As filed with the Securities and Exchange Commission on August 3, 2011

Registration No. 333-174225

 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

 

 

 

 

Amendment No. 5
to

Form S-1

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

 

 

 

 

 

 

Copies to:

 

 

 

 

Approximate date of commencement of proposed sale to the public:  As soon as practicable after this Registration Statement becomes effective.

 

 

 

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, check the following box.  o

 

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 post-effective amendment filed pursuant to Rule 462(d) 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

 

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” in Rule 12b-2 of the Exchange Act. (Check one):

 

(Do not check if a smaller reporting company)

 

 

 

 

The co-registrants hereby amend this Registration Statement on such date or dates as may be necessary to delay its effective date until the co-registrants shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until the Registration Statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.

 

 

Subject to Completion dated August 3, 2011

 

PROSPECTUS

 

 

13,200,000 Trust Units

 

 

 

This is the initial public offering of units of beneficial interest in Enduro Royalty Trust, or the “trust.” Enduro Sponsor (as defined in the “Prospectus Summary”) has formed the trust and, immediately prior to the closing of this offering, will convey, through the merger of a wholly owned subsidiary of Enduro Sponsor with the trust, a net profits interest in oil and natural gas properties (the “Net Profits Interest”) to the trust in exchange for 33,000,000 trust units. Enduro Sponsor is offering 13,200,000 trust units to be sold in this offering and will receive all of the proceeds derived therefrom. After the offering, Enduro Sponsor will own 19,800,000 trust units, or 17,820,000 trust units if the underwriters exercise their option to purchase additional trust units from Enduro Sponsor. No public market currently exists for the trust units. Enduro Sponsor is a privately-held limited liability company engaged in the production and development of oil and natural gas from properties located in Texas, Louisiana and New Mexico.

 

The trust units have been approved for listing on the New York Stock Exchange, subject to official notice of issuance, under the symbol “NDRO.”

 

Enduro Sponsor expects that the public offering price will be between $24.00 and $26.00 per trust unit.

 

The trust units.  Trust units are equity securities of the trust and represent undivided beneficial interests in the trust assets. They do not represent any interest in Enduro Sponsor.

 

The trust.  The trust will own the Net Profits Interest, which represents the right to receive 80% of the net profits from the sale of production from oil and natural gas properties in Texas, Louisiana and New Mexico, which are referred to as the “Underlying Properties,” held by Enduro Sponsor as of the date of the conveyance of the Net Profits Interest to the trust. Enduro Sponsor will retain the remaining 20% of the net profits from the sale of production from the Underlying Properties as of the date of the conveyance.

 

The trust unitholders.  As a trust unitholder, you will receive monthly distributions of cash from the proceeds that the trust receives from Enduro Sponsor pursuant to the Net Profits Interest. The trust’s ability to pay monthly cash distributions will depend on its receipt of net profits attributable to the Net Profits Interest, which will depend upon, among other things, volumes produced, wellhead prices, price differentials, production and development costs, potential reductions or suspensions of production and the amount and timing of trust administrative expenses.

 

Investing in the trust units involves a high degree of risk. Please read “Risk Factors” beginning on page 17 of this prospectus.

 

 

 

 

 

 

 

Enduro Sponsor has granted the underwriters a 30-day option to purchase up to an additional 1,980,000 trust units from it on the same terms and conditions set forth above if the underwriters sell more than 13,200,000 trust units in this offering.

 

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

 

Barclays Capital, on behalf of the underwriters, expects to deliver the trust units on or about          , 2011.

 

 

 

 

 

 

 

 

 

 

Prospectus dated          , 2011

 

 

 

TABLE OF CONTENTS

 

 

Important Notice About Information in This Prospectus

 

Enduro Sponsor and the trust have not, and the underwriters have not, authorized anyone to provide you with additional or different information. If anyone provides you with additional, different or inconsistent information, you should not rely on it. This prospectus is not an offer to sell or a solicitation of an offer to buy the trust units in any jurisdiction where such offer and sale would be unlawful. You should not assume that the information contained in this prospectus is accurate as of any date other than the date on the front of this document. The trust’s business, financial condition, results of operations and prospects may have changed since such date.

		Underlying Properties
																		Average Daily Net
		As of December 31, 2010																Production For Year
		Proved Reserves(1)																Ended December 31,				As of December 31,
		PV-10				Total								% Proved Developed				2010				2010
Operating Area		Value(2)				(MBoe)(3)				% Oil				Reserves				(Boe per day)				R/P Ratio(4)
		(In thousands)
Permian Basin		$	279,975				16,321				78	%			96	%			3,526				13
East Texas/North Louisiana			69,194				10,152				0	%			50	%			2,321				12
Total		$	349,169				26,473				48	%			79	%			5,847				12

(1)		In accordance with the rules and regulations promulgated by the SEC, the proved reserves presented above were determined using the twelve month unweighted arithmetic average of the first-day-of-the-month price for the period from January 1, 2010 through December 31, 2010, without giving effect to any hedge transactions, and were held constant for the life of the properties. This yielded a price for oil of $79.43 per Bbl and a price for natural gas of $4.37 per MMBtu.
(2)		PV-10 is the present value of estimated future net revenue to be generated from the production of proved reserves, discounted using an annual discount rate of 10%, calculated without deducting future income taxes. Standardized measure of discounted future net cash flows is calculated the same as PV-10 except that it deducts future income taxes and future abandonment costs. Because Enduro Sponsor bears no federal income tax expense and taxable income is passed through to the unitholders of the trust, no provision for federal or state income taxes is included in the reserve reports. PV-10 may not be considered a generally accepted accounting principle (“GAAP”) financial measure as defined by the SEC and is derived from the standardized measure of discounted future net cash flows, which is the most directly comparable GAAP financial measure. The pre-tax PV-10 value and the standardized measure of discounted future net cash flows do not purport to present the fair value of the oil and natural gas reserves attributable to the Underlying Properties.
(3)		Oil equivalents in the table are the sum of the Bbls of oil and the Boe of the stated Mcfs of natural gas, calculated on the basis that six Mcfs of natural gas are the energy equivalent of one Bbl of oil.
(4)		The R/P ratio, or the reserves-to-production ratio, is a measure of the number of years that a specified reserve base could support a fixed amount of production. This ratio is calculated by dividing total estimated proved reserves of the subject properties at the end of a period by annual total production for the prior 12 months. Because production rates naturally decline over time, the R/P ratio is not a useful estimate of how long properties should economically produce. Based on the reserve reports, economic production from the Underlying Properties is expected for at least 50 more years, except that economic production from the horizontal Haynesville Shale and Lower Cotton Valley wells is expected for 25 years.

								% of Total
				PV-10 at				PV-10 at
Field Name		Operator		December 31, 2010				December 31, 2010
				(In thousands)
Elm Grove Field		Petrohawk Energy Corporation(1), J-W Operating, Questar Corporation		$	54,275				16	%
North Monument Grayburg Unit		Apache Corporation			42,989				12	%
North Central Levelland Unit		Apache Corporation			39,208				11	%
North Cowden Unit		Occidental Permian Ltd.			32,563				9	%
Yates Field Unit		Kinder Morgan Inc.			18,052				5	%
Total				$	187,087				53	%

(1)		On July 14, 2011, BHP Billiton Ltd. announced it had entered into an agreement to acquire Petrohawk. Enduro Sponsor does not believe that the consummation of the acquisition will significantly affect Petrohawk’s operations on the Underlying Properties.

	•	Mature oil base combined with significant production and inventories of low risk natural gas locations. The Underlying Properties in the Permian Basin region include multiple

		mature oil fields currently using secondary and tertiary recovery methods. These fields typically are characterized by mature long-lived production profiles. Many of the Underlying Properties in the Permian Basin currently under waterflood have CO2 recovery potential, which could increase the ultimate oil recovered from these fields. The Underlying Properties located in the East Texas/North Louisiana region have significant natural gas production and near-term growth potential stemming primarily from the development of the Haynesville Shale and the horizontal Cotton Valley plays. Future increases in natural gas prices could accelerate development activity in this region, thereby increasing cash flows.

	•	Substantial proved developed reserves.  Proved developed reserves are the most valuable and lowest risk category of reserves because their production requires no significant future development expenses. As of December 31, 2010, approximately 79% of the volumes and 91% of the PV-10 value of the proved reserves associated with the Underlying Properties were attributed to proved developed reserves.
	•	Additional development opportunities.  Enduro Sponsor believes that the Underlying Properties are likely to offer economic development opportunities in the future that are not reflected in existing proved reserves and that could significantly increase future reserves and production. In the Permian Basin region, future increases in estimated oil recovery factors may increase reserves and production. Such increases in recovery factors may occur through, among other means, the implementation of additional enhanced recovery techniques, infill drilling and production outperformance. Examples of potential development opportunities not included in proved reserves in the East Texas/North Louisiana region include increased density drilling, refracs and development of prospective formations such as the Bossier Shale and Smackover, among others.
	•	Location in areas with significant histories of oil and natural gas production.  Long producing histories in the Permian Basin and East Texas/North Louisiana regions provide well established production profiles which increase certainty of production estimates. These regions also have significant access to oilfield services and pipeline takeaway infrastructure. In addition, Enduro Sponsor believes that operating risk is generally lower in regions accustomed to oil and natural gas production.
	•	Leading third party operators.  In the Permian Basin region, approximately 70% of the PV-10 value of the proved reserves is operated by Occidental Petroleum, Apache Corporation or Kinder Morgan, all of whom are among the top 10 producers in the basin by volume. These operators also have many years of experience in maximizing production response from mature oil and natural gas fields through enhanced recovery techniques. In the East Texas/North Louisiana region, approximately 85% of the PV-10 value of proved reserves is operated by Petrohawk Energy Corporation and EXCO Resources, Inc. These companies are two of the most active operators in the Haynesville Shale play and have significant operating experience in the region.
	•	Downside commodity price protection.  To mitigate the negative effects of a possible decline in oil and natural gas prices on distributable income to the trust, Enduro Sponsor has entered into hedge contracts with respect to approximately 69%, 70% and 57% of expected oil and natural gas production for 2011, 2012 and 2013, respectively, from the total proved reserves attributable to the Underlying Properties in the reserve reports. These hedge contracts include a combination of fixed price swaps, collars and floors to protect the trust’s downside, while still allowing the trust to participate in increasing oil and natural gas markets. After December 31, 2013, none of the production attributable to the Underlying Properties will be hedged.
	•	High Operating Margins.  The Underlying Properties have historically generated substantial operating margins. Lease operating expenses and property and other taxes on the Underlying Properties averaged $15.93 per Boe during the past three years. During the

		same period, the sales price for oil and natural gas averaged $52.65 per Boe, providing an operating margin of $36.72 per Boe, or 70%.

	•	Aligned interests of sponsor.  Immediately following the closing of this offering, Enduro Sponsor will have an effective ownership of approximately 68% of the net profits attributable to the sale of oil and natural gas produced from the Underlying Properties, including its retained 20% interest in the net profits from the sale of production from the Underlying Properties and its ownership of approximately 60% of the trust units.

	•	Enduro Sponsor will convey the Net Profits Interest to a wholly owned subsidiary of Enduro Sponsor through a merger. After this merger, the subsidiary will merge with the trust, thereby conveying the Net Profits Interest to the trust in exchange for 33,000,000 trust units in the aggregate, representing all of the outstanding trust units of the trust.

	•	Enduro Sponsor will sell 13,200,000 trust units offered hereby, representing an approximate 40% interest in the trust. Enduro Sponsor will also make available during the 30-day option period up to 1,980,000 trust units for the underwriters to purchase at the initial offering price to cover over-allotments. Enduro Sponsor intends to use the proceeds of the offering as disclosed under “Use of Proceeds.”

	•	Prices of oil and natural gas fluctuate, and lower prices could reduce proceeds to the trust and cash distributions to trust unitholders.
	•	Estimates of future cash distributions to trust unitholders are based on assumptions that are inherently subjective.
	•	Actual reserves and future production may be less than current estimates, which could reduce cash distributions by the trust and the value of the trust units.
	•	The Third Party Operators are the operators of approximately 99.3% of the wells on the Underlying Properties and, therefore, Enduro Sponsor is not in a position to control the timing of development efforts, the associated costs or the rate of production of the reserves on such properties.
	•	Developing oil and natural gas wells and producing oil and natural gas are costly and high-risk activities with many uncertainties that could adversely affect future production from the Underlying Properties. Any delays, reductions or cancellations in development and producing activities could decrease revenues that are available for distribution to trust unitholders.
	•	The trust is passive in nature and neither the trust nor the trust unitholders will have any ability to influence Enduro Sponsor or control the operations or development of the Underlying Properties.
	•	Shortages of equipment, services and qualified personnel could increase costs of developing and operating the Underlying Properties and result in a reduction in the amount of cash available for distribution to the trust unitholders.
	•	The trust units may lose value as a result of title deficiencies with respect to the Underlying Properties.
	•	Enduro Sponsor may transfer all or a portion of the Underlying Properties at any time without trust unitholder consent, subject to specified limitations.
	•	The reserves attributable to the Underlying Properties are depleting assets and production from those reserves will diminish over time. Furthermore, the trust is precluded from acquiring other oil and natural gas properties or net profits interests to replace the depleting assets and production. Therefore, proceeds to the trust and cash distributions to trust unitholders will decrease over time.
	•	An increase in the differential between the price realized by Enduro Sponsor for oil or natural gas produced from the Underlying Properties and the NYMEX or other benchmark price of oil or natural gas could reduce the profits to the trust and, therefore, the cash distributions by the trust and the value of trust units.
	•	The amount of cash available for distribution by the trust will be reduced by the amount of any costs and expenses related to the Underlying Properties and other costs and expenses incurred by the trust.
	•	The generation of profits for distribution by the trust depends in part on access to and operation of gathering, transportation and processing facilities. Any limitation in the availability of those facilities could interfere with sales of oil and natural gas production from the Underlying Properties.
	•	The trustee must, under certain circumstances, sell the Net Profits Interest and dissolve the trust prior to the expected termination of the trust. As a result, trust unitholders may not recover their investment.

