustee fees and expenses		**
Listing fees		***
Transfer and disbursement agent fees		**
Printing costs		**
Miscellaneous expenses		**

Total	$	**


*		Applicable SEC registration fees have been deferred in accordance with Rules 456(b) and 457(r) of the Securities Act and are not estimable at this time.

**		Because an indeterminate amount of securities is covered by this registration statement, the expenses in connection with the issuance and distribution of the securities are therefore not currently determinable.

***		The listing fee is based upon the principal amount of securities listed, if any, and is therefore not currently determinable.


Item 15.	*Indemnification of Directors and Officers.*

Copano Energy, L.L.C.

Section 18-108 of the Delaware Limited Liability Company Act provides that, subject to such standards and restrictions, if any, as are set forth in its limited liability company agreement, a limited liability company may, and shall have the power to, indemnify and hold harmless any member or manager or other person from and against any and all claims and demands whatsoever. Under our limited liability company agreement and subject to specified limitations, we will indemnify to the fullest extent permitted by law, from and against all losses, claims, damages or similar events any director or officer, or while serving as a director or officer, any person who is or was serving as a tax matters member or as a director, officer, tax matters member, employee, partner, manager, fiduciary or trustee of any or our affiliates. Additionally, we may indemnify from and against all losses, claims, damages or similar events any person who is or was an employee (other than an officer) or agent of our company to the extent permitted by law and authorized by our Board of Directors.

Any indemnification under our limited liability company agreement will only be out of our assets. We are authorized 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 our limited liability company agreement.

Additionally, we have entered into indemnification agreements with each of our directors and officers and the officers of each of our wholly owned subsidiaries, including Copano Energy Finance Corporation. The indemnification agreements provide each officer and director the maximum indemnification protection permitted under Delaware law with respect to actions taken in his or her capacity as a director or officer.

Any underwriting agreement entered into in connection with the sale of securities offered pursuant to this registration statement will provide for the indemnification of our officers and directors, including liabilities under the Securities Act.

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Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to directors, officers or persons controlling our company pursuant to the foregoing provisions, we have been informed that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act and is therefore unenforceable.

Copano Energy Finance Corporation

Section 145(a) of the General Corporation Law of the State of Delaware (the “DGCL”), in which Copano Energy Finance Corporation (“Copano Finance”) is incorporated, provides that a corporation may indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action, suit or proceeding, whether civil, criminal, administrative or investigative (other than an action by or in the right of the corporation) by reason of the fact that the person is or was a director, officer, employee or agent of the corporation, or is or was serving at the request of the corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement actually and reasonably incurred by the person in connection with such action, suit or proceeding if the person acted in good faith and in a manner the person reasonably believed to be in or not opposed to the best interests of the corporation, and, with respect to any criminal action or proceeding, had no reasonable cause to believe the person’s conduct was unlawful. Section 145(b) of the DGCL provides that a corporation may indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action or suit by or in the right of the corporation to procure a judgment in its favor by reason of the fact that the person is or was a director, officer, employee or agent of the corporation, or is or was serving at the request of the corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise against expenses (including attorneys’ fees) actually and reasonably incurred by the person in connection with the defense or settlement of such action or suit if the person acted in good faith and in a manner the person reasonably believed to be in or not opposed to the best interests of the corporation and except that no indemnification shall be made in respect of any claim, issue or matter as to which such person shall have been adjudged to be liable to the corporation unless and only to the extent that the Court of Chancery or the court in which such action or suit was brought shall determine upon application that, despite the adjudication of liability but in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses which the Court of Chancery or such other court shall deem proper. To the extent that a present or former director or officer of a corporation has been successful on the merits or otherwise in defense of any action, suit or proceeding referred to in subsections (a) and (b) of Section 145 of the DGCL, or in defense of any claim, issue or matter therein, such person shall be indemnified against expenses (including attorneys’ fees) actually and reasonably incurred by such person in connection therewith.

Any indemnification under subsections (a) and (b) of Section 145 of the DGCL (unless ordered by a court) shall be made by the corporation only as authorized in the specific case upon a determination that indemnification of the present or former director, officer, employee or agent is proper in the circumstances because the person has met the applicable standard of conduct set forth in subsections (a) and (b) of Section 145. Such determination shall be made, with respect to a person who is a director or officer at the time of such determination, (1) by a majority vote of the directors who are not parties to such action, suit or proceeding, even though less than a quorum, or (2) by a committee of such directors designated by majority vote of such directors, even though less than a quorum, or (3) if there are no such directors, or if such directors so direct, by independent legal counsel in a written opinion, or (4) by the stockholders. Expenses (including attorneys’ fees) incurred by an officer or director in defending any civil, criminal, administrative or investigative action, suit or proceeding may be paid by the corporation in advance of the final disposition of such action, suit or proceeding upon receipt of an undertaking by or on behalf of such director or officer to repay such amount if it shall ultimately be determined that such person is not entitled to be indemnified by the corporation as authorized in this section. Such expenses (including attorneys’ fees) incurred by former directors and officers or other employees and agents may be so paid upon such terms and conditions, if any, as the corporation deems appropriate. The indemnification and advancement of expenses provided by, or granted pursuant to, Section 145 shall not be deemed exclusive of any other rights to which those seeking indemnification or advancement of expenses may be entitled under any bylaw, agreement, vote of stockholders or disinterested directors or otherwise, both as to action in such person’s official capacity and as to action in another capacity while holding such office.

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Section 145 of the DGCL also empowers a corporation to purchase and maintain insurance on behalf of any person who is or was a director, officer, employee or agent of the corporation, or is or was serving at the request of the corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise against any liability asserted against such person and incurred by such person in any such capacity, or arising out of such person’s status as such, whether or not the corporation would have the power to indemnify such person against such liability under Section 145.

Copano Finance’s Certificate of Incorporation provides that directors, officers, employees and agents shall be indemnified to the fullest extent permitted by Section 145 of the DGCL.

Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to directors, officers or persons controlling Copano Finance pursuant to the foregoing provisions, Copano Finance has been informed that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act and is therefore unenforceable.


Item 16.	*Exhibits.*


Exhibit
Number			Description

	*1	.1	Form of Underwriting Agreement.
	3	.1	Certificate of Formation of Copano Energy Holdings, L.L.C. (now Copano Energy, L.L.C.) (incorporated by reference to Exhibit 3.1 to Registration Statement onForm S-1 filed July 30, 2004).
	3	.2	Certificate of Amendment to Certificate of Formation of Copano Energy Holdings, L.L.C. (now Copano Energy, L.L.C.) (incorporated by reference to Exhibit 3.2 to Registration Statement onForm S-1 filed July 30, 2004).
	3	.3	Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed April 30, 2007).
	3	.4	Amendment No. 1 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed May 4, 2007).
	3	.5	Amendment No. 2 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. dated October 19, 2007 (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed October 25, 2007).
	3	.6	Amendment No. 3 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C., dated October 19, 2007 (incorporated by reference to Exhibit 3.2 to Current Report onForm 8-K filed October 25, 2007).
	4	.1	Form of Senior Indenture.
	*4	.2	Form of Senior Debt Security.
	4	.3	Form of Subordinated Indenture.
	*4	.4	Form of Subordinated Debt Security.
	4	.5	Indenture dated as of February 7, 2006, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Guarantors parties thereto and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed February 8, 2006).
	4	.6	Form of Global Note representing 8.125% Senior Notes due 2016 (incorporated by reference to the Rule 144A/Regulation S Appendix of Exhibit 4.5 hereto).
	4	.7	Registration Rights Agreement by and between Copano Energy, L.L.C. and Cantera Resources Holdings LLC, dated October 19, 2007 (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed October 25, 2007).
	4	.8	Indenture, dated May 16, 2008, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Subsidiary Guarantors named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed May 19, 2008).
	4	.9	Form of Global Note representing 7.75% Senior Notes due 2018 (incorporated by reference to the Rule 144A/Regulation S Appendix to Exhibit 4.8 hereto).

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Exhibit
Number			Description

	4	.10	Registration Rights Agreement, dated May 16, 2008, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Subsidiary Guarantors named therein and the Initial Purchasers named therein (incorporated by reference to Exhibit 4.2 to Current Report onForm 8-K filed May 19, 2008).
	5	.1	Opinion of Vinson & Elkins L.L.P. as to the legality of the securities being registered.
	8	.1	Opinion of Vinson & Elkins L.L.P. as to certain tax matters.
	12	.1	Statement of Computation of Ratio of Earnings to Fixed Charges.
	21	.1	List of Subsidiaries.
	23	.1	Consent of Deloitte & Touche LLP.
	23	.2	Consent of Vinson & Elkins L.L.P. (contained in Exhibits 5.1 and 8.1).
	24	.1	Powers of Attorney (included on signature pages of this registration statement).
	**25	.1	Form T-1 Statement of Eligibility and Qualification under the Trust Indenture Act of 1939 of the Trustee under the Senior Indenture.
	**25	.2	Form T-1 Statement of Eligibility and Qualification under the Trust Indenture Act of 1939 of the Trustee under the Subordinated Indenture.