	•	Enduro Sponsor may sell trust units in the public or private markets, and such sales could have an adverse impact on the trading price of the trust units.
	•	There has been no public market for the trust units.
	•	The trading price for the trust units may not reflect the value of the Net Profits Interest held by the trust.
	•	Conflicts of interest could arise between Enduro Sponsor and its affiliates, on the one hand, and the trust and the trust unitholders, on the other hand.
	•	The trust is managed by a trustee who cannot be replaced except by a majority vote of the trust unitholders at a special meeting, which may make it difficult for trust unitholders to remove or replace the trustee.
	•	Trust unitholders have limited ability to enforce provisions of the Net Profits Interest, and Enduro Sponsor’s liability to the trust is limited.
	•	Courts outside of Delaware may not recognize the limited liability of the trust unitholders provided under Delaware law.
	•	The operations of the Underlying Properties are subject to environmental laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations on them or result in significant costs and liabilities, which could reduce the amount of cash available for distribution to trust unitholders.
	•	The operations of the Underlying Properties are subject to complex federal, state, local and other laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations on them or expose the operator to significant liabilities, which could reduce the amount of cash available for distribution to trust unitholders.
	•	Climate change laws and regulations restricting emissions of “greenhouse gases” could result in increased operating costs and reduced demand for the oil and natural gas that the operators produce while the physical effects of climate change could disrupt their production and cause them to incur significant costs in preparing for or responding to those effects.
	•	Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays as well as adversely affect the services of the operators of the Underlying Properties.
	•	The bankruptcy of Enduro Sponsor or any of the Third Party Operators could impede the operation of the wells and the development of the proved undeveloped reserves.
	•	In the event of the bankruptcy of Enduro Sponsor, if a court held that the Net Profits Interest was part of the bankruptcy estate, the trust may be treated as an unsecured creditor with respect to the Net Profits Interest attributable to properties in Louisiana and New Mexico.
	•	Adverse developments in Texas, Louisiana or New Mexico could adversely impact the results of operations and cash flows of the Underlying Properties and reduce the amount of cash available for distributions to trust unitholders.
	•	The receipt of payments by Enduro Sponsor based on the hedge contracts depends upon the financial position of the hedge contract counterparties. A default by any of the hedge contract counterparties could reduce the amount of cash available for distribution to the trust unitholders.
	•	The tax treatment of an investment in trust units could be affected by recent and potential legislative changes, possibly on a retroactive basis.

	•	The trust has not requested a ruling from the Internal Revenue Service (the “IRS”) regarding the tax treatment of the trust. If the IRS were to determine (and be sustained in that determination) that the trust is not a “grantor trust” for federal income tax purposes, the trust could be subject to more complex and costly tax reporting requirements that could reduce the amount of cash available for distribution to trust unitholders.
	•	Certain U.S. federal income tax preferences currently available with respect to oil and natural gas production may be eliminated as a result of future legislation.
	•	You will be required to pay taxes on your share of the trust’s income even if you do not receive any cash distributions from the trust.
	•	A portion of any tax gain on the disposition of the trust units could be taxed as ordinary income.
	•	The trust will allocate its items of income, gain, loss and deduction between transferors and transferees of the trust units each month based upon the ownership of the trust units on the monthly record date, instead of on the basis of the date a particular trust unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among the trust unitholders.

		Three Months Ended				Year Ended
		March 31, 2011				December 31, 2010
		(In thousands)
		(Unaudited)
Revenues:
Oil		$	20,150			$	70,033
Natural gas			7,262				33,787
Total revenues		$	27,412			$	103,820
Direct operating expenses:
Lease operating		$	6,185			$	24,579
Gathering and processing			489				1,977
Production and other taxes			2,005				8,069
Total direct operating expenses		$	8,679			$	34,625
Excess of revenues over direct operating expenses		$	18,733			$	69,195

		Three Months Ended				Year Ended
		March 31, 2011				December 31, 2010
		(In thousands, except per unit data)
		(Unaudited)
Excess of revenues over direct operating expenses		$	18,733			$	69,195
Less development expenses			12,105				37,036
Excess of revenues over direct operating expenses and development expenses		$	6,628			$	32,159
Times Net Profits Interest			80	%			80	%
Income from Net Profits Interest		$	5,302			$	25,727
Pro forma adjustments:
Less estimated trust general and administrative expenses		$	213			$	850
Distributable income		$	5,089			$	24,877
Distributable income per trust unit		$	0.15			$	0.75

		Three Months Ended
		March 31,								Year Ended December 31,
		2011				2010				2010				2009				2008
										(Unaudited)
Operating Data:
Sales volumes:
Oil (MBbls)			230				239				939				1,016				1,084
Natural gas (MMcf)			1,619				1,768				7,171				8,455				8,868
Total sales (MBoe)			500				534				2,134				2,425				2,562
Average sales prices:
Oil (per Bbl)		$	87.61			$	72.61			$	74.58			$	54.44			$	98.52
Natural gas (per Mcf)			4.49				5.56				4.71				3.91				8.57
Average costs per Boe:
Lease operating		$	12.37			$	11.62			$	11.52			$	10.65			$	11.45
Gathering and processing			0.98				0.79				0.93				0.78				1.18
Production and other taxes			4.01				3.58				3.78				3.10				4.38
Capital expenditures (in thousands):
Property development costs		$	12,105			$	1,781			$	37,036			$	18,532			$	65,571

						Enduro
		Enduro				Sponsor
		Sponsor				Pro Forma								Enduro
		Pro Forma				as Adjusted								Sponsor
		for the				for the Offering								Pro Forma
		Acquisition				(Including the				Enduro				as Adjusted
		of the				Conveyance of				Sponsor				for the Offering
		Acquired				Net Profits				Pro Forma for the				(including the
		Properties				Interest)				Acquisition of the				Conveyance of the				Enduro Sponsor									Enduro Sponsor					Predecessor-DNR					Predecessor-EAC
		Three Months				Three Months				Acquired Properties				Net Profits Interest)				Three Months				Inception					Inception					March 9, 2010					January 1,
		Ended				Ended				Year Ended				Year Ended				Ended				Through					Through					Through					2010
		March 31,				March 31,				December 31,				December 31,				March 31,				March 31,					December 31,					November 30,					Through
		2011				2011				2010				2010				2011				2010					2010					2010					March 8, 2010
(In thousands)		(Unaudited)				(Unaudited)				(Unaudited)				(Unaudited)				(Unaudited)				(Unaudited)
Revenues		$	33,793			$	31,672			$	137,712			$	127,421			$	22,952			$	—				$	3,975				$	40,210				$	12,164
Net income (loss)		$	(9,559	)		$	(6,594	)		$	(8,645	)		$	2,957			$	(11,495	)		$	(77	)			$	(8,222	)			$	(19,515	)			$	(17,821	)
Total assets (at period end)						$	664,729											$	735,806			$	100				$	361,832				$	397,314				$	313,106
Long-term liabilities, excluding current maturities (at period end)						$	76,392											$	260,392			$	—				$	66,211				$	587				$	1,412
Members’ equity/owners’ equity						$	558,066											$	445,143			$	23				$	273,939				$	374,731				$	290,073

	•	the oil and natural gas production estimates for the twelve months ending April 30, 2012 contained in the reserve reports;
	•	estimated direct operating expenses and development expenses for the twelve months ending April 30, 2012 contained in the reserve reports;
	•	projected payments made or received pursuant to the hedge contracts for the twelve months ending June 30, 2012;
	•	estimated general and administrative expenses of $850,000 for the twelve months ending April 30, 2012; and
	•	an adjustment for the estimated production, revenue, operating expenses and development expenses (as adjusted to reflect that Enduro Sponsor has agreed to pay for $7.3 million of development expenses otherwise attributable to the trust) expected in the twelve months ending April 30, 2012 for drilling projects in the Haynesville Shale that are not included in the reserve reports.

		Projections for the Twelve
		Month Period Ending
Projected Cash Distributions to Trust Unitholders		September 30, 2012
		(In thousands,
		except per unit data)
Underlying Properties sales volumes:
Oil (MBbl)(1)			911
Natural gas (MMcf)			7,119
Total sales (MBoe)			2,097
Assumed NYMEX price(2):
Oil (per Bbl)		$	100.00
Natural gas (per MMBtu)			4.50
Assumed realized sales price(3):
Oil (per Bbl)		$	96.54
Natural gas (per Mcf)			4.63
Calculation of net profits:
Gross profits(4):
Oil sales		$	87,940
Natural gas sales			32,979
Total			120,919
Costs:
Direct operating expenses:
Lease operating expenses		$	23,489
Production and other taxes			9,225
Development expenses(5)			14,300
Total			47,014
Settlement of hedge contracts(6)			1,857
Net adjustment for additional projects(7)			(989	)
Net profits			74,773
Percentage allocable to Net Profits Interest			80%
Net profits to trust from Net Profits Interest		$	59,818
Trust general and administrative expenses(8)			850
Cash available for distribution by the trust		$	58,968
Cash distribution per trust unit (assumes 33,000,000 units)		$	1.79

(1)		Sales volumes for oil include 9 MBbls of NGLs.
(2)		For a description of the effect of lower NYMEX prices on projected cash distributions, please read “Projected Cash Distributions — Sensitivity of Projected Cash Distributions to Oil and Natural Gas Production and Prices.”

(3)		Sales price net of forecasted gravity, quality, transportation, gathering and processing and marketing costs. For more information about the estimates and hypothetical assumptions made in preparing the table above, see “Projected Cash Distributions — Significant Assumptions Used to Prepare the Projected Cash Distributions.”
(4)		Represents “gross profits” as described in “Computation of Net Profits.”
(5)		Does not include development expenses related to 21 gross (2.4 net) wells associated with development drilling projects in the Haynesville Shale. Please read footnote 7.
(6)		Reflects net cash impact of settlements of hedge contracts relating to production. See “The Underlying Properties — Hedge Contracts.”
(7)		Net adjustment for additional projects reflects the expected drilling of 21 gross (2.4 net) wells in the Haynesville Shale during the forecast period associated with development drilling projects not reflected in the reserve reports but for which notifications have been received by Enduro Sponsor as of June 2011. These additional development drilling projects are expected to increase total sales volumes by 221 MBoe, total gross profits by $3.3 million and total lease operating and development expenses and production and other taxes by $4.3 million, which is expected to result in a decrease in net profits for the Underlying Properties by $989,000 and cash available for distribution to the trust by $791,000. The amount of estimated development expenses has been adjusted to reflect the agreement by Enduro Sponsor to pay for up to $9.1 million (or $7.3 million attributable to the trust’s Net Profits Interest) of the total estimated development expenses of $12.4 million related to the 21 gross (2.4 net) wells, thereby reducing the trust’s share of development expenses associated with these wells to $2.6 million. In the absence of this payment obligation by Enduro Sponsor, the cash available for distribution to the trust would be reduced by an additional $7.3 million during the forecast period. Please read “Projected Cash Distributions — Significant Assumptions Used to Prepare the Projected Cash Distributions — Net adjustment for additional projects.”
(8)		Total general and administrative expenses of the trust on an annualized basis for the twelve months ending April 30, 2012 are expected to be $850,000 and will include the annual fees to the trustees, accounting fees, engineering fees, legal fees, printing costs and other expenses properly chargeable to the trust.

Trust units offered by Enduro Sponsor		13,200,000 trust units, or 15,180,000 trust units if the underwriters exercise their option to purchase additional trust units in full
Trust units owned by Enduro Sponsor after the offering		19,800,000 trust units, or 17,820,000 trust units if the underwriters exercise their option to purchase additional trust units in full
Trust units outstanding after the offering		33,000,000 trust units

Use of proceeds		Enduro Sponsor is offering all of the trust units to be sold in this offering, including the trust units to be sold upon any exercise of the underwriters’ option to purchase additional trust units. The estimated net proceeds of this offering to be received by Enduro Sponsor will be approximately $302.9 million, after deducting underwriting discounts and commissions, structuring fees and expenses, and $348.9 million if the underwriters exercise their option to purchase additional trust units in full. Enduro Sponsor intends to use the net proceeds from this offering, including any proceeds from the exercise of the underwriters’ option to purchase additional trust units, to repay approximately $184.0 million of the borrowings outstanding under its senior secured credit agreement and to make a distribution of approximately $20.0 million to its sole member, Enduro Resource Holdings LLC (“Enduro Holdings”). The remaining $98.9 million will be used to acquire additional oil and natural gas properties in the future for Enduro Sponsor (none of which have been identified). Enduro Sponsor is deemed to be an underwriter with respect to the trust units offered hereby. Please read “Use of Proceeds.” Affiliates of certain of the underwriters participating in this offering are lenders under Enduro Sponsor’s senior secured credit agreement and will receive a substantial portion of the proceeds from this offering pursuant to the repayment of a portion of the borrowings thereunder. Please read “Underwriting — FINRA Rules.”

Proposed NYSE symbol		“NDRO”
Monthly cash distributions		The trust will pay monthly distributions to the holders of trust units as of the applicable record date (generally the 15th day of each calendar month) on or before the 10th business day after the record date. The first distribution from the trust to the trust unitholders will be made on or about October 28, 2011 to trust unitholders owning trust units on or about October 14, 2011.
		Actual cash distributions to the trust unitholders will fluctuate monthly based upon the quantity of oil and natural gas produced from the Underlying Properties, the prices received for oil and natural gas production and other factors. Because

		payments to the trust will be generated by depleting assets with the production from the Underlying Properties diminishing over time, a portion of each distribution will represent, in effect, a return of your original investment. Oil and natural gas production from proved reserves attributable to the Underlying Properties is expected to decline over time. Please read “Risk Factors.”
Dissolution of the trust		The trust will dissolve upon the earliest to occur of the following: (1) the trust, upon approval of the holders of at least 75% of the outstanding trust units, sells the Net Profits Interest, (2) the annual cash available for distribution to the trust is less than $2 million for each of any two consecutive years, (3) the holders of at least 75% of the outstanding trust units vote in favor of dissolution or (4) the trust is judicially dissolved.
Estimated ratio of taxable income to distributions		Enduro Sponsor estimates that a trust unitholder who owns the trust units purchased in this offering through the record date for distribution for the period ending December 31, 2013, will recognize, on a cumulative basis, an amount of federal taxable income for that period of approximately 30% of the cash distributed to such trust unitholder with respect to that period. Please read “Federal Income Tax Consequences — U.S. Federal Income Tax Consequences — Direct Taxation of Trust Unitholders” for the basis of this estimate.
Summary of income tax consequences		Trust unitholders will be taxed directly on the income from assets of the trust. Enduro Sponsor and the trust intend to treat the Net Profits Interest, which will be granted to the trust on a perpetual basis, as a mineral royalty interest that generates ordinary income subject to depletion for U.S. federal income tax purposes. Please read “Federal Income Tax Consequences.”

 

Prices of oil and natural gas fluctuate, and lower prices could reduce proceeds to the trust and cash distributions to trust unitholders.