*		To be filed by amendment or as an exhibit to a Current Report onForm 8-K of the registrant.

**		To be filed in accordance with Section 310(a) of the Trust Indenture Act of 1939, as amended.


Item 17.	*Undertakings.*

(a) Each undersigned registrant hereby undertakes:

(1) To file, during any period in which offers or sales are being made, a post-effective amendment to this registration statement:

(i) To include any prospectus required by Section 10(a)(3) of the Securities Act of 1933;

(ii) To reflect in the prospectus any facts or events arising after the effective date of the registration statement (or the most recent post-effective amendment thereof) which, individually or in the aggregate, represent a fundamental change in the information set forth in the registration statement. Notwithstanding the foregoing, any increase or decrease in volume of securities offered (if the total dollar value of securities offered would not exceed that which was registered) and any deviation from the low or high end of the estimated maximum offering range may be reflected in the form of prospectus filed with the Commission pursuant to Rule 424(b) if, in the aggregate, the changes in volume and price represent no more than a 20 percent change in the maximum aggregate offering price set forth in the “Calculation of Registration Fee” table in the effective registration statement; and

(iii) To include any material information with respect to the plan of distribution not previously disclosed in the registration statement or any material change to such information in the registration statement;

provided, however, that paragraphs (i), (ii) and (iii) above do not apply if the information required to be included in a post-effective amendment by those paragraphs is contained in reports filed with or furnished to the Commission by the registrant pursuant to Section 13 or Section 15(d) of the Exchange Act that are incorporated by reference in the registration statement, or is contained in a form of prospectus filed pursuant to Rule 424(b) that is part of the registration statement.

(2) That, for the purpose of determining any liability under the Securities Act of 1933, each such post-effective amendment shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

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(3) To remove from registration by means of a post-effective amendment any of the securities being registered which remain unsold at the termination of the offering.

(4) That, for the purpose of determining liability under the Securities Act of 1933 to any purchaser:

(i) Each prospectus filed by the registrants pursuant to Rule 424(b)(3)shall be deemed to be part of the registration statement as of the date the filed prospectus was deemed part of and included in the registration statement; and

(ii) Each prospectus required to be filed pursuant to Rule 424(b)(2), (b)(5) or (b)(7) as part of a registration statement in reliance on Rule 430B relating to an offering made pursuant to Rule 415(a)(1)(i), (vii) or (x) for the purpose of providing the information required by Section 10(a) of the Securities Act of 1933 shall be deemed to be part of and included in the registration statement as of the earlier of the date such form of prospectus is first used after effectiveness or the date of the first contract of sale of securities in the offering described in the prospectus. As provided in Rule 430B, for liability purposes of the issuer and any person that is at that date an underwriter, such date shall be deemed to be a new effective date of the registration statement relating to the securities in the registration statement to which the prospectus relates, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof. Provided, however, that no statement made in a registration statement or prospectus that is part of the registration statement or made in a document incorporated or deemed incorporated by reference into the registration statement or prospectus that is part of the registration statement will, as to a purchaser with a time of contract of sale prior to such effective date, supersede or modify any statement that was made in the registration statement or prospectus that was part of the registration statement or made in any such document immediately prior to such effective date.

(5) That, for the purpose of determining liability of the registrants under the Securities Act of 1933 to any purchaser in the initial distribution of the securities, each undersigned registrant undertakes that in a primary offering of securities of such undersigned registrant pursuant to this registration statement, regardless of the underwriting method used to sell the securities to the purchaser, if the securities are offered or sold to such purchaser by means of any of the following communications, such undersigned registrant will be a seller to the purchaser and will be considered to offer or sell such securities to such purchaser:

(i) Any preliminary prospectus or prospectus of such undersigned registrant relating to the offering required to be filed pursuant to Rule 424;

(ii) Any free writing prospectus relating to the offering prepared by or on behalf of such undersigned registrant or used or referred to by such undersigned registrant;

(iii) The portion of any other free writing prospectus relating to the offering containing material information about such undersigned registrant or its securities provided by or on behalf of the undersigned registrant; and

(iv) Any other communication that is an offer in the offering made by such undersigned registrant to the purchaser.