 

The trust’s reserves and monthly cash distributions are highly dependent upon the prices realized from the sale of oil and natural gas. Prices of oil and natural gas can fluctuate widely on a month-to-month basis in response to a variety of factors that are beyond the control of the trust and Enduro Sponsor. These factors include, among others:

 

 

Crude oil prices declined from record high levels in early July 2008 of over $140 per Bbl to below $45 per Bbl in February 2009 before rebounding to over $101 per Bbl in June 2011. Natural gas prices declined from over $13.57 per MMBtu in July 2008 to below $3.30 per MMBtu in October 2010 before rebounding to over $4.90 per MMBtu in June 2011.

 

Lower prices of oil and natural gas will reduce profits to which the trust is entitled and may ultimately reduce the amount of oil and natural gas that is economic to produce from the Underlying Properties. As a result, the operators of the Underlying Properties could determine during periods of low commodity prices to shut in or curtail production from wells on the Underlying Properties. In addition, the operators could determine during periods of low commodity prices to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Specifically, an operator may abandon any well or property if it reasonably believes that the well or property can no longer produce oil or natural gas in commercially paying quantities. This could result in termination of the Net Profits Interest relating to the abandoned well or property.

 

The Underlying Properties are sensitive to decreasing commodity prices. The commodity price sensitivity is due to a variety of factors that vary from well to well, including the costs associated with water handling and disposal, chemicals, surface equipment maintenance, downhole casing repairs and reservoir pressure maintenance activities that are necessary to maintain production. As a result, the volatility of commodity prices may cause the expenses of certain wells to exceed the well’s revenue. If this scenario were to occur, the operator may decide to shut-in the well or plug and abandon the well. This scenario could reduce future cash distributions to trust unitholders.

 

Enduro Sponsor has entered into hedge contracts with respect to approximately 69%, 70% and 57% of expected production of oil and natural gas production for 2011, 2012 and 2013, respectively, from the total proved reserves attributable to the Underlying Properties in the reserve reports. The

hedge contracts are intended to reduce exposure of the revenues from oil and natural gas production from the Underlying Properties to fluctuations in oil and natural gas prices and to achieve more predictable cash flow. Some of the hedge contracts could limit the benefit to the trust of any increase in oil or natural gas prices through 2013. The trust will be required to bear its share of the hedge payments regardless of whether the corresponding quantities of oil and natural gas are produced or sold. Furthermore, Enduro Sponsor has not entered into any hedge contracts relating to oil and natural gas volumes expected to be produced after 2013, and the terms of the conveyance of the Net Profits Interest will prohibit Enduro Sponsor from entering into new hedging arrangements burdening the trust following the completion of this offering. As a result, the amount of the cash distributions will be subject to a greater fluctuation after 2013 due to changes in oil and natural gas prices. For a discussion of the hedge contracts, please read “The Underlying Properties — Hedge Contracts.”

 

Estimates of future cash distributions to trust unitholders are based on assumptions that are inherently subjective.

 

The projected cash distributions to trust unitholders for the twelve months ending September 30, 2012 contained elsewhere in this prospectus are based on Enduro Sponsor’s calculations, and Enduro Sponsor has not received an opinion or report on such calculations from any independent accountants or engineers. Such calculations are based on assumptions about drilling, production, crude oil and natural gas prices, hedging activities, development expenses, and other matters that are inherently uncertain and are subject to significant business, economic, financial, legal, regulatory and competitive risks and uncertainties that could cause actual results to differ materially from those estimated. In particular, these estimates have assumed that crude oil and natural gas production is sold in 2011 and 2012 based on assumed NYMEX prices of $100.00 per Bbl in the case of crude oil and $4.50 per MMBtu in the case of natural gas. However, actual sales prices may be significantly lower. Additionally, these estimates assume the Underlying Properties will achieve production volumes set forth in the reserve reports; however, actual production volumes may be significantly lower. If prices or production are lower than expected, the amount of cash available for distribution to trust unitholders would be reduced. Furthermore, there have been an additional 21 gross (2.4 net) wells spud or proposed and approved by Enduro Sponsor in 2011 that are not represented in the reserve report because they would not be classified as proved locations but would rather be classified as probable locations based on the information available on December 31, 2010. Although Enduro Sponsor has agreed to pay up to $9.1 million of the development expenses associated with these wells incurred after May 1, 2011, Enduro Sponsor will not pay any amounts in excess of $9.1 million ($7.3 million attributable to the trust’s Net Profits Interest), even if future capital expenditures increase substantially. Thus, any additional drilling opportunities not reflected in the reserve reports could increase development expenses significantly without an immediate increase in production or revenues, which could decrease the amount of cash available for distribution to trust unitholders unless and until production and revenue from the new wells resulted in the recoupment of such expenses.

 

Actual reserves and future production may be less than current estimates, which could reduce cash distributions by the trust and the value of the trust units.

 

The value of the trust units and the amount of future cash distributions to the trust unitholders will depend upon, among other things, the accuracy of the reserves and future production estimated to be attributable to the trust’s interest in the Underlying Properties. Please read “The Underlying Properties — Reserve Reports” for a discussion of the method of allocating proved reserves to the Underlying Properties and the Net Profits Interest. It is not possible to measure underground accumulations of oil and natural gas in an exact way, and estimating reserves is inherently uncertain. Ultimately, actual production and revenues for the Underlying Properties could vary both positively and negatively and in material amounts from estimates. Furthermore, direct operating expenses and development expenses relating to the Underlying Properties could be substantially higher than current

estimates. Petroleum engineers are required to make subjective estimates of underground accumulations of oil and natural gas based on factors and assumptions that include:

 

 

Changes in these assumptions and amounts of actual direct operating expenses and development expenses could materially decrease reserve estimates. In addition, the quantities of recovered reserves attributable to the Underlying Properties may decrease in the future as a result of future decreases in the price of oil or natural gas.

 

The Third Party Operators are the operators of approximately 99.3% of the wells on the Underlying Properties and, therefore, Enduro Sponsor is not in a position to control the timing of development efforts, the associated costs or the rate of production of the reserves on such properties.

 

As of December 31, 2010, approximately 99.3% of the wells on the Underlying Properties were operated by the Third Party Operators. As a result, Enduro Sponsor has limited ability to exercise influence over, and control the risks or costs associated with, the operations of these properties. The failure of a Third Party Operator to adequately or efficiently perform operations, a Third Party Operator’s breach of the applicable operating agreements or a Third Party Operator’s failure to act in ways that are in Enduro Sponsor’s or the trust’s best interests could reduce production and revenues. Further, none of the Third Party Operators of the Underlying Properties are obligated to undertake any development activities, so any development and production activities will be subject to their reasonable discretion. The success and timing of drilling and development activities on properties operated by the Third Party Operators, therefore, depends on a number of factors that will be largely outside of Enduro Sponsor’s control, including:

 

 

The Third Party Operators may elect not to undertake development activities, or may undertake such activities in an unanticipated fashion, which may result in significant fluctuations in capital expenditures and amounts available for distribution to trust unitholders.

 

Developing oil and natural gas wells and producing oil and natural gas are costly and high-risk activities with many uncertainties that could adversely affect future production from the Underlying Properties. Any delays, reductions or cancellations in development and producing activities could decrease revenues that are available for distribution to trust unitholders.

 

The process of developing oil and natural gas wells and producing oil and natural gas on the Underlying Properties is subject to numerous risks beyond the trust’s, Enduro Sponsor’s and the Third Party Operators’ control, including risks that could delay the operators’ current drilling or production

schedule and the risk that drilling will not result in commercially viable oil or natural gas production. The ability of the operators to carry out operations or to finance planned development expenses could be materially and adversely affected by any factor that may curtail, delay, reduce or cancel development and production, including:

 

 

In the event that planned operations, including drilling of development wells, are delayed or cancelled, or existing wells or development wells have lower than anticipated production due to one or more of the factors above or for any other reason, estimated future distributions to trust unitholders may be reduced. In the event an operator incurs increased costs due to one or more of the above factors or for any other reason and is not able to recover such costs from insurance, the estimated future distributions to trust unitholders may be reduced.

 

The trust is passive in nature and neither the trust nor the trust unitholders will have any ability to influence Enduro Sponsor or control the operations or development of the Underlying Properties.

 

The trust units are a passive investment that entitle the trust unitholder to only receive cash distributions from the Net Profits Interest being conveyed to the trust by merger. Trust unitholders have no voting rights with respect to Enduro Sponsor and, therefore, will have no managerial, contractual or other ability to influence Enduro Sponsor’s or the Third Party Operators’ activities or the operations of the Underlying Properties. Oil and natural gas properties are typically managed pursuant to an operating agreement among the working interest owners of oil and natural gas properties. The Third Party Operators operate approximately 99.3% of the wells on the Underlying Properties. The typical operating agreement contains procedures whereby the owners of the working interests in the property designate one of the interest owners to be the operator of the property. Under these arrangements, the operator is typically

responsible for making all decisions relating to drilling activities, sale of production, compliance with regulatory requirements and other matters that affect the property.

 

Shortages of equipment, services and qualified personnel could increase costs of developing and operating the Underlying Properties and result in a reduction in the amount of cash available for distribution to the trust unitholders.

 

The demand for qualified and experienced personnel to conduct field operations, geologists, geophysicists, engineers and other professionals in the oil and natural gas industry can fluctuate significantly, often in correlation with oil and natural gas prices, causing periodic shortages. Historically, there have been shortages of drilling rigs and other equipment as demand for rigs and equipment has increased along with the number of wells being drilled. These factors also cause significant increases in costs for equipment, services and personnel. Higher oil and natural gas prices generally stimulate demand and result in increased prices for drilling rigs, crews and associated supplies, equipment and services. Shortages of field personnel and equipment or price increases could hinder the ability of the operators of the Underlying Properties to conduct the operations which they currently have planned for the Underlying Properties, which would reduce the amount of cash received by the trust and available for distribution to the trust unitholders.

 

The trust units may lose value as a result of title deficiencies with respect to the Underlying Properties.

 

Enduro Sponsor acquired the Underlying Properties through various acquisitions since December 2010. The existence of a material title deficiency with respect to the Underlying Properties could reduce the value of a property or render it worthless, thus adversely affecting the Net Profits Interest and the distributions to trust unitholders. Enduro Sponsor does not obtain title insurance covering mineral leaseholds, and Enduro Sponsor’s failure to cure any title defects may cause Enduro Sponsor to lose its rights to production from the Underlying Properties. In the event of any such material title problem, profits available for distribution to trust unitholders and the value of the trust units may be reduced.

 

Enduro Sponsor may transfer all or a portion of the Underlying Properties at any time without trust unitholder consent, subject to specified limitations.

 

Enduro Sponsor may at any time transfer all or part of the Underlying Properties, subject to and burdened by the Net Profits Interest, and may, along with the Third Party Operators, abandon individual wells or properties reasonably believed to be uneconomic. Trust unitholders will not be entitled to vote on any transfer or abandonment of the Underlying Properties, and the trust will not receive any profits from any such transfer, except in the limited circumstances when the Net Profits Interest is released in connection with such transfer, in which case the trust will receive an amount equal to the fair market value (net of sales costs) of the Net Profits Interest released. Please read “The Underlying Properties — Sale and Abandonment of Underlying Properties.” Following any sale or transfer of any of the Underlying Properties, if the Net Profits Interest is not released in connection with such sale or transfer, the Net Profits Interest will continue to burden the transferred property and net profits attributable to such property will be calculated as part of the computation of net profits described in this prospectus. Enduro Sponsor may delegate to the transferee responsibility for all of Enduro Sponsor’s obligations relating to the Net Profits Interest on the portion of the Underlying Properties transferred.

 

In addition, Enduro Sponsor may, without the consent of the trust unitholders, require the trust to release the Net Profits Interest associated with any lease that accounts for less than or equal to 0.25% of the total production from the Underlying Properties in the prior 12 months and provided that the Net Profits Interest covered by such releases cannot exceed, during any 12-month period, an aggregate fair market value to the trust of $500,000. These releases will be made only in connection with a sale by Enduro Sponsor of the relevant Underlying Properties and are conditioned upon an amount equal to the fair market value of such Net Profits Interest being treated as an offset amount against costs and expenses. Enduro Sponsor has not identified for sale any of the Underlying Properties.

The Third Party Operators and Enduro Sponsor may enter into farm-out, operating, participation and other similar agreements to develop the property without the consent or approval of the trustee or any trust unitholder.

 

The reserves attributable to the Underlying Properties are depleting assets and production from those reserves will diminish over time. Furthermore, the trust is precluded from acquiring other oil and natural gas properties or net profits interests to replace the depleting assets and production. Therefore, proceeds to the trust and cash distributions to trust unitholders will decrease over time.

 

The profits payable to the trust attributable to the Net Profits Interest are derived from the sale of production of oil and natural gas from the Underlying Properties. The reserves attributable to the Underlying Properties are depleting assets, which means that the reserves and the quantity of oil and natural gas produced from the Underlying Properties will decline over time. Based on the estimated production and operating expenses in the reserve report of the Underlying Properties, the oil and natural gas production from proved reserves attributable to the Underlying Properties is projected to be shallow declining over the next five years. Actual decline rates may vary from this projected decline rate. In the event expected future development is delayed, reduced or cancelled, the average rate of decline will likely exceed 9% per year.

 

Future maintenance projects on the Underlying Properties may affect the quantity of proved reserves that can be economically produced from wells on the Underlying Properties. The timing and size of these projects will depend on, among other factors, the market prices of oil and natural gas. Neither Enduro Sponsor nor, to Enduro Sponsor’s knowledge, the Third Party Operators have a contractual obligation to develop or otherwise pay development expenses on the Underlying Properties in the future. Enduro Sponsor, however, will have an obligation to pay up to $9.1 million of development expenses (or $7.3 million attributable to the trust’s 80% indirect interest in the Underlying Properties) for projects in the Haynesville Shale for which notifications have been received by Enduro Sponsor as of June 2011, and which are a part of Enduro Sponsor’s $37 million 2011 capital budget for the Underlying Properties. Furthermore, with respect to properties for which Enduro Sponsor is not designated as the operator, Enduro Sponsor has limited control over the timing or amount of those development expenses. Enduro Sponsor also has the right to non-consent and not participate in the development expenses on properties for which it is not the operator, in which case Enduro Sponsor and the trust will not receive the production resulting from such development expenses. If the operators of the Underlying Properties do not implement maintenance projects when warranted, the future rate of production decline of proved reserves may be higher than the rate currently expected by Enduro Sponsor or estimated in the reserve report.

 

The trust agreement will provide that the trust’s activities will be limited to owning the Net Profits Interest and any activity reasonably related to such ownership, including activities required or permitted by the terms of the conveyance related to the Net Profits Interest. As a result, the trust will not be permitted to acquire other oil and natural gas properties or net profits interests to replace the depleting assets and production attributable to the Net Profits Interest.

 

Because the net profits payable to the trust are derived from the sale of depleting assets, the portion of the distributions to trust unitholders attributable to depletion may be considered to have the effect of a return of capital as opposed to a return on investment. Eventually, the Underlying Properties burdened by the Net Profits Interest may cease to produce in commercially paying quantities and the trust may, therefore, cease to receive any distributions of net profits therefrom.

 

An increase in the differential between the price realized by Enduro Sponsor for oil or natural gas produced from the Underlying Properties and the NYMEX or other benchmark price of oil or natural gas could reduce the profits to the trust and, therefore, the cash distributions by the trust and the value of trust units.

 

The prices received for Enduro Sponsor’s oil and natural gas production usually fall below the relevant benchmark prices, such as NYMEX, that are used for calculating hedge positions. The difference

between the price received and the benchmark price is called a basis differential. The differential may vary significantly due to market conditions, the quality and location of production and other factors. Enduro Sponsor cannot accurately predict oil or natural gas differentials. Increases in the differential between the realized price of oil and natural gas and the benchmark price for oil and natural gas could reduce the profits to the trust, the cash distributions by the trust and the value of the trust units.

 

The amount of cash available for distribution by the trust will be reduced by the amount of any costs and expenses related to the Underlying Properties and other costs and expenses incurred by the trust.

 

The trust will indirectly bear an 80% share of all costs and expenses related to the Underlying Properties, such as direct operating expenses, development expenses and hedge expenses, which will reduce the amount of cash received by the trust and thereafter distributable to trust unitholders. Accordingly, higher costs and expenses related to the Underlying Properties will directly decrease the amount of cash received by the trust in respect of its Net Profits Interest. Please read “The Underlying Properties — Unaudited Pro Forma Combined Financial and Operating Data of the Underlying Properties.” Historical costs may not be indicative of future costs. For example, the Third Party Operators may in the future propose additional drilling projects that significantly increase the capital expenditures associated with the Underlying Properties, which could reduce cash available for distribution by the trust. In addition, cash available for distribution by the trust will be further reduced by the trust’s general and administrative expenses, which are expected to be approximately $850,000 for the twelve months ending April 30, 2012. For details about these general and administrative expenses, please read “Description of the Trust Agreement — Fees and Expenses.”

 

If direct operating expenses, development expenses and hedge expenses on the Underlying Properties together with the other costs exceed gross profits of production from the Underlying Properties, the trust will not receive net profits from those properties until future gross profits from production exceed the total of the excess costs, plus accrued interest at the prime rate. If the trust does not receive net profits pursuant to the Net Profits Interest, or if such net profits are reduced, the trust will not be able to distribute cash to the trust unitholders, or such cash distributions will be reduced, respectively. Development activities may not generate sufficient additional revenue to repay the costs.

 

The generation of profits for distribution by the trust depends in part on access to and operation of gathering, transportation and processing facilities. Any limitation in the availability of those facilities could interfere with sales of oil and natural gas production from the Underlying Properties.

 

The amount of oil and natural gas that may be produced and sold from a well is subject to curtailment in certain circumstances, such as by reason of weather conditions, pipeline interruptions due to scheduled and unscheduled maintenance, failure of tendered oil and natural gas to meet quality specifications of gathering lines or downstream transporters, excessive line pressure which prevents delivery, physical damage to the gathering system or transportation system or lack of contracted capacity on such systems. The curtailments may vary from a few days to several months. In many cases, the operators of the Underlying Properties are provided limited notice, if any, as to when production will be curtailed and the duration of such curtailments. If the operators of the Underlying Properties are forced to reduce production due to such a curtailment, the revenues of the trust and the amount of cash distributions to the trust unitholders would similarly be reduced due to the reduction of profits from the sale of production.

 

The trustee must, under certain circumstances, sell the Net Profits Interest and dissolve the trust prior to the expected termination of the trust. As a result, trust unitholders may not recover their investment.

 

The trustee must sell the Net Profits Interest and dissolve the trust if the holders of at least 75% of the outstanding trust units approve the sale or vote to dissolve the trust. The trustee must also sell the Net Profits Interest and dissolve the trust if the annual gross profits from the Underlying Properties attributable to the Net Profits Interest are less than $2 million for each of any two consecutive years. The net profits of any such sale will be distributed to the trust unitholders.

Enduro Sponsor may sell trust units in the public or private markets, and such sales could have an adverse impact on the trading price of the trust units.

 

After the closing of the offering, Enduro Sponsor will hold an aggregate of 19,800,000 trust units, assuming no exercise of the underwriters’ option to purchase additional trust units. Enduro Sponsor has agreed not to sell any trust units for a period of 180 days after the date of this prospectus without the consent of Barclays Capital Inc. Please read “Underwriting.” After such period, Enduro Sponsor may sell trust units in the public or private markets, and any such sales could have an adverse impact on the price of the trust units or on any trading market that may develop. The trust has granted registration rights to Enduro Sponsor, which, if exercised, would facilitate sales of trust units by Enduro Sponsor.

 

There has been no public market for the trust units.

 

The initial public offering price of the trust units will be determined by negotiation among Enduro Sponsor and the underwriters. Among the factors to be considered in determining the number of trust units to be offered hereby and the initial public offering price will be estimates of distributions to trust unitholders; overall quality of the oil and natural gas properties attributable to the Underlying Properties; the history and prospects for the energy industry; Enduro Sponsor’s financial information; the prevailing securities markets at the time of this offering and the recent market prices of, and the demand for, publicly traded units of royalty trusts. None of Enduro Sponsor, the trust or the underwriters will obtain any independent appraisal or other opinion of the value of the Net Profits Interest, other than the reserve report prepared by Cawley Gillespie.

 

The trading price for the trust units may not reflect the value of the Net Profits Interest held by the trust.

 

The trading price for publicly traded securities similar to the trust units tends to be tied to recent and expected levels of cash distributions. The amounts available for distribution by the trust will vary in response to numerous factors outside the control of the trust, including prevailing prices for sales of oil and natural gas production from the Underlying Properties and the timing and amount of direct operating expenses and development expenses. Consequently, the market price for the trust units may not necessarily be indicative of the value that the trust would realize if it sold the Net Profits Interest to a third-party buyer. In addition, such market price may not necessarily reflect the fact that since the assets of the trust are depleting assets, a portion of each cash distribution paid with respect to the trust units should be considered by investors as a return of capital, with the remainder being considered as a return on investment. As a result, distributions made to a trust unitholder over the life of these depleting assets may not equal or exceed the purchase price paid by the trust unitholder.

 

Conflicts of interest could arise between Enduro Sponsor and its affiliates, on the one hand, and the trust and the trust unitholders, on the other hand.

 

As working interest owners in, and the operators of certain wells on, the Underlying Properties, Enduro Sponsor and its affiliates could have interests that conflict with the interests of the trust and the trust unitholders. For example:

 

 

 

The trust is managed by a trustee who cannot be replaced except by a majority vote of the trust unitholders at a special meeting, which may make it difficult for trust unitholders to remove or replace the trustee.

 

The affairs of the trust will be managed by the trustee. Your voting rights as a trust unitholder are more limited than those of stockholders of most public corporations. For example, there is no requirement for annual meetings of trust unitholders or for an annual or other periodic re-election of the trustee. The trust agreement provides that the trustee may only be removed and replaced by the holders of a majority of the trust units present in person or by proxy at a meeting of such holders where a quorum is present, including trust units held by Enduro Sponsor, called by either the trustee or the holders of not less than 10% of the outstanding trust units. As a result, it will be difficult for public trust unitholders to remove or replace the trustee without the cooperation of Enduro Sponsor so long as it holds a significant percentage of total trust units.

 

Trust unitholders have limited ability to enforce provisions of the Net Profits Interest, and Enduro Sponsor’s liability to the trust is limited.

 

The trust agreement permits the trustee to sue Enduro Sponsor or any other future owner of the Underlying Properties to enforce the terms of the conveyance creating the Net Profits Interest. If the trustee does not take appropriate action to enforce provisions of the conveyance, trust unitholders’ recourse would be limited to bringing a lawsuit against the trustee to compel the trustee to take specified actions. The trust agreement expressly limits a trust unitholder’s ability to directly sue Enduro Sponsor or any other third party other than the trustee. As a result, trust unitholders will not be able to sue Enduro Sponsor or any future owner of the Underlying Properties to enforce these rights. Furthermore, the Net Profits Interest conveyance provides that, except as set forth in the conveyance, Enduro Sponsor will not be liable to the trust for the manner in which it performs its duties in operating the Underlying Properties as long as it acts without gross negligence or willful misconduct.

 

Courts outside of Delaware may not recognize the limited liability of the trust unitholders provided under Delaware law.

 

Under the Delaware Statutory Trust Act, trust unitholders will be entitled to the same limitation of personal liability extended to stockholders of corporations for profit under the General Corporation Law of the State of Delaware. No assurance can be given, however, that the courts in jurisdictions outside of Delaware will give effect to such limitation.

The operations of the Underlying Properties are subject to environmental laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations on them or result in significant costs and liabilities, which could reduce the amount of cash available for distribution to trust unitholders.

 

The oil and natural gas exploration and production operations on the Underlying Properties are subject to stringent and comprehensive federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may impose numerous obligations that apply to the operations on the Underlying Properties, including the requirement to obtain a permit before conducting drilling, waste disposal or other regulated activities; the restriction of types, quantities and concentrations of materials that can be released into the environment; the incurrence of significant development expenses to install pollution or safety-related controls at the operated facilities; the limitation or prohibition of drilling activities on certain lands lying within wilderness, wetlands and other protected areas; and the imposition of substantial liabilities for pollution resulting from operations. For example, the U.S. Environmental Protection Agency (“EPA”) has proposed regulations to impose more stringent emissions control requirements for oil and gas development and production operations, which may require us, our operators, or third-party contractors to incur additional expenses to control air emissions from current operations and during new well developments by installing emissions control technologies and adhering to a variety of work practice and other requirements. Any such requirements could increase the costs of development and production, reducing the profits available to the trust and potentially impairing the economic development of the Underlying Properties. Numerous governmental authorities, such as the EPA and analogous state agencies, have the power to enforce compliance with these laws and regulations and the permits issued under them, often times requiring difficult and costly actions. Failure to comply with these laws and regulations may result in the assessment of administrative, civil or criminal penalties; the imposition of investigatory or remedial obligations; and the issuance of injunctions limiting or preventing some or all of the operations on the Underlying Properties. Furthermore, the inability to comply with environmental laws and regulations in a cost-effective manner, such as removal and disposal of produced water and other generated oil and gas wastes, could impair the operators’ ability to produce oil and natural gas commercially from the Underlying Properties, which would reduce profits attributable to the Net Profits Interest.

 

There is inherent risk of incurring significant environmental costs and liabilities in the operations on the Underlying Properties as a result of the handling of petroleum hydrocarbons and wastes, air emissions and wastewater discharges related to operations, and historical industry operations and waste disposal practices. Under certain environmental laws and regulations, the operators could be subject to joint and several strict liability for the removal or remediation of previously released materials or property contamination regardless of whether such operators were responsible for the release or contamination or whether the operations were in compliance with all applicable laws at the time those actions were taken. Private parties, including the owners of properties upon which wells are drilled and facilities where petroleum hydrocarbons or wastes are taken for reclamation or disposal, may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. In addition, the risk of accidental spills or releases could expose the operators of the Underlying Properties to significant liabilities that could have a material adverse effect on the operators’ businesses, financial condition and results of operations and could reduce the amount of cash available for distribution to trust unitholders. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly operational control requirements or waste handling, storage, transport, disposal or cleanup requirements could require the operators of the Underlying Properties to make significant expenditures to attain and maintain compliance and may otherwise have a material adverse effect on their results of operations, competitive position or financial condition.

 

The trust will indirectly bear 80% of all costs and expenses paid by Enduro Sponsor, including those related to environmental compliance and liabilities associated with the Underlying Properties, including costs and liabilities resulting from conditions that existed prior to Enduro Sponsor’s

acquisition of the Underlying Properties unless such costs and expenses result from the operator’s negligence or misconduct. In addition, as a result of the increased cost of compliance, the operators of the Underlying Properties may decide to discontinue drilling.

 

Neither Enduro Sponsor nor the trust is generally entitled to, nor required to provide, indemnity to third party operators with respect to pollution liability and associated environmental remediation costs. However, Enduro Sponsor may be required to provide, and may be entitled to, indemnity from third party operators with respect to such liabilities and costs in the event of the other party’s gross negligence or misconduct. In addition, Enduro Sponsor has agreed to assume certain environmental liabilities of prior owners of the Underlying Properties in connection with the purchase thereof.

 

The amount of cash available for distribution by the trust could be reduced by expenses caused by uninsured claims.

 

Enduro Sponsor maintains insurance coverage against potential losses that it believes are customary in its industry. Enduro Sponsor currently maintains general liability insurance and excess liability coverage with limits of $1 million and $20 million per occurrence, respectively, and $2 million and $20 million in the aggregate, respectively. Enduro Sponsor’s excess liability coverage has a deductible of $10,000 per occurrence, while there is no deductible on the general liability insurance. The general liability insurance covers Enduro Sponsor and its subsidiaries for legal and contractual liabilities arising out of bodily injury or property damage, including any resulting loss of use to third parties, and for sudden and accidental pollution or environmental liability, while the excess liability coverage is in addition to and triggered if the general liability per occurrence limit is reached. In addition, Enduro Sponsor maintains control of well insurance with per occurrence limits ranging from $5 million to $20 million and deductibles ranging from $100,000 to $200,000 depending on the status of the well. Enduro Sponsor’s general liability insurance and excess liability policies do not provide coverage with respect to legal and contractual liabilities of the trust, and the trust does not maintain such coverage since it is passive in nature and does not have any ability to influence Enduro Sponsor or control the operations or development of the Underlying Properties. However, the trust unitholders may indirectly benefit from Enduro Sponsor’s insurance coverage to the extent that insurance proceeds offset or reduce any costs or expenses that are deducted when calculating the net profits attributable to the trust.