(b) Each undersigned registrant hereby undertakes that, for purposes of determining any liability under the Securities Act of 1933, each filing of such registrant’s annual report pursuant to Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934 (and, where applicable, each filing of an employee benefit plan’s annual report pursuant to Section 15(d) of the Securities Exchange Act of 1934) that is incorporated by reference in the registration statement shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

(c) Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to directors, officers and controlling persons of the registrants pursuant to the foregoing provisions, or otherwise, the registrants have been advised that in the opinion of the Commission such indemnification is against public policy as expressed in the Securities Act of 1933 and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action, suit or proceeding) is asserted by such

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director, officer or controlling person in connection with the securities being registered, each registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities Act of 1933 and will be governed by the final adjudication of such issue.

(d) Each undersigned registrant hereby undertakes to file an application for the purpose of determining the eligibility of the trustee to act under subsection (a) of Section 310 of the Trust Indenture Act of 1939 (the “Trust Indenture Act”) in accordance with the rules and regulations prescribed by the Commission under Section 305(b)(2) of the Trust Indenture Act.

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SIGNATURES

Pursuant to the requirements of the Securities Act of 1933, the registrant certifies that it has reasonable grounds to believe that it meets all of the requirements for filing onForm S-3 and has duly caused this registration statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Houston, State of Texas, on November 2, 2009.

COPANO ENERGY, L.L.C.


	By:	/s/ John R. Eckel, Jr.

Name: John R. Eckel, Jr.


	Title:	Chairman of the Board and Chief Executive Officer

Each person whose signature appears below appoints John R. Eckel, Jr., Carl A. Luna and Douglas L. Lawing, and each of them, any of whom may act without the joinder of the other, as his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this registration statement and any registration statement (including any amendment thereto) for this offering that is to be effective upon filing pursuant to Rule 462(b) under the Securities Act of 1933, as amended, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or would do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them of their or his substitute and substitutes, may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman of the Board and Chief Executive Officer (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

/s/ James G. Crump James G. Crump	Director	November 2, 2009

/s/ Ernie L. Danner Ernie L. Danner	Director	November 2, 2009

/s/ Scott A. Griffiths Scott A. Griffiths	Director	November 2, 2009

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Signature	Title	Date


/s/ Michael L. Johnson Michael L. Johnson	Director	November 2, 2009

/s/ T. William Porter T. William Porter	Director	November 2, 2009

/s/ William L. Thacker William L. Thacker	Director	November 2, 2009

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SIGNATURES

COPANO ENERGY FINANCE CORPORATION


	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman and Chief Executive Officer (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Director	November 2, 2009

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SIGNATURES

Pursuant to the requirements of the Securities Act of 1933, each registrant certifies that it has reasonable grounds to believe that it meets all of the requirements for filing onForm S-3 and has duly caused this registration statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Houston, State of Texas, on November 2, 2009.

COPANO PIPELINES GROUP, L.L.C.
COPANO ENERGY SERVICES GP, L.L.C.
COPANO ENERGY SERVICES (TEXAS) GP, L.L.C.
COPANO FIELD SERVICES GP, L.L.C.
COPANO FIELD SERVICES/CENTRAL GULF COAST GP, L.L.C.
COPANO NGL SERVICES GP, L.L.C.
COPANO PIPELINES GP, L.L.C.
COPANO PIPELINES (TEXAS) GP, L.L.C.
COPANO PROCESSING GP, L.L.C.
COPANO NGL SERVICES (MARKHAM), L.L.C.
COPANO PIPELINES/NORTH TEXAS, L.L.C.
COPANO FIELD SERVICES/NORTH TEXAS, L.L.C.
ACP TEXAS, L.L.C.
ALAMO CREEK PROPERTIES, L.L.C.
RIVER VIEW PIPELINES, L.L.C.
CMW ENERGY SERVICES, L.L.C.
GREENWOOD GATHERING, L.L.C.
CPNO SERVICES GP, L.L.C.
COPANO/WEBB-DUVAL PIPELINE GP, L.L.C.
COPANO HOUSTON CENTRAL, L.L.C.
COPANO ENERGY/MID-CONTINENT, L.L.C.
SCISSORTAIL ENERGY, LLC
COPANO/RED RIVER GATHERING GP, L.L.C.
COPANO PIPELINES/TEXAS GULF COAST, L.L.C.
COPANO PIPELINES/VICTORIA, L.L.C.
COPANO PROCESSING/LOUISIANA, LLC
COPANO ENERGY/ROCKY MOUNTAINS, L.L.C.
COPANO PIPELINES/ROCKY MOUNTAINS, LLC
COPANO NATURAL GAS/ROCKY MOUNTAINS, LLC
COPANO FIELD SERVICES/ROCKY MOUNTAINS, LLC
COPANO FIELD FACILITIES/ROCKY MOUNTAINS, LLC
CANTERA GAS COMPANY LLC