 

Enduro Sponsor does not currently have any insurance policies in effect that are intended to provide coverage for losses solely related to hydraulic fracturing operations; however, Enduro Sponsor believes its general liability and excess liability insurance policies would cover third-party claims related to hydraulic fracturing operations in accordance with, and subject to, the terms of such policies. These policies may not cover fines, penalties or costs and expenses related to government-mandated clean up of pollution. In addition, these policies do not provide coverage for all liabilities, and we cannot assure you that the insurance coverage will be adequate to cover claims that may arise or that Enduro Sponsor will be able to maintain adequate insurance at rates it considers reasonable. The occurrence of an event not fully covered by insurance could result in a significant decrease in the amount of cash available for distribution by the trust.

 

The operations of the Underlying Properties are subject to complex federal, state, local and other laws and regulations that could adversely affect the cost, manner or feasibility of conducting operations on them or expose the operator to significant liabilities, which could reduce the amount of cash available for distribution to trust unitholders.

 

The production and development operations on the Underlying Properties are subject to complex and stringent laws and regulations. In order to conduct their operations in compliance with these laws and regulations, the operators of the Underlying Properties must obtain and maintain numerous permits, drilling bonds, approvals and certificates from various federal, state and local governmental authorities and engage in extensive reporting. The operators of the Underlying Properties may incur substantial costs and experience delays in order to maintain compliance with these existing laws and regulations, and the trust will bear an 80% share of these costs. In addition, the operators’

costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to their operations. Such costs could have a material adverse effect on the operators’ business, financial condition and results of operations and reduce the amount of cash received by the trust in respect of the Net Profits Interest. The operators of the Underlying Properties must also comply with laws and regulations prohibiting fraud and market manipulations in energy markets. To the extent the operators of the Underlying Properties are shippers on interstate pipelines, they must comply with the tariffs of such pipelines and with federal policies related to the use of interstate capacity, and such compliance costs will be borne in part by the trust.

 

Laws and regulations governing exploration and production may also affect production levels. The operators of the Underlying Properties are required to comply with federal and state laws and regulations governing conservation matters, including: provisions related to the unitization or pooling of the oil and natural gas properties; the establishment of maximum rates of production from wells; the spacing of wells; the plugging and abandonment of wells; and the removal of related production equipment. Additionally, state and federal regulatory authorities may expand or alter applicable pipeline safety laws and regulations, compliance with which may require increase capital costs on the part of the operators and third party downstream natural gas transporters. These and other laws and regulations can limit the amount of oil and natural gas the operators can produce from their wells, limit the number of wells they can drill, or limit the locations at which they can conduct drilling operations, which in turn could negatively impact trust distributions, estimated and actual future net revenues to the trust and estimates of reserves attributable to the trust’s interests.

 

New laws or regulations, or changes to existing laws or regulations, may unfavorably impact the operators of the Underlying Properties, could result in increased operating costs or have a material adverse effect on their financial condition and results of operations and reduce the amount of cash received by the trust. For example, Congress is currently considering legislation that, if adopted in its proposed form, would subject companies involved in oil and natural gas exploration and production activities to, among other items, additional regulation of and restrictions on hydraulic fracturing of wells, the elimination of certain U.S. federal tax incentives and deductions available to oil and natural gas exploration and production activities and the prohibition or additional regulation of private energy commodity derivative and hedging activities. These and other potential regulations could increase the operating costs of the Underlying Properties, reduce the operators’ liquidity, delay the operators’ operations or otherwise alter the way the operators conduct their business, any of which could have a material adverse effect on the trust and the amount of cash available for distribution to trust unitholders.

 

Climate change laws and regulations restricting emissions of “greenhouse gases” could result in increased operating costs and reduced demand for the oil and natural gas that the operators produce while the physical effects of climate change could disrupt their production and cause them to incur significant costs in preparing for or responding to those effects.

 

The oil and gas industry is a direct source of certain greenhouse gas (“GHG”) emissions, namely carbon dioxide and methane, and future restrictions on such emissions could impact future operations on the Underlying Properties. On December 15, 2009, the EPA published its findings that emissions of carbon dioxide, methane and other GHGs present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to the warming of the Earth’s atmosphere and other climate changes. Based on these findings, the agency has begun adopting and implementing regulations that would restrict emissions of GHGs under existing provisions of the federal Clean Air Act. During 2010, the EPA adopted two sets of rules regulating GHG emissions under the Clean Air Act, one of which requires a reduction in emissions of GHGs from motor vehicles and the other of which regulates emissions of GHGs from certain large stationary sources under the Prevention of Significant Deterioration (“PSD”) and Title V permitting programs. The stationary source rule “tailors” these permitting programs to apply to certain stationary sources in a multi-step process, with the largest sources first subject to permitting. Facilities required to obtain PSD permits for their GHG emissions also will be required to reduce those emissions

according to “best available control technology” standards for GHG that will be established by the states or, in some instances, by the EPA on a case-by-case basis. The EPA’s rules relating to emissions of GHGs from large stationary sources of emissions are currently subject to a number of legal challenges, but the federal courts have thus far declined to issue any injunctions to prevent the EPA from implementing, or requiring state environmental agencies to implement, the rules. These EPA rulemakings could affect the operations on the Underlying Properties or the ability of the operators of the Underlying Properties to obtain air permits for new or modified facilities. In addition, on November 30, 2010, the EPA published final regulations expanding the existing greenhouse gas monitoring and reporting rule to include onshore and offshore oil and natural gas production and onshore oil and natural gas processing, transmission, storage and distribution facilities. Reporting of GHG emissions from such facilities will be required on an annual basis, with reporting beginning in 2012 for emissions occurring in 2011. The Underlying Properties may be subject to these requirements or become subject to them in the future.

 

In addition, the U.S. Congress has from time to time considered legislation to reduce emissions of GHGs, and almost half of the states have already taken legal measures to reduce emissions of GHGs, primarily through the planned development of GHG emission inventories and/or regional GHG cap and trade programs. Most of these cap and trade programs work by requiring either major sources of emissions or major producers of fuels to acquire and surrender emission allowances, with the number of allowances available for purchase reduced each year until the overall GHG emission reduction goal is achieved. These reductions would be expected to cause the cost of allowances to escalate significantly over time. The adoption of any legislation or regulations that requires reporting of GHGs or otherwise limits emissions of GHGs from the equipment or operations of the operators of the Underlying Properties could require the operators to incur costs to monitor and report on GHG emissions or reduce emissions of GHGs associated with their operations. Such requirements could also adversely affect demand for the oil and natural gas produced, all of which could reduce profits attributable to the Net Profits Interest and, as a result, the trust’s cash available for distribution.

 

Because regulation of GHG emissions is relatively new, further regulatory, legislative and judicial developments are likely to occur. Such developments may affect how these GHG initiatives will impact the operators of the Underlying Properties and the trust. Due to the uncertainties surrounding the regulation of and other risks associated with GHG emissions, Enduro Sponsor cannot predict the financial impact of related developments on the operators of the Underlying Properties or the trust.

 

Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts and floods and other climatic events. If any such effects were to occur, they could have an adverse effect on the operators’ assets and operations and, consequently, may reduce profits attributable to the Net Profits Interest and, as a result, the trust’s cash available for distribution.

 

Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays as well as adversely affect the services of the operators of the Underlying Properties.

 

Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons, particularly natural gas, from tight formations. The process involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. The process is typically regulated by state oil and gas commissions. However, the EPA has asserted federal regulatory authority over hydraulic fracturing involving diesel fuel under the Safe Drinking Water Act’s Underground Injection Control Program and has commenced drafting guidance for permitting authorities and the industry regarding the process for obtaining a permit for hydraulic fracturing involving diesel fuel. Industry groups have filed suit challenging the EPA’s recent decision. At the same time, the EPA has commenced a study of the potential environmental impacts of hydraulic fracturing activities, with results of the study anticipated to be available by late 2012. Other

federal agencies are also examining hydraulic fracturing, including the U.S. Department of Energy (“DOE”), the U.S. Government Accountability Office and the White House Council for Environmental Quality. The U.S. Department of the Interior is also considering regulation of hydraulic fracturing activities on public lands. In addition, legislation called the Fracturing Responsibility and Awareness of Chemicals Act (“FRAC Act”) has been introduced in Congress to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the fracturing process. Also, some states have adopted, and other states are considering adopting, regulations that could restrict or impose additional requirements relating to hydraulic fracturing in certain circumstances. For example, on June 17, 2011, Texas signed into law a bill that requires the disclosure of information regarding the substances used in the hydraulic fracturing process to the Railroad Commission of Texas (the entity that regulates oil and natural gas production) and the public. Such federal or state legislation could require the disclosure of chemical constituents used in the fracturing process to state or federal regulatory authorities who could then make such information publicly available. Disclosure of chemicals used in the fracturing process could make it easier for third parties opposing hydraulic fracturing to initiate legal proceedings against producers and service providers based on allegations that specific chemicals used in the fracturing process could adversely affect groundwater. In addition, if hydraulic fracturing is regulated at the federal level, Enduro Sponsor’s and the Third Party Operators’ fracturing activities could become subject to additional permit requirements or operational restrictions and also to associated permitting delays and potential increases in costs. Further, at least three local governments in Texas have imposed temporary moratoria on drilling permits within city limits so that local ordinances may be reviewed to assess their adequacy to address such activities, while some state and local governments in the Marcellus Shale region in Pennsylvania and New York have considered or imposed temporary moratoria on drilling operations using hydraulic fracturing until further study of the potential environmental and human health impacts by the EPA or the relevant agencies are completed. No assurance can be given as to whether or not similar measures might be considered or implemented in the jurisdictions in which the Underlying Properties are located. If new laws or regulations that significantly restrict or otherwise impact hydraulic fracturing are passed by Congress or adopted in Texas, Louisiana or New Mexico, such legal requirements could make it more difficult or costly for Enduro Sponsor or the Third Party Operators to perform hydraulic fracturing activities and thereby could affect the determination of whether a well is commercially viable. In addition, restrictions on hydraulic fracturing could reduce the amount of oil and natural gas that the operators are ultimately able to produce in commercially paying quantities from the Underlying Properties.

 

The bankruptcy of Enduro Sponsor or any of the Third Party Operators could impede the operation of the wells and the development of the proved undeveloped reserves.

 

The value of the Net Profits Interest and the trust’s ultimate cash available for distribution will be highly dependent on the financial condition of the operators of the Underlying Properties. None of the operators of the Underlying Properties, including Enduro Sponsor, has agreed with the trust to maintain a certain net worth or to be restricted by other similar covenants, and Enduro Sponsor intends to use a portion of the net proceeds of this offering for general limited liability company purposes instead of retaining all or a portion to pay costs for the operation and development of the Underlying Properties.

 

The ability to develop and operate the Underlying Properties depends on the future financial condition and economic performance and access to capital of the operators of those properties, which in turn will depend upon the supply and demand for oil and natural gas, prevailing economic conditions and financial, business and other factors, many of which are beyond the control of Enduro Sponsor and the Third Party Operators. Please read “Information about Enduro Resource Partners LLC (Enduro Sponsor)” for additional information relating to Enduro Sponsor, including information relating to the business of Enduro Sponsor, historical financial statements of Enduro Sponsor and other financial information relating to Enduro Sponsor. This prospectus contains no financial information about the Third Party Operators. Enduro Sponsor will not be a reporting company following this offering and will not be required to file periodic reports with the SEC pursuant to the Securities

Exchange Act of 1934, as amended (the “Exchange Act”). Therefore, as a trust unitholder, you will not have access to financial information about Enduro Sponsor.

 

In the event of the bankruptcy of an operator of the Underlying Properties, the working interest owners in the affected properties will have to seek a new party to perform the development and the operations of the affected wells. The working interest owners may not be able to find a replacement driller or operator, and they may not be able to enter into a new agreement with such replacement party on favorable terms within a reasonable period of time. As a result, such a bankruptcy may result in reduced production from the reserves and decreased distributions to trust unitholders.

 

In the event of the bankruptcy of Enduro Sponsor, if a court held that the Net Profits Interest was part of the bankruptcy estate, the trust may be treated as an unsecured creditor with respect to the Net Profits Interest attributable to properties in Louisiana and New Mexico.

 

It is well-established under Texas law that the conveyance of a net profits interest constitutes the conveyance of a presently vested, non-possessory interest in real property. Therefore, Enduro Sponsor and the trust believe that, in a bankruptcy of Enduro Sponsor, the Net Profits Interest would be viewed as a separate property interest under Texas law and, as such, outside of Enduro Sponsor’s bankruptcy estate. Likewise, Enduro Sponsor and the trust believe that the Net Profits Interest would be viewed as a separate property interest under the laws of Louisiana and outside of Enduro Sponsor’s bankruptcy estate. Since enactment of the Louisiana Mineral Code in 1975, Louisiana courts have classified an overriding royalty interest as a real right and an incorporeal immovable (similar to a real property interest). Although there are no reported Louisiana court cases addressing whether a net profits interest, carved out of the interest of a mineral lessee under an oil and gas lease, should be similarly classified as a real right and an incorporeal immovable, a 1972 Colorado federal court applying Louisiana law did conclude that such a net profits interest was comparable to an overriding royalty interest and, thus, was properly so classified. Similarly, Enduro Sponsor and the trust believe that a New Mexico court would rule that the conveyance of a net profits interest constitutes a conveyance of a real property interest. While no New Mexico case has clearly defined the nature of a “net profits interest” independent of the creating instrument, New Mexico case law has held that an overriding royalty interest in a mineral lease is a real property interest under New Mexico law. The 10th Circuit Court of Appeals has held that a net profits interest is “similar to” an overriding royalty interest. Given that the conveyance of the Net Profits Interest will contain a provision stating that it is the express intent of the parties that the conveyance of the Net Profits Interest constitutes a conveyance of a royalty interest in real property, in the event of a bankruptcy on the part of Enduro Sponsor, under New Mexico law, the Net Profits Interest would likely not be treated as part of Enduro Sponsor’s bankruptcy estate. Further, it is relevant that Enduro Sponsor and the trust have structured the Net Profits Interest as an overriding royalty interest in gross production payable on the basis of net profits. Nevertheless, the outcome is not certain given that there are not any dispositive Louisiana or New Mexico Supreme Court cases directly concluding that a conveyance of a net profits interest: (i) in the case of Louisiana, constitutes the conveyance of a real right and an incorporeal immovable (similar to a real property interest) or (ii) in the case of New Mexico, constitutes the conveyance of a real property interest. As such, in a bankruptcy of Enduro Sponsor, to the extent Louisiana or New Mexico law were held to be applicable, the Net Profits Interest might be considered an asset of the bankruptcy estate and used to satisfy obligations to creditors of Enduro Sponsor, in which case the trust would be an unsecured creditor of Enduro Sponsor at risk of losing the entire value of the Net Profits Interest to senior creditors.