	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

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pursuant to Rule 462(b) under the Securities Act of 1933, as amended, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or would do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them of their or his substitute and substitutes, may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager	November 2, 2009

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SIGNATURES

ESTES COVE FACILITIES, L.L.C.


	By:	Copano Field Services/Copano Bay, L.P., member

	By:	Copano Field Services GP, L.L.C., general partner of Copano Field Services/Copano Bay, L.P.

	By:	Copano Pipelines/South Texas, L.P., member

	By:	Copano Pipelines GP, L.L.C., general partner of Copano Pipelines/South Texas, L.P.

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of each of Copano Field Services GP, L.L.C. and Copano Pipelines GP, L.L.C. (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of each of Copano Field Services GP, L.L.C. and Copano Pipelines GP, L.L.C.	November 2, 2009

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SIGNATURES

NUECES GATHERING, L.L.C.


	By:	Copano Field Services/Agua Dulce, L.P., its sole member (the “Sole Member”)

	By:	Copano Field Services GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-13

SIGNATURES

COPANO PROCESSING, L.P.


	By:	Copano Processing GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-14

SIGNATURES

COPANO NGL SERVICES, L.P.


	By:	Copano NGL Services GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-15

SIGNATURES

CHC LP HOLDINGS, L.L.C.
COPANO/RED RIVER GATHERING LP HOLDINGS, L.L.C.
CPG LP HOLDINGS, L.L.C.
CWDPL LP HOLDINGS, L.L.C.
CPNO SERVICES LP HOLDINGS, L.L.C.


	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

/s/ Thomas M. Strauss Thomas M. Strauss	Manager	November 2, 2009

II-16

SIGNATURES

COPANO GENERAL PARTNERS, INC.


	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman and Chief Executive Officer (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer (Principal Accounting Officer)	November 2, 2009

II-17

SIGNATURES

COPANO FIELD SERVICES/AQUA DULCE, L.P.
COPANO FIELD SERVICES/COPANO BAY, L.P.
COPANO FIELD SERVICES/KARNES, L.P.
COPANO FIELD SERVICES/LIVE OAK, L.P.
COPANO FIELD SERVICES/SOUTH TEXAS, L.P.
COPANO FIELD SERVICES/UPPER GULF COAST, L.P.


	By:	Copano Field Services GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-18

SIGNATURES

COPANO PIPELINES/HEBBRONVILLE, L.P.
COPANO PIPELINES/SOUTH TEXAS, L.P.
COPANO PIPELINES/UPPER GULF COAST, L.P.


	BY:	Copano Pipelines GP, L.L.C., its general partner (the “General Partner”)


	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-19

SIGNATURES

COPANO PIPELINES/TGC, L.P.


	By:	Copano Pipelines (Texas) GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-20

SIGNATURES

COPANO FIELD SERVICES/CENTRAL GULF COAST, L.P.


	By:	Copano Field Services/Central Gulf Coast GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-21

SIGNATURES

COPANO ENERGY SERVICES/UPPER GULF COAST, L.P.


	By:	Copano Energy Services GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-22

SIGNATURES

COPANO ENERGY SERVICES/TEXAS GULF COAST, L.P.


	By:	Copano Energy Services (Texas) GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-23

SIGNATURES

COPANO/WEBB-DUVAL PIPELINE, L.P.


	By:	Copano/Webb-Duval Pipeline GP, L.L.C., its general partner

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-24

SIGNATURES

CPNO SERVICES, L.P.
COPANO RISK MANAGEMENT, L.P.


	By:	CPNO Services GP, L.L.C., its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-25

SIGNATURES

CIMMARRON GATHERING, LP


	By:	Copano/Red River Gathering GP, L.L.C. its general partner (the “General Partner”)

	By:	/s/ Carl A. Luna

Name: Carl A. Luna


	Title:	Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities and on the dates indicated.