 

Adverse developments in Texas, Louisiana or New Mexico could adversely impact the results of operations and cash flows of the Underlying Properties and reduce the amount of cash available for distributions to trust unitholders.

 

The operations of the Underlying Properties are focused on the production and development of oil and natural gas within the states of Texas, Louisiana and New Mexico. As a result, the results of

operations and cash flows of the Underlying Properties depend upon continuing operations in these areas. This concentration could disproportionately expose the trust’s interests to operational and regulatory risk in these areas. Due to the lack of diversification in geographic location, adverse developments in exploration and production of oil and natural gas in any of these areas of operation could have a significantly greater impact on the results of operations and cash flows of the Underlying Properties than if the operations were more diversified.

 

The receipt of payments by Enduro Sponsor based on the hedge contracts depends upon the financial position of the hedge contract counterparties. A default by any of the hedge contract counterparties could reduce the amount of cash available for distribution to the trust unitholders.

 

Payments from hedge contract counterparties to Enduro Sponsor are intended to offset costs and thus have the effect of providing additional cash to the trust during periods of lower crude oil prices. In the event that any of the counterparties to the hedge contracts default on their obligations to make payments to Enduro Sponsor under the hedge contracts, the cash distributions to the trust unitholders could be materially reduced. Enduro Sponsor does not have any security interest from its hedge counterparties against which it could recover in the event of a default by any such counterparty.

 

Tax Risks Related to the Trust Units

 

The tax treatment of an investment in trust units could be affected by recent and potential legislative changes, possibly on a retroactive basis.

 

The recently enacted Health Care and Education Affordability Reconciliation Act of 2010 includes a provision that, in taxable years beginning after December 31, 2012, subjects an individual having modified adjusted gross income in excess of $200,000 (or $250,000 for married taxpayers filing joint returns) to a “Medicare tax” equal generally to 3.8% of the lesser of such excess or the individual’s net investment income, which appears to include royalty income, if any, derived from the trust units as well as any net gain from the disposition of trust units. In addition, absent new legislation extending the current rates, beginning January 1, 2013, 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.

 

The trust has not requested a ruling from the IRS regarding the tax treatment of the trust. If the IRS were to determine (and be sustained in that determination) that the trust is not a “grantor trust” for federal income tax purposes, the trust could be subject to more complex and costly tax reporting requirements that could reduce the amount of cash available for distribution to trust unitholders.

 

If the trust were not treated as a grantor trust for federal income tax purposes, the trust should be treated as a partnership for such purposes. Although the trust would not become subject to federal income taxation at the entity level as a result of treatment as a partnership, and items of income, gain, loss and deduction would flow through to the trust unitholders, the trust’s tax reporting requirements would be more complex and costly to implement and maintain, and its distributions to trust unitholders could be reduced as a result.

 

Neither Enduro Sponsor nor the trustee has requested a ruling from the IRS regarding the tax status of the trust, and neither Enduro Sponsor nor the trust can assure you that such a ruling would be granted if requested or that the IRS will not challenge these positions on audit.

 

Trust unitholders should be aware of the possible state tax implications of owning trust units. Please read “State Tax Considerations.”

Certain U.S. federal income tax preferences currently available with respect to oil and natural gas production may be eliminated as a result of future legislation.

 

Among the changes contained in President Obama’s Budget Proposal for Fiscal Year 2012 (the “Budget Proposal”) is the elimination of certain key U.S. federal income tax preferences relating to oil and natural gas exploration and production. The Budget Proposal proposes to eliminate certain tax preferences applicable to taxpayers engaged in the exploration or production of natural resources. These changes include, but are not limited to, (i) the repeal of the percentage depletion allowance for oil and gas properties, (ii) the elimination of current deductions for intangible drilling and development costs, (iii) the elimination of the deduction for United States production activities and (iv) the increase in the amortization period from two years to seven years for geophysical costs paid or incurred in connection with the exploration for, or development of, oil or gas within the United States. It is unclear whether any such changes will actually be enacted into law or, if enacted, how soon any such changes could become effective. The passage of any legislation as a result of these proposals, or any other similar changes in U.S. federal income tax laws that eliminate certain tax preferences that are currently available with respect to oil and natural gas exploration and production, could reduce the cash available for distribution to the trust unitholders or adversely affect the value of the trust units.

 

You will be required to pay taxes on your share of the trust’s income even if you do not receive any cash distributions from the trust.

 

Trust unitholders are treated as if they own the trust’s assets and receive the trust’s income and are directly taxable thereon as if no trust were in existence. Because the trust will generate taxable income that could be different in amount than the cash the trust distributes, you will be required to pay any federal income taxes and, in some cases, state and local income taxes on your share of the trust’s taxable income even if you receive no cash distributions from the trust. You may not receive cash distributions from the trust equal to your share of the trust’s taxable income or even equal to the actual tax liability that results from that income.

 

A portion of any tax gain on the disposition of the trust units could be taxed as ordinary income.

 

If you sell your trust units, you will recognize a gain or loss equal to the difference between the amount realized and your tax basis in those trust units. A substantial portion of any gain recognized may be taxed as ordinary income due to potential recapture items, including depletion recapture. Please read “Federal Income Tax Consequences — Tax Consequences to U.S. Trust Unitholders — Disposition of Trust Units.”

 

The trust will allocate its items of income, gain, loss and deduction between transferors and transferees of the trust units each month based upon the ownership of the trust units on the monthly record date, instead of on the basis of the date a particular trust unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among the trust unitholders.

 

The trust will generally allocate its items of income, gain, loss and deduction between transferors and transferees of the trust units each month based upon the ownership of the trust units on the monthly record date, instead of on the basis of the date a particular trust unit is transferred. It is possible that the IRS could disagree with this allocation method and could assert that income and deductions of the trust should be determined and allocated on a daily or prorated basis, which could require adjustments to the tax returns of the trust unitholders affected by the issue and result in an increase in the administrative expense of the trust in subsequent periods. Please read “Federal Income Tax Consequences — U.S. Federal Income Tax Consequences — Direct Taxation of Trust Unitholders.”

 

This prospectus contains “forward-looking statements” about Enduro Sponsor and the trust that are subject to risks and uncertainties. All statements other than statements of historical fact included in this prospectus, including, without limitation, statements under “Prospectus Summary” and “Risk Factors” regarding the financial position, business strategy, production and reserve growth and other plans and objectives for the future operations of Enduro Sponsor and the trust are forward-looking statements. Such statements may be influenced by factors that could cause actual outcomes and results to differ materially from those projected. Forward-looking statements are subject to risks and uncertainties and include statements made in this prospectus under “Projected Cash Distributions,” statements pertaining to future development activities and costs, and other statements in this prospectus that are prospective and constitute forward-looking statements.

 

When used in this document, the words “believes,” “expects,” “anticipates,” “intends” or similar expressions are intended to identify such forward-looking statements. The following important factors, in addition to those discussed elsewhere in this prospectus, could affect the future results of the energy industry in general, and Enduro Sponsor and the trust in particular, and could cause actual results to differ materially from those expressed in such forward-looking statements:

 

 

You should not place undue reliance on these forward-looking statements. All forward-looking statements speak only as of the date of this prospectus. Enduro Sponsor does not undertake any obligation to release publicly any revisions to the forward-looking statements to reflect events or circumstances after the date of this prospectus or to reflect the occurrence of unanticipated events, unless the securities laws require it to do so.

 

This prospectus describes other important factors that could cause actual results to differ materially from expectations of Enduro Sponsor and the trust, including under the heading “Risk Factors.” All written and oral forward-looking statements attributable to Enduro Sponsor, the trust, or persons acting on behalf of Enduro Sponsor or the trust are expressly qualified in their entirety by such factors.

 

Enduro Sponsor is offering all of the trust units to be sold in this offering, including the trust units to be sold upon the exercise of the underwriters’ option to purchase additional trust units. Enduro Sponsor expects to receive net proceeds from the sale of 13,200,000 trust units offered by this prospectus of approximately $302.9 million, after deducting underwriting discounts and commissions, structuring fees and offering expenses, and $348.9 million if the underwriters exercise their option to purchase additional trust units in full. Enduro Sponsor is deemed to be an underwriter with respect to the trust units offered hereby.

 

Enduro Sponsor intends to use the net proceeds from this offering, including any proceeds from the exercise of the underwriters’ option to purchase additional trust units, to repay a portion of the borrowings outstanding under its senior secured credit agreement, to make a distribution to its sole member, Enduro Holdings, and to acquire additional oil and natural gas properties in the future for Enduro Sponsor. Enduro Sponsor has not yet identified oil and natural gas properties to be acquired.

 

The table below sets forth these intended uses with the corresponding dollar amounts planned for such use, assuming no exercise of the underwriters’ over-allotment option.

 

 

 

 

On December 1, 2010 Enduro Sponsor entered into a $500 million senior secured credit agreement, which provides for revolving loans. Borrowings under the revolving credit facility have a maturity date of December 1, 2015 and bear interest at the applicable LIBOR rate, plus applicable margins ranging from 1.75% to 2.75%, or at a base rate, based upon the greatest of (a) the Prime Rate, (b) the Federal Funds Rate plus 0.5%, and (c) LIBOR plus 1%, plus applicable margins ranging from 0.75% to 1.75%.

 

As of June 30, 2011, total borrowings under Enduro Sponsor’s revolving credit facility were $231 million and had a weighted average interest rate of approximately 3.3% for the second quarter of 2011. The current borrowings under the revolving credit facility were incurred to fund the acquisition of the Acquired Properties. Affiliates of certain of the underwriters participating in this offering are lenders under Enduro Sponsor’s senior secured credit agreement and will receive a substantial portion of the proceeds from this offering pursuant to the repayment of a portion of the borrowings thereunder. Please read “Underwriting — FINRA Rules.”

 

Enduro Sponsor is a privately-held Delaware limited liability company engaged in the production and development of oil and natural gas from properties located in Texas, Louisiana and New Mexico. Enduro Sponsor was formed on March 3, 2010.

 

The Underlying Properties were acquired in three separate transactions and are located in two different geographic regions: the Permian Basin and East Texas/North Louisiana. After giving pro forma effect to the conveyance of the Net Profits Interest to the trust, which will occur through two mergers, the offering of the trust units contemplated by this prospectus and the application of the net proceeds as described in “Use of Proceeds,” as of March 31, 2011, Enduro Sponsor would have had total assets of $664.7 million and total liabilities of $106.7 million. For an explanation of the pro forma adjustments, please read “Financial Statements of Enduro Sponsor — Unaudited Pro Forma Financial Statements — Introduction.”

 

The trust units do not represent interests in, or obligations of, Enduro Sponsor.

Summary Historical and Unaudited Pro Forma Financial, Operating and Reserve Data of Enduro Sponsor

 

The summary historical audited financial data presented below should be read in conjunction with “Information about Enduro Resource Partners LLC (Enduro Sponsor) — Selected Historical and Unaudited Pro Forma Financial, Operating and Reserve Data of Enduro Sponsor” and the accompanying financial statements and related notes of Enduro Sponsor included elsewhere in this prospectus. The summary historical audited financial data of the Predecessor as of December 31, 2009 and 2010 and for each of the years in the three-year period ended December 31, 2010 have been derived from the Predecessor’s audited financial statements. Operations of the Predecessor Properties are deemed to be the “predecessor” of Enduro Sponsor and recorded transactions are shown separately based on the ownership of the Predecessor Properties. EAC owned the Predecessor Properties prior to March 9, 2010, at which time Denbury Resources Inc. acquired the properties in connection with its acquisition of EAC. Enduro Sponsor then acquired the Predecessor Properties on December 1, 2010. Accordingly, the audited financial statements of the Predecessor as of and for the three years ended December 31, 2010 are presented for (i) “Predecessor-EAC” for the years ended December 31, 2008 and 2009 and for the period from January 1, 2010 through March 8, 2010; (ii) “Predecessor-DNR” for the period from March 9, 2010 through November 30, 2010 and (iii) “Enduro Sponsor” for the period from Enduro Sponsor’s inception (March 3, 2010) through December 31, 2010.

 

The summary historical unaudited financial data of Enduro Sponsor as of March 31, 2011 and 2010 and for the three-month period ended March 31, 2011 and 2010 have been derived from Enduro Sponsor’s unaudited interim financial statements. The unaudited financial statements were prepared on a basis consistent with the audited statements and, in the opinion of Enduro Sponsor’s management, include all adjustments (consisting only of normal recurring adjustments) necessary to present fairly the results of Enduro Sponsor for the periods presented.

 

The summary unaudited pro forma financial data as of and for the three months ended March 31, 2011 and for the year ended December 31, 2010 set forth in the following table has been derived from the unaudited pro forma financial statements of Enduro Sponsor included elsewhere in this prospectus. The pro forma adjustments have been prepared as if the acquisition of the Acquired Properties and, with respect to the pro forma as adjusted information, the conveyance of the Net Profits Interest and the offer and sale of the trust units and application of the net proceeds therefrom, had taken place (i) on March 31, 2011, in the case of the pro forma balance sheet information as of March 31, 2011, and (ii) as of January 1, 2010, in the case of the pro forma statements of earnings for the three months ended March 31, 2011 and for the year ended December 31, 2010.

 

The table below includes selected historical production and reserve information for Enduro Sponsor for the periods presented.

 

 

Management of Enduro Sponsor

 

Set forth in the table below are the names, ages and titles of the managers and executive officers of Enduro Sponsor.

 

 

Jon S. Brumley co-founded Enduro Sponsor and has been the President and Chief Executive Officer of Enduro Sponsor and a member of Enduro Sponsor’s board of managers (the “Enduro Sponsor Board”) since March 2010. Mr. Brumley is responsible for the coordination and supervision of exploration and production and the acquisition of Enduro Sponsor’s oil and natural gas reserves. Mr. Brumley was the Chief Executive Officer of EAC from January 2006 until March 2010 when it was sold to Denbury Resources Inc., a publicly traded exploration and production company. At EAC, Mr. Brumley also served as President from August 2002 until March 2010, a director on the Board of Directors from April 1999 until May 2001 and from November 2001 until March 2010 and Executive Vice President of Business Development and Corporate Secretary from April 1998 until August 2002. Mr. Brumley also served as President and Chief Executive Officer of Encore Energy Partners GP LLC (“Encore GP LLC”), the general partner of Encore Energy Partners LP (“Encore Energy”), a publicly traded master limited partnership whose general partner was owned by EAC from February 2007 until March 2010. Prior to joining EAC, Mr. Brumley held management positions at MESA Petroleum and Pioneer Natural Resources Company. Mr. Brumley received a Bachelor of Business Administration in Marketing from the University of Texas.

 

John W. Arms co-founded Enduro Sponsor and has been the Executive Vice President and Chief Operating Officer of Enduro Sponsor and a member of the Enduro Sponsor Board since March 2010. Mr. Arms is responsible for the coordination and supervision of acquisitions, the engineering, enhancement and exploitation of Enduro Sponsor’s existing properties as well as the engineering analysis and evaluation of its future reserve acquisitions. Prior to joining Enduro Sponsor, Mr. Arms served as Senior Vice President of Acquisitions at EAC and Encore Energy from February 2007 until its acquisition by Denbury Resources Inc. in March 2010. At EAC, Mr. Arms also served as Vice President of Business Development of EAC from September 2001 until February 2007 and as Manager of Acquisitions and in various other petroleum engineering positions from November 1998 until

September 2001. Prior to joining EAC, Mr. Arms held various positions of responsibility at XTO Energy and ARCO Oil and Gas Company. Mr. Arms received his Bachelor of Science in Petroleum Engineering from the Colorado School of Mines.

 

Kimberly A. Weimer has been the Vice President and Chief Financial Officer of Enduro Sponsor since April 2010. Prior to joining Enduro Sponsor, Ms. Weimer served as the Director of Investor Relations of EAC from October 2008 until its acquisition by Denbury Resources Inc. in March 2010. From May 2007 until October 2008, she was the Senior Manager of Financial Reporting at EAC responsible for all aspects of SEC reporting for Encore Energy. During this timeframe, Encore Energy completed its initial public offering and was listed on the New York Stock Exchange, completed two follow-on equity offerings, and purchased over $500 million in assets. Prior to joining EAC in 2007, Ms. Weimer worked in public accounting, beginning her career at Arthur Andersen. From May 2005 to May 2007, Ms. Weimer served as an Audit Manager at Cherry, Bekaert & Holland. Ms. Weimer received a Bachelor of Science in Accounting and Finance from Louisiana State University. She is a Certified Public Accountant.

 

Bill R. Pardue has been the Director, Engineering and Operations of Enduro Sponsor since May 2010. Prior to joining Enduro Sponsor, Mr. Pardue served as the Asset Manager of Encore Energy from May 2007 to May 2010. Mr. Pardue also served as the Engineering Manager for EAC from June 2005 until May 2007 in the Permian and Mid-Continent regions. At EAC, Mr. Pardue also worked in various petroleum engineering positions from November 2000 until May 2005. Prior to joining EAC, Mr. Pardue worked as a production and reservoir engineer for Meridian Oil/Burlington Resources from 1996 until 2000. Mr. Pardue received a Bachelor of Science in Petroleum Engineering from Texas Tech University and a Master of Business Administration from Texas Christian University. Mr. Pardue is also a registered professional engineer in the state of Texas.

 

David J. Grahek has been the Director, Geology of Enduro Sponsor since June 2010. Prior to joining Enduro Sponsor, Mr. Grahek served as Geologic Advisor of EAC from June 2005 until its acquisition by Denbury Resources, Inc. in March 2010. Prior to joining EAC, Mr. Grahek held various positions of responsibility with G&G Exploration Inc. and Union Pacific Resources Company. Mr. Grahek has over 35 years of petroleum geology experience. Mr. Grahek received his Bachelor of Science in Geology from the University of Southern Colorado and completed post graduate work at the Colorado School of Mines.

 

David Leuschen has been a member of the Enduro Sponsor Board since March 2010. Mr. Leuschen is a founder and Senior Managing Director of Riverstone. Prior to co-founding Riverstone, Mr. Leuschen was a Partner and Managing Director at Goldman, Sachs & Co. and founder and head of the Goldman, Sachs & Co. Global Energy & Power Group. Mr. Leuschen joined Goldman, Sachs & Co. in 1977 and became head of the Global Energy & Power Group in 1985 and a Partner in 1986. He remained with Goldman, Sachs & Co. until leaving to found Riverstone. Mr. Leuschen has served as a director of Cambridge Energy Research Associates, Cross Timbers Oil Company (predecessor to XTO Energy), J. Aron Resources, Mega Energy, Inc. and Natural Meats Montana. He currently serves on the boards of directors of Legend Natural Gas, Dynamic Industries, Dynamic Offshore Resources, Canera Resources and Titan Operating. He is also president of Switchback Ranch LLC and has served on a number of non-profit boards of directors. Mr. Leuschen received his Bachelor of Arts from Dartmouth and his Master of Business Administration from Dartmouth’s Amos Tuck School of Business.

 

Pierre F. Lapeyre, Jr. has been a member of the Enduro Sponsor Board since March 2010. Mr. Lapeyre is a founder and Senior Managing Director of Riverstone. Prior to co-founding Riverstone, Mr. Lapeyre was a Managing Director at Goldman, Sachs & Co. in its Global Energy & Power Group. Mr. Lapeyre joined Goldman, Sachs & Co. in 1986 and spent his 14-year investment banking career focused on energy and power, particularly the midstream/pipeline and oil service sectors. Mr. Lapeyre’s responsibilities included client coverage and leading the execution of a wide variety of mergers and acquisitions, initial public offerings, strategic advisory and capital markets financings for clients across all sectors of the industry. Mr. Lapeyre serves on the boards of directors of Legend Natural Gas, Titan Specialties, Dynamic Industries, Titan Operating, Three Rivers, Dynamic Offshore Resources and

Quorum Technologies. Mr. Lapeyre received his Bachelor of Science in Finance and Economics from the University of Kentucky and his Master of Business Administration from the University of North Carolina at Chapel Hill.

 

N. John Lancaster has been a member of the Enduro Sponsor Board since March 2010. Mr. Lancaster is a Partner and Managing Director of Riverstone. Mr. Lancaster joined Riverstone in 2000 and is responsible for the sourcing and management of investments across the energy industry, with a particular emphasis on the oilfield service and exploration and production sectors. Prior to joining Riverstone, Mr. Lancaster was a Director with The Beacon Group, LLC, a privately held firm specializing in principal investing and strategic advisory services in the energy and other industries. Mr. Lancaster began his career at Bankers Trust and later at CS First Boston, spending time as an investment banker and equity research analyst focused on the oil service and unregulated gas transmission sectors of the energy industry. Mr. Lancaster serves on the boards of directors of Cobalt International Energy, Inc., Titan Specialties, Dynamic Industries, Dynamic Offshore Resources, Cuadrilla Resources, Hudson Products, Liberty Resources, and Barra Energia. Mr. Lancaster received his Bachelor of Business Administration from the University of Texas, where he serves on the McCombs School of Business Advisory Council, and his Master of Business Administration from Harvard Business School.

 

I. Jon Brumley has been a member of the Enduro Sponsor Board since March 2010. Mr. Brumley served as the Chairman of the Board of Directors of Encore GP LLC from February 2007 to March 2010. Mr. Brumley also served as the Chairman of the Board of Directors of EAC since its inception in April 1998 until March 2010, the Chief Executive Officer from its inception until December 2005 and President from its inception until August 2002. Beginning in August 1996, Mr. Brumley served as Chairman and Chief Executive Officer of MESA Petroleum until MESA’s merger in August 1997 with Parker & Parsley to form Pioneer Natural Resources Company. He served as Chairman and Chief Executive Officer of Pioneer until joining EAC in 1998. Mr. Brumley received a Bachelor of Business Administration from the University of Texas and a Master of Business Administration from the University of Pennsylvania Wharton School of Business.

Beneficial Ownership of Enduro Sponsor

 

The following table sets forth, as of July 25, 2011, the beneficial ownership of limited liability company interests of Enduro Sponsor held by:

 

 

Except as indicated by footnote, the persons named in the table below have sole voting and investment power with respect to all membership interests of Enduro Sponsor shown as beneficially owned by them and their address is 777 Main Street, Suite 800, Fort Worth, Texas 76102.

 

 

 

 

 

 

 

 

Beneficial Ownership of Enduro Royalty Trust

 

The following table sets forth the beneficial ownership of trust units of the trust that will be outstanding after giving effect to the consummation of this offering, assuming no exercise of the underwriters’ option to purchase additional trust units, and held, directly or indirectly, by each person who will then beneficially own 5% or more of the outstanding trust units.

 

 

The trust will enter into a registration rights agreement with Enduro Sponsor in connection with Enduro Sponsor’s contribution to the trust of the Net Profits Interest. Under the registration rights agreement, the trust will agree, for the benefit of Enduro Sponsor and any transferee of Enduro Sponsor’s trust units, to register the trust units they hold. In connection with the preparation and filing of any registration statement, Enduro Sponsor will bear all costs and expenses incidental to any registration statement, excluding certain internal expenses of the trust, which will be borne by the trust. Any underwriting discounts and commissions will be borne by the seller of the trust units. Please read “Trust Units Eligible for Future Sale — Registration Rights.”

 

The trust is a statutory trust created under the Delaware Statutory Trust Act on May 3, 2011. The affairs of the trust will be managed by The Bank of New York Mellon Trust Company, N.A., as trustee. Enduro Sponsor has no ability to manage or influence the operations of the trust. In addition, Wilmington Trust Company will act as Delaware trustee of the trust. The Delaware trustee will have only minimal rights and duties as are necessary to satisfy the requirements of the Delaware Statutory Trust Act. In connection with the completion of this offering, Enduro Sponsor will contribute the Net Profits Interest to the trust in exchange for 33,000,000 newly issued trust units. Enduro Sponsor will make its first payment to the trust pursuant to the Net Profits Interest in October 2011, which payment may include cash that Enduro Sponsor is required to pay to the trust relating to sales of oil and natural gas production for the months of May and June 2011 and production and development expenses for the months of May and June 2011. Subsequent distributions will only cover the net profits attributable to the Net Profits Interest for one month, and, as a result, are likely to differ substantially.

 

The trustee can authorize the trust to borrow money to pay trust administrative or incidental expenses that exceed cash held by the trust. The trustee may authorize the trust to borrow from the trustee as a lender provided the terms of the loan are fair to the trust unitholders. The trustee may also deposit funds awaiting distribution in an account with itself, if the interest paid to the trust at least equals amounts paid by the trustee on similar deposits, and make other short-term investments with the funds distributed to the trust. The trustee has no current plans to authorize the trust to borrow money.

 

The trust will pay the trustee and Delaware trustee an administrative fee of $200,000 and $2,000 per year, respectively. The trust will also incur legal, accounting, tax, advisory and engineering fees, printing costs and other administrative and out-of-pocket expenses that are deducted by the trust before distributions are made to trust unitholders. The trust will also be responsible for paying other expenses incurred as a result of being a publicly traded entity, including costs associated with annual, quarterly and monthly reports to trust unitholders, tax return and Form 1099 preparation and distribution, NYSE listing fees, independent auditor fees and registrar and transfer agent fees. Total administrative expenses of the trust on an annualized basis for 2011 are initially expected to be approximately $850,000, including the administrative fees payable to the trustee and Delaware trustee.

 

The trust will dissolve upon the earliest to occur of the following: (1) the trust, upon the approval of the holders of at least 75% of the outstanding trust units, sells the Net Profits Interest, (2) the annual cash available for distribution to the trust is less than $2 million for each of any two consecutive years, (3) the holders of at least 75% of the outstanding trust units vote in favor of dissolution or (4) the trust is judicially dissolved.

 

Immediately prior to the closing of this offering, Enduro Sponsor will create the Net Profits Interest through a conveyance to the trust of a Net Profits Interest carved from Enduro Sponsor’s interests in certain of its oil and natural gas properties located in Texas, Louisiana and New Mexico. The conveyance will be effected through the transfer of the Net Profits Interest by merger to a wholly owned subsidiary of Enduro Sponsor, which will then be merged into the trust. The Net Profits Interest will entitle the trust to receive 80% of the net profits from the sale of production of oil and natural gas attributable to the Underlying Properties.

 

The amount of trust revenues and cash distributions to trust unitholders will depend on, among other things:

 

 

The following table presents a calculation of forecasted cash distributions to holders of trust units for the twelve months ending September 30, 2012, which was prepared by Enduro Sponsor based on the assumptions that are described below and in “— Significant Assumptions Used to Prepare the Projected Cash Distributions.”

 

Typically, cash payment is received by Enduro Sponsor for oil production 30 to 60 days after it is produced and for natural gas production 60 to 90 days after it is produced. Given that the trust is entitled to production effective May 1, 2011 and the initial distribution will not occur until October 2011, the initial distribution in October 2011 may relate to net profits received from production from May and June of 2011. The forecasted cash distributions assume that each of the monthly distributions during the forecasted period will relate to production from a single month. To adjust for the lag between the timing of production and the timing of cash received by Enduro Sponsor and the trust, the forecasted cash distributions for the twelve months ending September 30, 2012 are based on estimated production of oil and natural gas for the twelve months ending April 30, 2012.

 

Unlike payments for production, payments related to hedges are settled during or very soon after the end of each month. As a result, and in an effort to better align payments associated with production and hedges, the trust will not bear any hedge settlement costs paid by Enduro Sponsor, or be entitled to any hedge payments received by Enduro Sponsor, for periods on or prior to June 30, 2011 (which is 60 days after May 1, 2011). In order to reflect this, the forecasted cash distributions for the twelve months ending September 30, 2012 reflect forecasted hedge settlements related to the twelve months ending June 30, 2012.

 

Enduro Sponsor does not as a matter of course make public projections as to future sales, earnings or other results. However, the management of Enduro Sponsor has prepared the projected financial information set forth below to present the projected cash distributions to the holders of the trust units based on the estimates and hypothetical assumptions described below. The accompanying projected financial information was not prepared with a view toward complying with the published guidelines of the SEC or guidelines established by the American Institute of Certified Public Accountants with respect to projected financial information.

 

In the view of Enduro Sponsor’s management, the accompanying unaudited projected financial information was prepared on a reasonable basis and reflects the best currently available estimates and

judgments of Enduro Sponsor related to oil and natural gas production, operating expenses and development expenses and other general and administrative expenses based on:

 

 

The projected financial information was also based on the hypothetical assumption that prices for oil and natural gas remain constant at $100.00 per Bbl of oil and $4.50 per MMBtu of natural gas during the twelve months ending April 30, 2012. These hypothetical prices are then adjusted to take into account Enduro Sponsor’s estimate of the basis differential (based on location and quality of the production) between published prices and the prices actually received by Enduro Sponsor. Actual prices paid for oil and natural gas expected to be produced from the Underlying Properties during the twelve months ending April 30, 2012 will likely differ from these hypothetical prices due to fluctuations in the prices generally experienced with respect to the production of oil and natural gas and variations in basis differentials. For example, for the twelve months ending June 30, 2011, the published daily average closing WTI crude oil spot price per Bbl was approximately $89.40 and the daily average Henry Hub natural gas spot price per MMBtu was approximately $4.16.