Signature	Title	Date


/s/ John R. Eckel, Jr. John R. Eckel, Jr.	Chairman, Chief Executive Officer and Manager of the General Partner (Principal Executive Officer)	November 2, 2009

/s/ Carl A. Luna Carl A. Luna	Senior Vice President and Chief Financial Officer of the General Partner (Principal Financial Officer)	November 2, 2009

/s/ Lari Paradee Lari Paradee	Senior Vice President, Controller and Principal Accounting Officer of the General Partner (Principal Accounting Officer)	November 2, 2009

/s/ Douglas L. Lawing Douglas L. Lawing	Manager of the General Partner	November 2, 2009

II-26

INDEX TO EXHIBITS


Exhibit
Number			Description

	*1	.1	Form of Underwriting Agreement.
	3	.1	Certificate of Formation of Copano Energy Holdings, L.L.C. (now Copano Energy, L.L.C.) (incorporated by reference to Exhibit 3.1 to Registration Statement onForm S-1 filed July 30, 2004).
	3	.2	Certificate of Amendment to Certificate of Formation of Copano Energy Holdings, L.L.C. (now Copano Energy, L.L.C.) (incorporated by reference to Exhibit 3.2 to Registration Statement onForm S-1 filed July 30, 2004).
	3	.3	Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed April 30, 2007).
	3	.4	Amendment No. 1 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed May 4, 2007).
	3	.5	Amendment No. 2 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C. dated October 19, 2007 (incorporated by reference to Exhibit 3.1 to Current Report onForm 8-K filed October 25, 2007).
	3	.6	Amendment No. 3 to Third Amended and Restated Limited Liability Company Agreement of Copano Energy, L.L.C., dated October 19, 2007 (incorporated by reference to Exhibit 3.2 to Current Report onForm 8-K filed October 25, 2007).
	4	.1	Form of Senior Indenture.
	*4	.2	Form of Senior Debt Security.
	4	.3	Form of Subordinated Indenture.
	*4	.4	Form of Subordinated Debt Security.
	4	.5	Indenture dated as of February 7, 2006, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Guarantors parties thereto and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed February 8, 2006).
	4	.6	Form of Global Note representing 8.125% Senior Notes due 2016 (incorporated by reference to the Rule 144A/Regulation S Appendix of Exhibit 4.5 hereto).
	4	.7	Registration Rights Agreement by and between Copano Energy, L.L.C. and Cantera Resources Holdings LLC, dated October 19, 2007 (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed October 25, 2007).
	4	.8	Indenture, dated May 16, 2008, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Subsidiary Guarantors named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to Current Report onForm 8-K filed May 19, 2008).
	4	.9	Form of Global Note representing 7.75% Senior Notes due 2018 (incorporated by reference to the Rule 144A/Regulation S Appendix to Exhibit 4.8 hereto).
	4	.10	Registration Rights Agreement, dated May 16, 2008, among Copano Energy, L.L.C., Copano Energy Finance Corporation, the Subsidiary Guarantors named therein and the Initial Purchasers named therein (incorporated by reference to Exhibit 4.2 to Current Report onForm 8-K filed May 19, 2008).
	5	.1	Opinion of Vinson & Elkins L.L.P. as to the legality of the securities being registered.
	8	.1	Opinion of Vinson & Elkins L.L.P. as to certain tax matters.
	12	.1	Statement of Computation of Ratio of Earnings to Fixed Charges.
	21	.1	List of Subsidiaries.
	23	.1	Consent of Deloitte & Touche LLP.
	23	.2	Consent of Vinson & Elkins L.L.P. (contained in Exhibits 5.1 and 8.1).
	24	.1	Powers of Attorney (included on signature pages of this registration statement).
	**25	.1	Form T-1 Statement of Eligibility and Qualification under the Trust Indenture Act of 1939 of the Trustee under the Senior Indenture.
	**25	.2	Form T-1 Statement of Eligibility and Qualification under the Trust Indenture Act of 1939 of the Trustee under the Subordinated Indenture.


*		To be filed by amendment or as an exhibit to a Current Report onForm 8-K of the registrant.

**		To be filed in accordance with Section 310(a) of the Trust Indenture Act of 1939, as amended.

Copano Field Services/South Texas S-3ASRAutomatic shelf registration