 

Please read “— Significant Assumptions Used to Prepare the Projected Cash Distributions” and “Risk Factors — Prices of oil and natural gas fluctuate, and lower prices could reduce proceeds to the trust and cash distributions to trust unitholders.”

 

Neither Enduro Sponsor’s independent auditors nor any other independent accountants have compiled, examined or performed any procedures with respect to the projected financial information contained herein, nor have they expressed any opinion or any other form of assurance on such information or its achievability, and assume no responsibility for, and disclaim any association with, the projected financial information.

 

The projections and estimates and the hypothetical assumptions on which they are based are subject to significant uncertainties, many of which are beyond the control of Enduro Sponsor or the trust. Actual cash distributions to trust unitholders, therefore, could vary significantly based upon events or conditions occurring that are different from the events or conditions assumed to occur for purposes of these projections. Cash distributions to trust unitholders will be particularly sensitive to fluctuations in oil and natural gas prices. Please read “Risk Factors — Prices of oil and natural gas fluctuate, and lower prices could reduce proceeds to the trust and cash distributions to trust unitholders.” As a result of typical production declines for oil and natural gas properties, production estimates generally decrease from year to year, and the projected cash distributions shown in the table below are not necessarily indicative of distributions for future years. Please read “— Sensitivity of Projected Cash Distributions to Oil and Natural Gas Production and Prices” below, which shows projected effects on cash distributions from hypothetical changes in oil and natural gas production and prices. Because payments to the trust will be generated by depleting assets and the trust has a finite life with the production from the Underlying Properties diminishing over time, a portion of each

distribution will represent, in effect, a return of your original investment. Please read “Risk Factors — The reserves attributable to the Underlying Properties are depleting assets and production from those reserves will diminish over time. Furthermore, the trust is precluded from acquiring other oil and natural gas properties or net profits interests to replace the depleting assets and production. Therefore, proceeds to the trust and cash distributions to trust unitholders will decrease over time.”

 

 

 

 

 

Significant Assumptions Used to Prepare the Projected Cash Distributions

 

Timing of actual distributions.  In preparing the projected cash distributions above and sensitivity analysis below, the revenues and expenses of the trust were calculated based on the terms of the conveyance creating the trust’s Net Profits Interest. These calculations are described under “Computation of Net Profits Interest.” It is the intent of the trust to distribute to trust unitholders proceeds received by the trust in the month after the trust receives such funds. Monthly cash distributions will be made to holders of trust units as of the applicable record date (generally the 15^th day of each calendar month) on or before the 10^th business day after the record date. Due to the amount of time it typically takes the Third Party Operators to collect payments from their customers and distribute their payments to the interest owners, including Enduro Sponsor, it has been assumed, for purposes of the projections, that cash distributions for each month will include oil production from 60 to 90 days prior to the distribution date and natural gas production from 90 to 120 days prior to the distribution date. The first distribution is expected to be made on or about October 28, 2011 to record trust unitholders as of or about October 14, 2011, and may include cash that Enduro Sponsor is required to pay to the trust relating to sales of oil and natural gas production for the months of May and June 2011 and production and development expenses for the months of April and May 2011.

 

Production estimates and development expenses.  In 2009 and 2010, Enduro Sponsor’s production declines were 5.4% and 12%, respectively, and for the year ended December 31, 2010, net sales were 939 MBbls of oil and 7,171 MMcf of natural gas. Based on the reserve reports, production volumes for the twelve months ending April 30, 2012 (the “forecast period”) are 911 MBbls of oil and 7,119 Mcf of natural gas, representing a decline in production of 1.7% for the forecast period from 2010 production. Historically, Enduro Sponsor’s decline rate has been much greater. This difference is due to increased vertical infill drilling of tight sands in the Hosston and Cotton Valley formations in the East Texas/North Louisiana region in 2008 and 2009. Despite the drilling of 1.3 net wells and 1.1 net wells in 2009 and 2010, respectively, this was insufficient to offset the decline from the drilling of 21.9 net wells in the Elm Grove field in 2008.

 

In 2010, 11 gross (1.0 net) wells were horizontally drilled in the Haynesville Shale formation on the Underlying Properties. As of July 25, 2011, Enduro Sponsor was participating in 26 gross (2.5 net)

horizontal Haynesville Shale wells in the Kingston and Elm Grove fields in the East Texas/North Louisiana region. According to the Third Party Operators, future development drilling will be increasingly focused on the horizontal Haynesville Shale and Lower Cotton Valley. Please see “The Underlying Properties — Near Term Development Activities” for more information regarding drilling activities in the Haynesville Shale. The impact of horizontal drilling can be large with initial producing rates up to 15 MMcf per day. Thus, although the 2010 Haynesville drilling activity was not large enough to sufficiently impact the character or decline of Enduro Sponsor’s proved developed production, future drilling activity in the Haynesville Shale is expected to shallow the overall 2011 and 2012 producing decline rates (as represented in the forecast period).

 

The proved undeveloped reserves scheduled in the Underlying Properties reserve report for 2011 through 2015 have modeled future drilling with 29 proved undeveloped Haynesville Shale and Lower Cotton Valley wells, along with 8 proved undeveloped Lost Tank field wells. Without any future drilling, the reserve report relating to the Underlying Properties reflects a proved developed producing decline rate for 2011, 2012, 2013, 2014 and 2015 of 16%, 14%, 12%, 9% and 9%, respectively. With the development of the proved undeveloped Haynesville Shale and Lower Cotton Valley wells in the reserve report, Enduro Sponsor expects an average increase of 1% on production from 2011 through 2015. For further information, please see the five-year production graph in “Prospectus Summary — Enduro Royalty Trust” and “The Underlying Properties — Near Term Development Activities.”

 

Oil and natural gas prices.  Assumed NYMEX oil and natural gas prices differ from the actual price received for production attributable to the Underlying Properties. Differentials between published oil and natural gas prices and the prices actually received for the oil and natural gas production may vary significantly due to market conditions, transportation, gathering and processing costs, quality of production and other factors.

 

In the above table, an average of $3.46 per Bbl is deducted from, and an average of $0.13 per Mcf is added to, the assumed NYMEX futures price for crude oil and natural gas, respectively, to reflect these differentials. These differences are based on Enduro Sponsor’s estimate of the average difference between the NYMEX published price of crude oil and natural gas and the price to be received by Enduro Sponsor for production attributable to the Underlying Properties during the twelve months ending April 30, 2012. Projected average oil and natural gas prices appearing in this prospectus have been adjusted for these differentials.

 

The differentials to published oil and natural gas prices applied in the above projected cash distribution estimate are based upon an analysis by Enduro Sponsor of the historic price differentials for production from the Underlying Properties with consideration given to gravity, quality and transportation and marketing costs that may affect these differentials. There is no assurance that these assumed differentials will occur.

 

When oil and natural gas prices decline, the operators of the properties comprising the Underlying Properties may elect to reduce or completely suspend production. No adjustments have been made to estimated production during the twelve months ending April 30, 2012 to reflect potential reductions or suspensions of production.

 

Settlement of Hedge Contracts.  Enduro Sponsor has entered into commodity derivative contracts with unaffiliated third parties in order to mitigate the effects of falling commodity prices through 2013. The trust will not bear any hedge settlement costs paid by Enduro Sponsor, or be entitled to any hedge payments received by Enduro Sponsor, for periods on or prior to June 30, 2011. For more information, see “The Underlying Properties — Hedge Contracts.”

 

Costs.  For the twelve months ending April 30, 2012, Enduro Sponsor estimates lease operating expenses to be approximately $23.4 million, production and other taxes to be approximately $9.2 million and development costs incurred to be approximately $14.3 million. For the year ended December 31, 2010, lease operating expenses of the Underlying Properties were $24.6 million, property and other taxes were $8.1 million and development costs incurred were $37.0 million. Enduro Sponsor

believes drilling activity during the year ended December 31, 2010 was in excess of that which will be undertaken in each of the next five years. For a description of direct operating expenses, see “Computation of Net Profits — Net Profits Interest.”

 

Net adjustment for additional projects.  Net adjustment for additional projects reflects the expected drilling of 21 gross (2.4 net) wells in the Haynesville Shale during the forecast period associated with development drilling projects not reflected in the reserve reports but for which notifications have been received by Enduro Sponsor as of June 2011 and as identified in the conveyance relating to the Net Profits Interest. The additional wells are expected to increase total sales volumes for the Underlying Properties during the forecast period by 221 MBoe. In estimating the production attributable to the Haynesville Shale projects discussed above, Enduro Sponsor used the same methodologies and assumptions as were used in the preparation of the reserve reports by Cawley Gillespie. During the forecast period, the additional wells are expected to increase total gross profits with respect to the Underlying Properties by approximately $3.3 million and total lease operating and development expenses and production and other taxes by $4.3 million, which is expected to result in a decrease in net profits for the Underlying Properties by $989,000 and cash available for distribution to the trust by $791,000. The amount of estimated development expenses has been adjusted to reflect the agreement by Enduro Sponsor to pay for up to $9.1 million (or $7.3 million attributable to the trust’s Net Profits Interest) of the total estimated development expenses of $12.4 million related to the 21 gross (2.4 net) wells, thereby reducing the trust’s share of development expenses associated with these wells to $2.6 million. In the absence of this payment obligation by Enduro Sponsor, the cash available for distribution to the trust would be reduced by an additional $7.3 million during the forecast period. Enduro Sponsor will not pay the trust’s share of any development costs relating to these wells in excess of the amounts described above, so the trust will bear 80% of any incremental development expenses. Enduro Sponsor will also not pay the trust’s share of any development costs for additional wells that may be drilled during the forecast period.

 

General and administrative expense.  The trust will be responsible for paying the annual fees to the trustees, all accounting fees, engineering fees, legal fees, printing costs and other out-of-pocket expenses incurred by or at the direction of the trustee or the Delaware trustee. The trust will also be responsible for paying other expenses incurred as a result of being a publicly traded entity, including costs associated with annual, quarterly and monthly reports to trust unitholders, tax return and Form 1099 preparation and distribution, NYSE listing fees, independent auditor fees and registrar and transfer agent fees. These general and administrative expenses are anticipated to be approximately $850,000 for the twelve months ending April 30, 2012. General and administrative expenses for subsequent years could be greater or less depending on future events that cannot be predicted. Included in the estimates is an annual administrative fee of $200,000 and $2,000 for the trustee and Delaware trustee, respectively. The trust will pay, out of the first cash payment received by the trust, the trustee’s and Delaware trustee’s legal expenses incurred in forming the trust as well as their acceptance fees in the amount of $10,000 and $1,500, respectively. These costs will be deducted by the trust before distributions are made to trust unitholders. See “The Trust.”

 

Sensitivity of Projected Cash Distributions to Oil and Natural Gas Production and Prices

 

The amount of revenues of the trust and cash distributions to the trust unitholders will be directly dependent on the sales price for oil and natural gas production sold from the Underlying Properties, the volumes of oil and natural gas produced attributable to the Underlying Properties, payments made or received under the hedge contracts and variations in direct operating expenses and development expenses.

 

The table and discussion below set forth sensitivity analyses of annual cash distributions per trust unit for the twelve months ending September 30, 2012, on the assumption that a trust unitholder purchased a trust unit in this offering and held such trust unit until the monthly record date for distributions for September 2012, based upon (1) the assumption that a total of 33,000,000 trust units are issued and outstanding after the closing of the offering made hereby; (2) realization of the

production levels estimated in the reserve reports; (3) the hypothetical commodity prices based upon assumed NYMEX prices; (4) the impact of the hedge contracts entered into by Enduro Sponsor that relate to production from the Underlying Properties; and (5) other assumptions described above under “— Significant Assumptions Used to Prepare the Projected Cash Distributions.” The hypothetical commodity prices of oil and natural gas production shown have been chosen solely for illustrative purposes.

 

The table below is not a projection or forecast of the actual or estimated results from an investment in the trust units. The purpose of the table below is to illustrate the sensitivity of cash distributions to changes in oil and natural gas pricing (giving effect to the hedge contracts that will be in place during the twelve months ending April 30, 2012). There is no assurance that the hypothetical assumptions described below will actually occur or that NYMEX futures prices will not change by amounts different from those shown in the tables.

 

The trust’s hedge contracts will be in effect only through December 31, 2013, and thus there is likely to be greater fluctuation in cash distributions resulting from fluctuations in the realized oil and natural gas prices in periods subsequent to the expiration of those contracts. See “Risk Factors” for a discussion of various items that could impact production levels and the prices of crude oil and natural gas.

 

Sensitivity of Projected Cash Distribution Per Trust Unit
to Changes in NYMEX Futures Pricing
(Period Estimate of May 2011 to April 2012)

 

 

The Underlying Properties consist of producing and non-producing interests in oil and natural gas units, wells and lands in Texas, Louisiana and New Mexico. The Underlying Properties include a portion of the assets in East Texas and North Louisiana acquired by Enduro Sponsor from Denbury Resources Inc. in December 2010, and all of the assets in the Permian Basin of New Mexico and West Texas acquired by Enduro Sponsor from Samson Investment Company and ConocoPhillips Company in January 2011 and February 2011, respectively. The Underlying Properties are divided into two geographic regions: the Permian Basin region and East Texas/North Louisiana region.

 

As of December 31, 2010, the Underlying Properties had proved reserves of 26.5 MMBoe. A majority of the proved reserves attributable to Underlying Properties are proved developed reserves. Proved developed reserves are the most valuable and lowest risk category of reserves because their production requires no significant future development expenses. As of December 31, 2010, approximately 79% of the volumes and 91% of the PV-10 value of the proved reserves associated with the Underlying Properties were attributed to proved developed reserves. As of December 31, 2010, the Third Party Operators and Enduro Sponsor were the operators of 99% and 1%, respectively, of the proved reserves attributable to the Underlying Properties, based on PV-10 value.

 

As proved reserves are evaluated using only direct costs such as production costs, production taxes, work-over, gathering and processing, transportation and drilling costs, if applicable, and other costs such as general and administrative, depreciation, depletion and amortization, interest and derivative losses are not included, the attribution of proved reserves is not necessarily a sign of future overall corporate profitability.

 

The following table sets forth, as of December 31, 2010, certain estimated proved reserves, estimated future net revenues and the discounted present value thereof attributable to the Underlying Properties, 80% of the Underlying Properties and the Net Profits Interest, in each case derived from the reserve reports.